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PEGGY M. HATCH

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DEPARTMENT OF ENVIRONMENTAL QUALITY

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- Re: Baton Rouge Nonattainment Area Redesignation and Maintenance Plan,

1997 8-hour Moderate SIP Revision and CTGIRACT SIP Revision

(Redesignation Package)

Dr. Alfredo Armendariz

Regional Administrator

U. S. EPA Region 6 (6-RA)

1445 Ross Avenue, Suite 1200

Dallas, Texas 75202-2733

Dear Dr. Armendariz:

As the official designee of Governor Bobby Jindal and on behalf of the State of Louisiana, I

respectfully submit this final Redesignation Package for your approval. The Baton Rouge

Nonattainment Area has worked diligently toward this attainment goal.

Enclosed you will find three separate documents, all of which comprise the Redesignation

PackageJ The first element is the 1997 8-hour Moderate Revisions SIP, which outlines the

outstanding requirements outlined in the March 21, 2008 Federal Register Notice (73 FR

15087).

The second component is the Reasonably Available Control Technology (RACT) revisions,

comprised of the latest Control Technique Guideline (CTG) rulemakings as well as a

thorough discussion of the Volatile Organic Compound (VOC) and Oxides of Nitrogen

(NOx) rules and their applicability to the various industries in the nonattainment area. The

data in this document clearly proves the permanent and enforceable measures that have

helped this area attain both the I-hour and the 1997 8-hour ozone standards.

The final document is the state's Redesignation Request and Maintenance Plan which

outlines the Louisiana Department of Environmental Quality's (LDEQ) obligation to the

people of the state of Louisiana to sustain the current control strategy while working toward

continued emissions reductions.

Post Office Box 4301 • Baton Rouge, Louisiana 70821-4301 • Phone 225-219-3953· Fax 225-219-3971
Dr. Alfredo Armendariz

August 31, 2010

Page 2

If you or your staff have questions concerning this submittal, please ask them to contact

either Michael Vince, Administrator at (225)-219-3482 or by email at michael.vince@la.gov

or Vivian Aucoin, SIP Coordinator at (225) 219-3419 or by email at vivian.aucoin@la.gov.

I would like to thank you and your staff for all the assistance you provided to LDEQ. I hope

that our agencies can continue to work together successfully on the forthcoming ozone

standard as well as the various other standards issued by EPA.

c: Governor Bobby Jindal

Guy Donaldson, EPA
Revision to the Louisiana 

State Implementation Plan for the 

Baton Rouge Nonattainment Area 

Baton Rouge 1997 8-Hr Moderate 

Reclassification 

Submitted to: Dr. Alfredo Armendariz 

EPA Region 6 

1445 Ross Avenue, Suite 1200 

Dallas, TX 75202-2733 

Submitted: August 31, 2010 
Table of Contents

Baton Rouge 1997 8-Hr Moderate Reclassification

EXECUTIVE SUMMARy 1

SECTION 1:

1.1:

1.2:

1.3:

1.4:

1.5:

1.6:

SECTION 2:

2.1:

2.2:

PUBLIC NOTICE 3

Potpourri 0908Pot2 6

Newspaper Notices 8

Public Hearing Sign-In Sheet. 18

Public Hearing Transcript 19

Written Comments from EPA 29

Comment Summary Responses and Concise Statement.. .38

ATTAINMENT DEMONSTRATION 45

Technical Support Document:

Modeling to Support the Baton Rouge, Louisiana 8-Hour Ozone State

Implementation Plan 46

Mobile6 Motor Vehicle Emissions Budgets for the

Baton Rouge 8-Hr Ozone Nonattainment Area 398

SECTION 3: REASONABLE FURTHER PROGRESS 556

3.1: 2002-2008 RFP Demonstration 558

3.2: Appendices 566

SECTION 4:

4.1:

4.2:

4.3:

4.4:

4.5:

4.6:

4.7:

4.8:

4.9:

4.10:

SECTION 5:

5.1:

5.2:

5.3:

CONTINGENCY PLAN 576

Contingency Plan , 578

Appendix - Certified NOx Pollutant Emissions (tpy) by Facility 581

AQ305, Proposed Rule 587

Newspaper Notices 592

Public Hearing Sign-InSheet. 601

Public Hearing Transcript 602

Written Comments from' EPA 611

Written Comments from Kean Miller 613

Comment Summary Responses and Concise Statement.. 617

AQ305, Final Rule 625

OUTSTANDING REQUIREMENTS 630

Major Source Permits and Nonattainment New Source Review 632

Section 185 Fees 634

Reformulated Gasoline 635
EXECUTIVE SUMMARY 

Louisiana is hereby proposing revisions to the State Implementation Plan (SIP) 

for the Baton Rouge ozone nonattainment area to address the federal Clean Air Act’s 

(CAA) pollution control requirements for 1997 8-hour moderate ozone nonattainment 

areas, and to demonstrate attainment by June 15, 2010. Louisiana is submitting this 

revision to the SIP for the Baton Rouge nonattainment area to the Environmental 

Protection Agency (EPA) which addresses the CAA’s pollution control requirements as 

set forth in the March 21, 2008 Federal Register notice (73 FR 15087). 

On July 18, 1997, EPA promulgated a revised 8-hour ozone standard of 0.080 

parts per million (ppm). This new standard was more stringent that the previous 1-hour 

standard. The Baton Rouge 8-hour ozone nonattainment area consists of the parishes of 

Ascension, East Baton Rouge, Iberville, Livingston, and West Baton Rouge in southern 

Louisiana. The Baton Rouge area was initially designated nonattainment for the 8-hour 

ozone standard on April 30, 2004, and classified as “marginal” based on a design value of 

0.086 ppm, with an attainment date of June 15, 2007 (April 30, 2004, 69 FR 23858). The 

design value of an area, which characterizes the severity of the air quality concern, is 

represented by the annual fourth-highest daily maximum 8-hour average ozone 

concentration measured at each monitor averaged over a three year period. The Baton 

Rouge nonattainment area did not attain the 8-hour ozone standard by the June 15, 2007 

deadline for marginal areas. 

Section 181(b)(2)(A) of the CAA provides that, when EPA finds that an area fails 

to attain by the applicable date, the area is reclassified, by operation of law, to the higher 

classification applicable to the area’s ozone design value at the time of the required notice 

under Section 182(b)(2)(B). The applicable classification was based on a design value of 

0.091 ppm based on quality-assured ozone monitoring data from 2004-2006. Therefore, 

the Baton Rouge ozone nonattainment area was reclassified, by operation of law, as 

“moderate”. Moderate areas are required to attain the standard “as expeditiously as 

practicable” but no later than 6 years after designation. Based on this reclassification, the 

area’s new attainment date is June 15, 2010. 

As of December 31, 2008, the area monitored attainment and has requested a 

redesignation to attainment. A maintenance plan is being submitted under separate cover. 

1
Further, the area has requested a formal determination of attainment of the 1-hour ozone 

standard. EPA proposed approval of this request on March 26, 2009 (74 FR 13166), and 

was made final on February 10, 2010 (75 FR 6570). The department also requested a 

formal determination of attainment for the 1997 8-hour ozone standard on December 14, 

2009. EPA proposed approval and promulgation of this request on June 25, 2010 (75 FR 

36316). 

The proposed revisions to the ozone attainment SIP for Baton Rouge to fulfill 

“moderate” area CAA requirements as directed in the March 2008 Federal Register 

notice (73 FR 15087) include: 

(1) An attainment demonstration (40 CFR 51.908); 

(2) Provisions for reasonable available control technology (RACT) and 

reasonably available control measures (RACM) (40 CFR 51.912); 

(3) Reasonable further progress reductions in volatile organic compound (VOC) 

and nitrogen oxide (NOx) emissions (40 CFR 51.910); 

(4) Contingency measures to be implemented in the event of failure to meet a 

milestone or attain the standard (CAA 172(c)(9)); 

(5) A vehicle inspection and maintenance program (40 CFR 51.350); 

(6) NOx and VOC emissions offset of 1.15 to 1 for major source permits (40 CFR 

165(a)). 

2
SECTION 1 

PUBLIC NOTICE 

3
4
SECTION 1 

Public Notice 

 In accordance with La. R.S. 49:950 et seq., and to comply with 40 CFR 51.285, Public 

Notification, The Louisiana Department of Environmental Quality published in the Louisiana 

Register on August 20, 2009, a notice seeking comment on this SIP revision. A public hearing 

concerning this proposed SIP revision was held at 1:30 p.m. on September 24, 2009, in the 

Galvez Building, Oliver Pollock Conference Room, 602 N. Fifth Street, Baton Rouge, LA 

70802. Interested parties were invited to submit written or oral comments on the proposed 

revision at that time. The comment period closed at 4:30 p.m. on September 24, 2009. Written 

comments were accepted via mail, fax, or email. 

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March 11, 2010 

Page 1 of 7 

Comment Summary Response & Concise Statement 

State Implementation Plan Revision 

Baton Rouge 1997 8-Hour Moderate Reclassification 

COMMENT 1: — Since the black and white graphics in the Technical Support 

Document (TSD) are difficult to review, a color version displayed 

on the department’s website would be helpful. 

RESPONSE 1: — A color version of the TSD has been made available on the 

department’s website. 

COMMENT 2: — In Chapter 6, the 2005 episode could be presented as a weight 

of evidence (WOE) element, even though it was not used in the 

attainment demonstration test. Include, somewhere in the TSD, 

an explanation of why the 2005 episode was dropped. 

RESPONSE 2: — An explanation of why the 2005 episode was dropped has 

been added to Section 1.2.1 of the TSD. 

COMMENT 3: Chapter 2 — A more thorough documentation of the analyses 

performed regarding the meteorological model performance is 

needed. Include any power point presentations or reports that are 

referenced in the state implementation plan (SIP). These should 

be available to the public, including the raw analysis of the 

meteorology that Alpine Geophysics performed, if it is available 

from the department. 

RESPONSE 3: Chapter 2— A thorough documentation of the analyses performed 

regarding the meteorological model performance can be found in 

Appendix C of the TSD. 

COMMENT 4: Chapter 3 — The emissions discussion cites the Texas 

Commission on Environmental Quality (TCEQ) 2008b. The files 

are no longer available on TCEQ’s ftp; therefore a mention should 

be included stating how the files can be obtained from LDEQ. 

Include a write-up to document what databases and assumptions 

were in the TCEQ emission files that were used for other states in 

the modeling domain for the 2006 and 2009 emission inventories. 

38
March 11, 2010 

Page 2 of 7 

Include a discussion on how the emission files were QA/QC’d. 

RESPONSE 4: Chapter 3 — Discussions concerning TCEQ’s files and databases 

can be found in Section 3.1.1 and Appendix E of the TSD. 

COMMENT 5: Chapters 4 and 5 — To give a more complete picture of the 

model response on different days, plots for all modeled days, or at 

least all days used in the attainment test, should be included. 

Plots could be placed in either Chapter 4 or Chapter 5, as 

appropriate, or in Appendix B. 

 A table to evaluate daily model response would be helpful. 

The table should have the daily 8-hour maximums for each 

monitor, base and future year, for each episode day (May 27-July 

1). 

RESPONSE 5: Chapters 4 and 5 — To provide a complete picture of the model 

response, Appendix D (Daily 8-hour Ozone Modeling Results — 

CAMx Runs 13 and 15) has been added to the TSD. 

COMMENT 6: Chapter 6 — Some additional items could be pulled from the 

redesignation proposal and when added to this SIP revision would 

round out the WOE and support the modeling conclusion that the 

area will be in attainment in 2009. For example, Chart 1 and 

Tables 1, 5, and 6 from the Baton Rouge Ozone Redesignation 

and Maintenance proposed package would provide information on 

projected emission trends and recent monitoring showing 

attainment of the 1-hour and 1997 8-hour ozone standards. A 

short explanation, describing how future emissions in the 5-parish 

area are expected to continue a downward trend, would also be 

helpful. Include a brief mention of how the HYSPLIT runs help to 

validate the meteorological modeling for the days used in the 

modeled attainment test. 

RESPONSE 6: Chapter 6 — These items have now been addressed in Section 

6.2 of the TSD. 

COMMENT 7: Section 2.2 — Provide a table/summary of source types (area, 

point, non-road) emissions values for the 2009 attainment year, 

for comparison with the 2009 motor vehicle emissions budget 

(MVEB) in Table 3-1. This will help to satisfy the requirements in 

39
March 11, 2010 

Page 3 of 7 

40 CFR 93.118(e)(4)(iv)-(v). It will also outline what amount of the 

available on-road emissions inventory was used to constitute the 

MVEB numbers. 

RESPONSE 7: Section 2.2 — The MVEB in Table 3-1 is the same as Table 3-13 

in Section 3.2.2 (TSD) in Section 2.1 (SIP). Table 3-13 contains 

the other source type emissions values for 2009. 

COMMENT 8: Section 3 — Base Year Emissions Inventory — The 2002 base 

year inventory was approved in a Federal Register notice (74 FR 

45561) published on Sept. 3, 2009. 

RESPONSE 8: Section 3 — Base Year Emissions Inventory — No response 

necessary. 

COMMENT 9: Section 3 — Baton Rouge 1997 8-Hour Moderate Reclassification 

— The department has documented the correct amount for the 

total expected reductions in the nonattainment area by showing 

each step, discussing any assumptions made, and stating the 

origins of the numbers used in the calculations. 

RESPONSE 9: Section 3 — Baton Rouge 1997 8-Hour Moderate Reclassification 

— No response necessary. 

COMMENT 10: Section 3 — Reasonable Further Progress (RFP) Demonstration 

— The control measures included in the 2008 projection inventory 

are adequate to meet the 15% RFP requirement because the 

projected 2008 inventory is less than the target level of emissions. 

 No MVEBs associated with RFP were found in the 

document. The department should establish MVEBs for the 2008 

milestone year (40 CFR 93.118(a)(1)(i)). If the MVEBs 

established by the 2009 attainment demonstration are more 

stringent than the 2008 RFP budgets, they will supersede the 

2008 RFP budgets. 

 The department should provide a table summarizing the 

control measures used for RFP and the expected emission 

reductions from the control measures. 

RESPONSE 10: Section 3 — Reasonable Further Progress (RFP) Demonstration 

― The 2009 MVEB is more stringent than the motor vehicle 

40
March 11, 2010 

Page 4 of 7 

emissions in the 2008 RFP and supersede the 2008 RFP budget. 

The control measures used for RFP are found in Section 3 

(Reasonable Further Progress) of the SIP and the reductions are 

shown in Table D-1, Section 3 of the SIP. 

COMMENT 11: Section 3 — Contingency Measures for the RFP Plan — No 

additional controls are required for the 2009 contingency plan for 

the Baton Rouge nonattainment area. 

RESPONSE 11: Section 3 — Contingency Measures for the RFP Plan — No 

response necessary. 

COMMENT 12: Section 4 — Contingency Plan for Failure to Attain — The failure 

to attain measure included in the attainment demonstration plan is 

in the process of being adopted and does achieve the required 

3% emission reductions. 

RESPONSE 12: Section 4 — Contingency Plan for Failure to Attain — No 

response necessary. 

COMMENT 13: Section 5 — The pages in this Section are bound backwards and 

read from back to front. 

RESPONSE 13: Section 5 — This oversight has been corrected. 

COMMENT 14: Section 5 — Control Techniques Guidelines (CTG) Rule Updates 

— A review and comment of the CTG submittal of August 20, 

2009, is being prepared separately. 

RESPONSE 14: Section 5 — Control Techniques Guidelines (CTG) Rule Updates 

— No response necessary. 

COMMENT 15: Section 5 — Reasonably Available Control Technology (RACT) — 

A RACT analysis for the Baton Rouge area was not included in 

this submittal. A redesignation to attainment cannot be approved 

without an approvable RACT demonstration. The state needs to 

41
March 11, 2010 

Page 5 of 7 

develop an adequate and thorough RACT SIP. 

RESPONSE 15: Section 5 — Reasonably Available Control Technology (RACT) — 

A RACT analysis has been included in the final submittal. 

COMMENT 16: Section 5 — Reasonably Available Control Measures (RACM) 

Demonstration — A statement about RACM in the context of 

RACT should be included in order to adequately discuss the 

required elements of RACT. 

RESPONSE 16: Section 5 — Reasonably Available Control Measures (RACM) 

Demonstration — A RACM analysis has been included in the final 

submittal. 

COMMENT 17: Section 5.1 — Major Source Permits and Nonattainment New 

Source Review (NSR) — Add a reference to the EPA Phase I 

rule. 69 FR 23857. 

RESPONSE 17: Section 5.1 — Major Source Permits and Nonattainment New 

Source Review — The applicable reference has been made. 

COMMENT 18: Section 5.1 — Major Source Permits and Nonattainment New 

Source Review — Severe nonattainment NSR requirements 

should be implemented in Baton Rouge. 

RESPONSE 18: Section 5.1 — Major Source Permits and Nonattainment New 

Source Review — No response necessary. 

COMMENT 19: Section 5.2 — Section 185 Fees — A Section 185 penalty fee 

program is a required element and must be in place before a 

redesignation can be approved. 

RESPONSE 19: Section 5.2 — Section 185 Fees— Louisiana has requested a 

Termination Determination based on the guidance memorandum 

issued by EPA on Jan. 5, 2010 titled, Guidance on Developing 

Fee Programs Required by Clean Air Act Section 185 for the 1-

hour Ozone NAAQS. 

42
March 11, 2010 

Page 6 of 7 

COMMENT 20: Section 5.3 — Reformulated Gasoline (RFG) — The state should 

consider what the impact on the maintenance projections would 

be if RFG is implemented at some future date. 

RESPONSE 20: Section 5.3 — Reformulated Gasoline (RFG) — The state has 

considered the impact of the use of reformulated gasoline in the 

Baton Rouge nonattainment area (BRNA). Modeling in June of 

2004 indicated that the use of RFG would increase nitrogen oxide 

(NOx) levels by 0.04 tons per day, or 14.6 tons per year. This 

would pose a direct disadvantage to the BRNA air quality 

because the BRNA is a NOx limited area. 

43
March 11, 2010 

Page 7 of 7 

Comment Summary Response & Concise Statement Key 

State Implementation Plan Revision 

Baton Rouge 1997 8-Hour Moderate Reclassification 

COMMENT No. SUGGESTED BY

1 ― 20 Guy Donaldson, Chief 

 EPA, Air Planning Section 

44
Section 2, Attainment Demonstration, is in a separate document 
SECTION 3 

REASONABLE FURTHER PROGRESS 

556
557
2002 TO 2008 RFP DEMONSTRATION

A. INTRODUCTION 

On June 15, 2004, the Environmental Protection Agency (EPA) classified the Baton Rouge 

Nonattainment Area (BRNA) as marginal for the 1997 8-hour ozone standard with an attainment date of 

June 15, 2007. Because the area did not meet the attainment date, the BRNA was re-classified to 

moderate with a new attainment date of June 15, 2010. (FR72, 61315, 10/30/2007) 

Phase II of the 1997 Eight-Hour Ozone Implementation Rule states that moderate areas must meet the 

Reasonable Further Progress (RFP) requirements under sections 172(c)(2) and 182 of the 1990 Clean Air 

Act Amendments (CAA). In a memorandum from William T. Harnett of EPA that the State received on 

August 15, 2006, guidance was provided for calculating RFP for moderate areas that have an approved 

15% ROP plan under the 1-hour standard and that have an attainment date after 2009. The guidance 

states: “These areas are treated like subpart I areas, which must obtain a 15% reduction (can be for NOx 

or VOC or a combination of either) for the first 6 years after the baseline year. OTAQ [EPA Office of 

Transportation and Air Quality] is developing guidance for this situation. In the meantime, the State 

should use Appendix A/Method 2 (which applies to serious and higher classified areas) except that 

instead of demonstrating RFP for a total of 18% emission reductions for the first 6 years, the total would 

be 15% due to the moderate classification. See 40 CFR 51.910(a)(1)(ii)(A), which refers to section 

51.910(b)(2).”

This document details the process and results to show that the state meets the 15% RFP emission 

reduction requirements for the period between the 2002 base year through the 2008 RFP milestone year. 

Compliance with the 2008 milestone emission reduction requirements are demonstrated by using EPA 

guidance, first to calculate the elements of the RFP demonstration and then to use these elements in 

conjunction with EPA RFP methodology to demonstrate compliance with RFP reduction requirements. 

The required RFP elements are: 

2002 base year emissions 

2002 to 2008 non-creditable reductions 

2002 to 2008 required RFP reductions 

2008 target level of emissions 

2002 to 2008 projected emissions growth 

2008 RFP milestone year projected emissions with growth and controls 

Demonstration of compliance with RFP requirements 

Contingency plan 

This document describes how the elements of the BRNA 2008 RFP demonstration are calculated and 

used to demonstrate compliance with 2008 RFP requirements; it also provides a summary of the 2008 

BRNA RFP demonstration. First, the target level of emissions for 2008 is calculated. Second, the 2008 

RFP milestone year emissions with 2002 to 2008 emissions growth and controls are projected. Third, the 

558
2008 target level of emissions is compared to the projected 2008 RFP milestone year emissions in order 

to demonstrate compliance with the RFP requirements. Finally, in case of a milestone year failure, the 

required 3% contingency plan is provided. 

 

B. 2008 TARGET LEVEL CALCULATION 

EPA guidance specifies the method states are to use to calculate the maximum amount of emissions a 

nonattainment area can emit for an RFP milestone year. The RFP target level of emissions is calculated 

with a six-step process. 

Develop the 2002 base year inventory 

Develop the 2002 RFP base year inventory 

Calculate the non-creditable fleet turnover correction 

Develop the adjusted RFP base year inventory for 2002 relative to 2008 

Calculate the 2008 required 15% emissions reduction 

Calculate the 2008 target level of emissions 

1. Develop the 2002 Base Year Inventory 

EPA guidance specifies the method states must use to develop the base year inventory. Details of the 

development of the BRNA 2002 inventory are described in the document “2002 Base Year Emissions 

Inventory for the Baton Rouge Nonattainment Area” by LDEQ in June 2007 and submitted to EPA on 

July 20, 2007. A summary of the 2002 base year emissions inventory is shown in Table B-1. 

Table B-1: BRNA 2002 Base Year Ozone Season Weekday Emissions Inventory 

Source Category NOx (Tons/Day) VOC (Tons/Day)

Stationary Point 116.2 40.2 

Area /with Nonroad 38.8 44.7

Mobile 45.3 26.5

Biogenic 0.0 99.6

Total 200.3 211.0

2. Develop the 2002 RFP Base Year Inventory. 

EPA guidance specifies that the RFP reductions must be based on anthropogenic emissions only. For 

NOx, with no biogenic emissions in the 2002 Base Year Inventory, the 2002 RFP Base Year Inventory is 

the same as the 2002 Base Year Inventory. For VOC, the 2002 RFP Base Year Inventory is equal to 211.0 

minus 99.6 or 111.4 tons/day (TPD). 

3. Calculate the Non-creditable Fleet Turnover Correction 

EPA guidance states that emission reductions due to vehicle fleet turnover (higher polluting older vehicles 

being replaced by lower polluting newer vehicles) are not creditable towards RFP. The emission 

inventories are a representation of the effects of pre-1990 CAA controls projected to the RFP base and 

milestone years. As such, these inventories can be used to estimate the effects of the pre-1990 CAA 

controls between milestone years. 

559
The emission rates are developed using the latest version of EPA’s emission factor model, 

MOBILE6.2.03. The model input file is set up to disable all 1990 CAA effects, set the model evaluation 

year to the RFP base or milestone year, and then the model is run to determine emission factors for the 

base or milestone year with only pre-1990 CAA controls. The emission factors for all years are then 

multiplied by the 2002 base year VMT. The non-creditable fleet turnover correction is calculated by 

subtracting the 2008 projected emissions from the 2002 projected emissions. The results are summarized 

in Table B-2. (See Appendix – Calculation of FMVCP/RVP Reductions) 

Table B-2: FMVCP/RVP Emissions Corrections

NOx Mobile Emissions, TPD VOC Mobile Emissions, TPD

Target Year Target Year

Target Year 2002 Actual w/2002 VMT (1) 2002 Actual w/2002 VMT (1)

2002 45.3 51.0 26.5 29.0

2008 45.3 44.6 26.5 24.6

Correction 6.4 4.4

(1) Post 1990 Clean Air Act controls off 

4. Develop the Adjusted RFP Base Year Inventory for 2002 Relative to 2008 

The Adjusted RFP Base Year Inventory for 2002 Relative to 2008 is equal to the 2002 RFP Base Year 

Inventory, as calculated in Step 2, minus the Non-creditable Fleet Turnover Correction, as calculated in 

Step 3. For NOx, the calculation is 200.3 less 6.4 or 193.9 TPD. For VOC, the calculation is 111.4 less 

4.4 or 107.0 TPD. 

5. Calculate the 2008 Required 15% Emissions Reduction 

The EPA 1997 Phase II Eight-Hour Ozone Implementation Rule requires all ozone nonattainment areas 

classified as moderate and above to reduce NOx and/or VOC emissions by 15% for the period 2002 

through 2008. The required 2008 reductions are calculated by multiplying the Adjusted RFP Base Year 

Inventory for 2002 Relative to 2008, as calculated in Step 4, by the percent reduction needed to meet RFP 

requirements. LDEQ has decided to rely on NOx reductions to meet the RFP requirements. As such, the 

required NOx reductions are equal to 193.9 times 15% or 29.1 tons/day. 

 6. Calculate the 2008 Target Level of Emissions 

The 2008 Target Level of Emissions is calculated by subtracting the required emission reductions, as 

calculated in Step 5, and the Non-creditable Fleet Turnover Correction, as calculated in Step 3, from the 

2002 Base Year Inventory. For NOx, the calculation is 200.3 minus 29.1 and minus 6.4 or 164.8 tons/day. 

The RFP plan must demonstrate that the projected emissions for 2008, reflecting growth and the RFP 

control strategy, will be less than or equal to the 2008 Target Level of Emissions. Table B-3 summarizes 

the calculation of the Target Level. Note: The VOC calculation is shown for information only. 

560
 Table B-3: Summary of Calculation of Target Level for BRNA 

Description NOx, TPD VOC, TPD

Step 1: 2002 Base Year Inventory 200.3 211.0

Step 2: Emissions from Biogenic Sources 0.0 99.6

Step 2a: Calculate the 2002 RFP Base Year Inventory (Step 1 minus Step 2) 200.3 111.4

Step 3: 2002 to 2008 Non-creditable Fleet Turnover Correction 6.4 4.4

Step 4: Calculate the Adjusted RFP Base Year Inventory (Step 2a minus Step 3) 193.9 107.0

Step 5: Percent of NOx and VOC to meet 15% Reduction Requirement 15.0 0.0

Step 5a: Calculate the 2008 15% Reduction Requirement (Step 4 times Step 5) 29.1 0.0

Step 6: Calculate the 2008 Target Levels (Step 4 minus Step 5a) 164.8 107.0

C. 2008 RFP MILESTONE YEAR EMISSIONS PROJECTION 

EPA guidance specifies the method states must use to project the 2008 milestone year emissions. The 

projection is used to demonstrate compliance with RFP reduction requirements. The RFP milestone year 

emissions are projected with a three-step process. 

Determine the growth from 2002 to 2008 for the various source categories 

Determine the emission reductions from controls applied between 2002 and 2008 

Project the 2008 RFP milestone year emissions 

 1. Determine the Growth from 2002 to 2008 for the Various Source Categories 

EPA guidance requires that the growth of each source category be determined and included in the 2008 

milestone year emissions projection. 

Point Sources – The BRNA is classified as moderate nonattainment for the 1997 8-hour ozone standard. 

The CAA Section 182(b)(5) requires moderate areas to off-set growth by a minimum of 1.15 to 1.0. For 

this RFP demonstration, it is assumed that the off-set requirement will result in no NOx point source 

growth within the BRNA. The correctness of this assumption can be confirmed by comparing the point 

source inventory from the 2002 base year with the LDEQ Emission Inventory (EI) for 2007 (2008 is not 

yet available) as follows: 

 Table C-1: Comparison of NOx Inventory for 2002 to 2007 

Description NOx, TPD

2002 Base Year NOx Point Source Inventory 116.2

NOx Control Rule Reductions 40.0 (1)

NOx Inventory After Controls 76.2

2007 EI NOx 71.2

(1) The NOx Control Rule (LAC 33:III.2201) was designed to achieve approximately 40 TPD 

reductions in the BRNA. 

561
The required off-set, plus other factors, has resulted in an estimated excess over controls decrease in point 

source emissions of approximately 5 TPD. (See 2002 and 2007 Point Source Inventories in Appendix –

Point Sources by Facility) 

Area and Nonroad Sources– EPA guidance requires that states project growth of these emission 

categories with the Economic Growth Analysis System (EGAS) model. The EGAS growth factors for the 

emission categories in the BRNA were determined and then multiplied times the 2002 emissions to get 

the projected 2008 emissions. The growth was calculated by subtracting the 2002 emission from the 2008 

estimated emission for each category. (See Appendix – Calculation of Area Source Growth, 

Calculation of Nonroad Source Growth) 

Mobile Sources - EPA guidance requires that states project mobile source growth with the 

MOBILE6.2.03 model. Using the model and the projected 2008 Vehicle Miles Travelled (VMT), the 

2008 estimated emissions were determined. The growth was calculated by subtracting the 2002 emissions 

from the 2008 estimated emissions. (See Appendix – Calculation of Mobile Source Growth)

The following table summarizes the projected growth from 2002 to 2008 for all source types. 

Table C-2: Projected Growth by Source Type 

Source Type NOx, TPD VOC, TPD

Point 0.0 0.0

Area 0.26 3.29

Nonroad 3.90 0.36

Mobile -15.7 -7.8

 Total Growth -11.54 -4.15

 2. Determine the Emission Reductions from Controls Applied Between 2002 and 2008 

a. In early 2002 LDEQ promulgated a NOx control rule (LAC 33:III, Chapter 22) that established 

requirements for reducing NOx emissions during the ozone season in the Baton Rouge nonattainment area 

as well as four parishes to the north of Baton Rouge. Affected facilities included those with one or more 

sources that collectively emitted or had the potential to emit fifty tons per year or more of NOx. 

The rule established emission factors for boilers, heaters, furnaces, turbines and internal combustion 

engines. Further, the rule established requirements for permits, compliance demonstration, recordkeeping 

and reporting. Facilities were required to have controls fully operational by May 1, 2005. 

The rule established the following emission limits: 

Electric Power Generating System Boilers

Coal-fired ........................................................................................ 0.21 lb/MMBtu 

Number 6 Fuel Oil-fired ................................................................. 0.18 lb/MMBtu 

All Others (gaseous or liquid) ........................................................ 0.10 lb/MMBtu 

Industrial Boilers ............................................................................ 0.10 lb/MMBtu 

Process Heaters/Furnaces

Ammonia Reformers ...................................................................... 0.23 lb/MMBtu 

All Others ....................................................................................... 0.08 lb/MMBtu 

562
Stationary Gas Turbines 

Peaking Service, Fuel Oil-fired ....................................................... 0.30 lb/MMBtu 

Peaking Service, Gas-fired ............................................................. 0.20 lb/MMBtu 

All Others ....................................................................................... 0.16 lb/MMBtu 

Stationary Internal Combustion Engines

Lean-burn ............................................................................................. 4 g/Hp-hour 

Rich-burn ............................................................................................ 2 g/Hp-hour 

Additionally, after the BRNA was reclassified to severe, LDEQ promulgated a revision to Chapter 22 

(29LR1674) that established requirements for smaller NOx sources - equal to or greater than twenty-five 

tons per year and less than fifty tons per year. All other provisions of Chapter 22 remained the same. 

The rule proposed the following emission limits for these smaller sources: 

Electric Power Generating System Boilers

 Coal-fired ......................................................................................... 0.50 lb/MMBtu 

 Number 6 Fuel Oil-fired ................................................................. 0.30 lb/MMBtu 

 All Others (gaseous or liquid) ........................................................... 0.20 lb/MMBtu 

Industrial Boilers ............................................................................. 0.20 lb/MMBtu 

Process Heaters/Furnaces

Ammonia Reformers ....................................................................... 0.30 lb/MMBtu 

 All Others ......................................................................................... 0.18 lb/MMBtu 

Stationary Gas Turbines 

Peaking Service, Fuel Oil-fired ....................................................... 0.37 lb/MMBtu 

Peaking Service, Gas-fired .............................................................. 0.27 lb/MMBtu 

All Others ........................................................................................ 0.24 lb/MMBtu 

Stationary Internal Combustion Engines

Lean-burn ........................................................................................... 10 g/Hp-hour 

Rich-burn ............................................................................................. 2 g/Hp-hour 

The Chapter 22 NOx rule was designed to achieve approximately 40 TPD of reductions in BRNA only. 

b. Other regulations and programs that reduced NOx (and VOC) emissions after 2002 include: 

(1) Mobile Source Controls - Mobile source controls that reduced NOx and VOC emissions included a 

vehicle inspection and maintenance (I/M) program and federal motor vehicle control programs (FMVCP). 

All mobile source control programs were modeled with EPA’s current version of the onroad emissions 

model, MOBILE6. Below is a brief summary of these mobile source control programs.

563
(a) Vehicle I/M Program – LDEQ promulgated a revision to the low enhanced vehicle I/M program for 

the BRNA. LDEQ received full approval from EPA for its low enhanced I/M program (Final Rule, 67 FR 

60594). The program included gas cap testing and visual anti-tampering checks on 1980 and newer 

gasoline-fueled cars and trucks weighing less than 10,000 lbs (gross vehicle weight rating). On-board 

diagnostic (OBD) testing is conducted on 1996 and newer vehicles. Annual emission testing is conducted 

using a decentralized network of certified motor vehicle inspection stations. 

(b) Tier 2/Low Sulfur Gasoline Program Credits – The final rule on Tier 2 motor vehicle emissions 

standards and sulfur control requirements for passenger cars, light trucks, and medium-duty cars 

including SUVs and minivans rated between 8,500 and 10,000 pounds, was published on February 10, 

2000 (65 FR 6698). As with the NLEV program, MOBILE6 is configured for estimation of credits 

derived from the Tier 2 program beginning with calendar year 2004 and later. 

(2) Nonroad Source Controls - Nonroad source controls that reduced NOx and VOC emissions in the 

BRNA included four federal off-road measures. These measures regulated diesel engines, recreational and 

commercial marine vessels, and locomotives. Following is a summary of these federal measures:

(a) Nonroad Diesel Engines - The final rule on control of emissions from nonroad diesel engines was 

published on October 23, 1998 (63 FR 205). The rule was established to reduce emissions from nonroad 

diesel engines and equipment by establishing stringent new emissions standards and requirements to 

ensure that engines maintain their level of emission performance as they age, to provide compliance 

flexibility to engine and equipment manufacturers, and to establish a voluntary program to encourage the 

introduction of low-emitting engines. 

(b) Marine Spark-Ignition Engines – The final rule for control of emissions from new, gasoline, sparkignition marine engines was published on October 4, 1996 (61 FR 194). The rule established, beginning 

in 1998, more stringent standards for manufacture of engines used in outboards, personal watercraft, and 

jet boats. 

(c) Marine Compression-Ignition Engines - The final rule for control of emissions from new, 

compression-ignition, marine diesel engines, equal to or greater than 37 kilowatts, was published on 

December 29, 1999 (64 FR 249). The rule sets emission standards for engines and takes effect between 

2004 and 2007, depending on engine size. 

(d) Locomotives and Locomotive Engines - The final rule for control of emissions from locomotives 

and locomotive engines was published on April 16, 1998 (63 FR 73). The rule sets emission standards for 

engines and includes a variety of compliance and enforcement provisions and regulations concerning the 

preemption of certain state and local controls for locomotives. 

 

 

 3. Project the 2008 RFP Milestone Year Emissions 

The 2008 milestone year for BRNA projections are summarized in Table C-3. Each category includes 

both growth from 2002 to 2008 and controls. 

564
 Table C-3: 2008 RFP Milestone Year Emissions 

Source Category NOx, TPD VOC, TPD

Point Source (1) 71.2 34.2

Area/w Nonroad Source (Tables B-1 plus C-2) 43.0 48.4

Mobile Source (Tables B-1 plus C-2) 29.6 18.7

Total Projected Emissions 143.8 101.3

(1) From 2007 EI, no growth to 2008 

D. Demonstration of Compliance with RFP Requirements 

The EPA Phase II 1997 Eight-Hour Ozone Implementation Rule requires all ozone nonattainment areas 

classified as moderate to reduce NOx and/or VOC emissions by 15% for the period 2002 through 2008. In 

addition to the 15%, the required reductions must also offset growth and vehicle fleet turnover. To 

demonstrate compliance with these requirements, the states are to compare the calculated 2008 Target 

Level of Emissions to the 2008 Projected Milestone Year Emissions after controls are applied. If the 

Projected Milestone Year Emissions are less than the Target Level of Emissions, the requirements are 

satisfied. 

BRNA chose to demonstrate compliance with RFP requirements with NOx reductions. Table D-1 shows 

that the requirements are met. 

 

 Table D-1: RFP Demonstration for 2008 

Description NOx, TPD VOC TPD 

Target Level of Emissions for 2008 (Table B-3) 164.3 103.5

Projected 2008 RFP Milestone Year Emissions (Table C-3) 143.8 101.3

Are Milestone Year Emissions less than Target Level of Emissions? Yes Yes 

Excess 20.5 2.2

E. Contingency Plan 

In case of a milestone year attainment failure, the states are required to have a contingency plan that 

reduces emissions by an additional 3% between the 2008 RFP milestone year and the next calendar year. 

EPA guidance allows that controlled emission reductions not previously used in the 2008 RFP milestone 

demonstration may be used to satisfy contingency requirements. Because the excess emission reductions 

from the 2008 RFP demonstration are greater than the reductions required for 2009 contingency, the 2009 

contingency plan for BRNA does not require any additional controls. A summary of the estimated control 

reductions and the required contingency level of reductions is presented in Table E-1. 

 

 

Table E-1: RFP Contingency Demonstration 

Description NOx, TPD VOC, TPD

Adjusted 2008 Base Year (Section B.4) 193.9 103.5

Required % Contingency 3% NA

Required Contingency Reductions in 2009 5.8 NA

Excess from 2008 RFP Demonstration (Table D-1) 20.5 2.2

Is excess greater than required contingency reductions? Yes Yes

Contingency Excess 14.7 2.2

565
Section 3 Appendix 

Calculation of FMVCP/RVP Reductions 

Point Sources by Facility 

Calculation of Area Source Growth 

Calculation of Nonroad Source Growth 

Calculation of Mobile Source Growth 

566
Appendix - Calculation of FMVCP/RVP Reductions

2002 2002 2008 FMVCP 2002 2002 2008 FMVCP

Parish Actual (1) Adjusted (2) w/2002 VMT (3) Reduction (4) Actual (1) Adjusted (2) w/2002 VMT (3) Reduction (4)

Ascension 7.5 8.4 7.3 1.1 3.8 4.2 3.6 0.6

E Baton Rouge 18.9 21.5 19.1 2.4 13.9 15.2 12.9 2.3

Iberville 4.5 5.1 4.3 0.8 2.0 2.2 1.8 0.4

Livingston 8.9 9.9 8.6 1.3 4.4 4.8 4.1 0.7

W Baton Rouge 5.5 6.1 5.3 0.8 2.4 2.6 2.2 0.4

Totals 45.3 51.0 44.6 6.4 26.5 29.0 24.6 4.4

Notes:

(1) Peak Ozone Season, RVP 7.8, 2002 VMT, 2002 Emission Factors

(2) Peak Ozone Season, RVP 7.8, 2002 VMT, 2002 Emission Factors, CAA Disabled

(3) Peak Ozone Season, RVP 7.8, 2002 VMT, 2008 Emission Factors, CAA Disabled

(4) = (2) - (3)

Factors projected from MOBILE6.2.03.

The adjustments are due to FMVCP only since the RVP is constant from 2002 to 2008.

NOx Mobile Emissions, TPD VOC Mobile Emissions, TPD

Ozone Season Weekday Emissions, 2002 - 2008

567
Appendix - Point Sources by Facility

Parish AI # Facility VOC NOx VOC NOx

0180 529 UNIVAR USA, INC/GEISMAR 2.0 0.0 3.0 0.9

0180 1093 CROMPTON INC/MONOCHEM 10.0 392.0 5.6 158.7

0180 1136 SHELL CHEMICAL LP/GEISMAR PLNT 510.0 739.0 537.8 684.8

0180 1138 GEISMAR VINYLS CO, LP 115.0 130.0 110.2 42.8

0180 1433 CROMPTON MFG CO INC/GEISMAR PLANT 801.0 100.0 626.2 13.0

0180 1468 RUBICON, INC. 236.0 590.0 178.9 422.5

0180 2049 BASF CORPORATION/GEISMAR SITE 268.0 671.0 255.3 822.9

0180 2082 HONEYWELL INTL INC/GEISMAR WRKS 24.0 49.0 56.0 79.5

0180 2218 PRAXAIR INC/GEISMAR 19.0 199.0 33.5 216.3

0180 2245 TRIAD NITROGEN LLC 66.0 2368.0 0.6 6.2

0180 2398 TRIAD NITROGEN, LLC/MELAMINE CHEMICALS 6.0 2.0 0.0 0.0

0180 2416 CF INDUSTRIES, INC./DONALDSONVILLE NITROGEN 228.0 3429.0 199.4 2894.5

0180 2679 AIR PRODUCTS & CHEMICALS,INC/GEISMAR SYNGAS 3.0 56.0 4.2 62.2

0180 3302 EL PASO FLD SRVCS CO/RIVERSIDE 94.0 288.0 91.8 171.3

0180 3400 VULCAN CHEMICALS 262.0 1286.0 41.7 212.6

0180 3420 ORMET CORP/ALUMINA PLANT 0.0 6.0 0.0 0.0

0180 3732 PCS NITROGEN FERTILIZER,L.P./GEISMAR 50.0 1329.0 19.2 430.5

0180 3990 WAGNER OIL CO CO/DARROW COMM LEASE 36.0 0.0 0.0 0.0

0180 4762 ENTERPRISE GAS PROC LLC/TEBONE FRAC PLNT 107.0 49.0 174.5 39.2

0180 4803 BFI WASTE SYSTEMS OF N.A.,INC/COLONIAL LANDFILL 12.0 11.0 8.5 9.9

0180 5565 WILLIAMS OLEFINS LLC/GEISMAR ETHYLENE 278.0 703.0 246.3 640.4

0180 8142 WAGNER OIL CO/DARROW GRC BATTERY 70.0 41.0 11.4 5.0

0180 11416 BRIDGELINE HOLDINGS LP/SORRENTO UNDERGROUND GAS SF 11.0 44.0 17.1 30.2

0180 17771 T T BARGE CLEANING INC/MILE 183 7.1 1.8 11.8 1.0

0180 20506 ENTERPRISE PRODUCTS CO/SORRENTO PHT 29.0 3.0 27.7 2.8

0180 26272 DSI TRANSPORTS, INC 13.0 1.0 29.8 0.9

0180 27834 EXXONMOBIL PIPELINE CO/SORRENTO STORAGE 37.0 2.0 37.3 1.2

0180 30073 AIR PRODUCTS & CHEMICALS,INC/DINITROTOLUENE 5.0 25.0 5.1 29.2

0180 31513 AIR LIQUIDE AMERICA CORP/GEISMAR 3.0 269.0 20.2 106.2

0180 31514 GABRIEL CHEMICALS LLC/CHLOROSULFONIC ACID PLANT 0.0 0.0 0.0 0.0

0180 33564 Cooper T Smith Stevedoring Co - America Weigh Rig Loading & Transfer Facilityna na 0.8 29.2

0180 33579 Cooper T Smith Stevedoring Co - Floating Grain Elevator Rig #1 na na 0.0 0.0

0180 39945 ORMET CORP/BURNSIDE BULK MARINE TERMINAL 7.0 89.0 0.8 9.0

0180 41417 SHELL PIPELINE CO LP/SORRENTO DOME STORAGE 6.0 2.0 188.0 1.6

0180 46968 Mid-America Resources Corp - Sorrento Field Production Facility na na 2.4 0.2

0180 67572 DUPONT CHEMICALS/BURNSIDE PLANT 2.0 55.0 2.0 55.1

0180 83718 GULF LIQUIDS NEW RIVER PROJECT LLC/GEISMAR GAS PLNT 24.8 44.0 31.7 54.5

0180 86181 TEXACO PIPELINES LLC/SORRENTO TENDS PUMP STN 15.0 0.0 12.8 0.0

0180 88164 ENTERPRISE PROD OPER LP/SORRENTO RAIL RACK 1.0 0.0 5.9 0.2

0180 90203 EOTT ENERGY OPER LP/DARROW CRUDE OIL TERM 0.0 0.0 0.0 0.0

0180 92534 BORDEN CHEM INC/FORMALDEHYDE TRAINS & METHANOL TANK FARM 41.0 3.0 56.1 0.8

0180 97675 CHEMTECH CHEMICALS/CHEMICAL BLENDING 0.0 0.0 0.5 0.0

0180 99129 BURLINGTON RESOURCES O&G/UNITED LANDS #1 4.0 1.0 3.8 0.5

0180 100581 WILLIAMS OLEFINS LLC/HC BARGE LOAD 13.0 0.0 0.0 0.0

0180 100651 GULF LIQUIDS NEW RIVER PROJECT/SORRENTO GAS PLANT 5.5 0.2 12.1 1.7

0180 122402 IMTT - Geismar na na 0.0 0.0

0180 143528 State Lease 17446 Tank Battery - Darrow Field na na 7.9 0.0

0180 143529 SL 17446 Well - Darrow Field na na 2.4 0.3

0180 145270 Sorrento Production Facility na na 3.5 0.1

0840 248 DELTECH CORPORATION 28.0 256.0 38.5 90.8

0840 285 EXXONMOBIL CHEM/BR PLASTICS PLNT 532.0 108.0 199.2 117.2

0840 286 EXXONMOBIL CHEM CO/BR CHEM PLT 1708.0 2486.0 1510.2 2166.6

0840 288 FORMOSA PLASTICS CORPORATION, LA 44.0 570.0 80.7 253.0

0840 289 HONEYWELL/BATON ROUGE PLNT 242.0 21.0 269.1 16.4

0840 332 EXXONMOBIL/B R MARKETING TERM 36.0 0.0 32.4 0.0

0840 582 PLANTATION PIPELINE CO/BR TANK FARM 1787.0 0.0 634.5 0.0

0840 669 ALBEMARLE CORP. 31.0 11.0 27.0 9.6

0840 1000 ASHLAND CHEM CO/B.R. DISTRIBUTION 6.9 0.0 5.8 0.0

0840 1157 STUPP CORP/BAKER 5.0 0.0 8.0 0.0

0840 1186 ENTERGY GSI/LA STN 2 0.0 0.0 0.0 0.0

0840 1186 ENTERGY/LA STATION 1 51.0 1833.0 52.0 1676.0

0840 1314 RHODIA INC/BR FAC 66.0 74.0 30.5 69.9

0840 1395 DSM COPOLYMER/BR PLANT 78.0 127.0 76.9 197.2

0840 1396 EXIDE TECHNOLOGIES/B R SMELTER 0.0 9.0 1.1 15.7

0840 1413 UOP LLC/BR PLNT 2.0 46.0 2.8 35.0

0840 1516 CLEAN HARBORS BATON ROUGE, LLC 7.0 0.0 0.5 0.0

0840 2617 GEORGIA PACIFIC/PT HUDSON OPERATNS 334.0 1916.0 629.1 1681.6

2002 (TPY) 2007 (TPY)

568
Appendix - Point Sources by Facility

Parish AI # Facility VOC NOx VOC NOx

0180 529 UNIVAR USA, INC/GEISMAR 2.0 0.0 3.0 0.9

2002 (TPY) 2007 (TPY)

0840 2638 EXXONMOBIL REF & SUPPLY CO/B R REFINERY 1659.0 3583.0 1545.0 2018.5

0840 3085 ETHYL CORPORATION 1.2 0.0 4.9 0.0

0840 3230 EXXONMOBIL CHEM CO/RESIN FINSHNG PLT 14.0 16.0 22.1 14.8

0840 3387 FERRO CORPORATION/BATON ROUGE SITE 18.0 8.0 13.4 8.5

0840 3519 EXXONMOBIL CHEM CO/B.R. POLYOLEFINS 101.0 105.0 82.5 111.3

0840 3587 PPG IND INC/GROW AUTOMOTIVE 3.0 0.0 1.7 0.0

0840 4407 EBR Parish Renewable Energy Center na na 1.7 0.0

0840 4993 BP AMERICA PROD/PT HUDSON GAS PLNT 52.0 20.0 3.5 0.7

0840 5190 ALLWASTE CONTAINER SVCS/BATON ROUGE PLANT 0.0 2.0 1.0 2.0

0840 5540 LOUISIANA STATE UNIVERSITY 6.4 133.4 6.4 124.5

0840 8007 FLORIDA GAS TRANSMISSION CO/ZACHARY COMP STN 73.0 940.0 71.7 363.9

0840 11595 FLOWERS BAKING CO OF BATON ROUGE LLC 41.4 1.5 51.2 1.8

0840 17129 HILCORP ENERGY CO/COMITE FIELD FACILITY 9.0 9.0 25.0 7.0

0840 22750 EDO SPECIALTY PLASTICS 13.0 0.0 16.8 0.0

0840 25383 LAMAR CORP/ LAMAR GRAPHICS 20.0 0.0 38.4 0.0

0840 27559 BAYOU COATING LLC 2.0 2.0 27.2 6.2

0840 29884 GREAT LAKES CARBON CORP/B R CALCINED COKE PLT 8.5 380.0 5.5 361.9

0840 31128 East Baton Rouge Parish Landfill (BFI North) na na 4.2 5.5

0840 32045 VINTAGE PETROLEUM INC/MANCHAC POINT 85.0 19.0 16.0 22.0

0840 32050 SCHERING-PLOUGH ANIMAL HEALTH CORP/VET OPERATIONS 2.1 0.7 0.0 0.0

0840 32056 EXXON MOBIL CORP/EMPR 7.0 4.0 5.0 1.3

0840 88139 BP AMERICA PROD/PT HUDSON CTB 30.0 14.0 21.4 12.2

0840 90176 B P PIPELINES NORTH AMERICA/PT HUDSON TERMINAL 40.7 0.0 0.0 0.0

0840 95859 University Field Production Facility na na 28.2 9.6

0840 96336 US Composite Pipe South LLC - Baton Rouge Plant na na 5.5 4.6

0840 98136 HILCORP ENERGY CO/COBB #1 COMITE FIELD 1.0 35.0 0.0 0.0

0840 114658 Siegen Production Facility - Siegen Field na na 32.0 9.5

0840 114659 Port Hudson Field Production Facility na na 34.2 0.2

0840 119007 Duplantier Tank Battery - University Field na na 10.0 24.0

0840 119008 Nelson Tank Battery - University Field na na 24.0 18.0

0840 138716 North Burtville Field Facility - North Burtville Field na na 16.9 8.4

0840 144826 Crown Paper #1 Production Facility - Profit Island Field na na 14.8 7.5

0840 146877 Crown Paper #1 Treating Facility - Profit Island Field na na 5.2 13.5

1280 1306 CORA TEXAS MFG INC/SUGAR MILL 14.0 215.0 14.0 221.0

1280 1409 DOW CHEMICAL CO/LA OPERATIONS 1270.0 8611.0 1404.4 4582.7

1280 1607 ATOFINA PETROCHEMICALS INC/COSMAR STYRENE PLNT 98.0 682.0 121.7 373.7

1280 2043 WILLIAMS FIELD SERVICES/CHOCTAW TERMINAL 18.0 12.0 18.2 10.6

1280 2367 SYNGENTA CROP PROTECTION INC/ST. GABRIEL PLANT 257.0 215.0 215.1 231.9

1280 2455 GEORGIA GULF CHEM & VINYLS LLC/PLAQUEMINE 139.0 1265.0 170.4 1181.4

1280 2625 ENTERGY GSI/WILLOW GLEN 103.0 2437.0 10.0 208.0

1280 2644 PIONEER AMERICAS INC 0.3 16.7 1.6 26.0

1280 3129 ASHLAND CHEMICAL CO/PLAQUEMINE METHANOL PLNT 0.0 0.3 0.0 0.0

1280 3263 AIR PRODUCTS & CHEMICALS,INC/ST. GABRIEL 12.0 64.0 37.6 73.6

1280 3492 LBC BATON ROUGE LLC/SUNSHINE TERM 58.0 1.0 104.1 3.3

1280 4197 SOUTHERN NATURAL GAS/WHITE CASTLE CS 20.0 404.0 65.5 174.8

1280 5176 ATOFINA PETROCHEM INC/CARVILLE POLYSTYRENE 4.0 33.0 17.6 22.1

1280 7359 TEXAS EASTERN TRANSMISSION, LP/WHITE CASTLE CS 3.0 180.0 1.7 0.0

1280 8055 State of Louisiana Military - Gillis W Long Center na na 0.9 14.1

1280 8056 Plaquemine Point Shipyard na na 16.2 6.0

1280 8072 GRUY PETROLEUM MGMT CO/BAYOU BOUILLON PF 15.0 60.0 0.0 0.0

1280 14139 PLAINS MARKETING LP/ST GABRIEL TERMINAL 12.0 0.0 12.1 0.0

1280 14535 INEOS FLUOR AMERICAS LLC/KLEA-134A PLANT 1.9 15.6 2.5 14.9

1280 17383 LA INTRASTATE GAS CO./MYRTLE GROVE C.S. 10.0 19.0 24.8 11.6

1280 19184 LIG LIQUIDS CO LLC/PLAQUEMINE GAS 5.0 151.0 46.6 117.3

1280 20411 TEXAS PETRO INVESTMENT CO/BAYOU BLEU FLD PROD 69.0 113.0 19.9 60.4

1280 24479 SCS Iberville Coatings Inc na na 2.3 1.5

1280 26034 LA ENERGY & POWER AUTHORITY/PLAQUEMINE STEAM & DIESEL PWR PLT 0.0 1.1 0.0 0.3

1280 26984 CIBA SPECIALTY/ST. GABRIEL PLANT 5.0 4.0 3.0 1.5

1280 27495 BIOPRODUCTS OF LA LLC/GULF COAST 15.4 1.7 0.1 0.1

1280 32133 G & A INTERNATIONAL/BAYOU SORREL 23.0 43.0 22.8 19.5

1280 32135 JP OIL CO/WHITE CASTLE FLD 37.0 37.0 39.1 23.3

1280 32141 BRIDGELINE HOLDINGS LP/TALLY HO CS 1.0 1.0 0.2 0.2

1280 32145 HILCORP ENERGY CO/NW BAYOU CHOCTAW 47.0 16.0 3.6 2.9

1280 32146 BLIGH PETROLEUM INC/BAYOU CHOCTAW FLD PROD FAC 8.4 32.8 0.0 0.0

1280 32154 JP OIL CO/GRAND RIVER 0.0 0.0 0.0 0.0

1280 32160 Bayou Bleu Field Production Facility na na 9.8 25.7

1280 32161 OLEUM OPERATING CO, LC/BYU HENRY FLD PF 8.3 14.6 8.2 14.5

1280 33667 Basic Industries Inc - Sandblast & Spray Paint Yard na na 9.9 7.0

1280 39633 Command Services Inc na na 38.6 23.4

569
Appendix - Point Sources by Facility

Parish AI # Facility VOC NOx VOC NOx

0180 529 UNIVAR USA, INC/GEISMAR 2.0 0.0 3.0 0.9

2002 (TPY) 2007 (TPY)

1280 39978 KINDER MORGAN LIQUIDS TERMINAL LLC/ST GABRIEL TERMINAL 18.3 0.0 12.7 0.5

1280 40037 NOBLE ENERGY INC/STATE LEASE 14371 3.0 0.0 3.0 0.5

1280 51854 CARVILLE ENERGY LLC/CARVILLE ENERGY CENTER 2.0 18.0 1.2 347.2

1280 84377 OLEUM OPERATING CO, LC/BAYOU DES GLAISES-WILBERT MINERAL B LEASE 7.4 30.0 0.0 0.0

1280 84483 HILCORP ENERGY CO/FROG LAKE 14.0 29.0 0.0 0.0

1280 85393 PETRO HUNT LLC/BYU HENRY CTL FAC 36.0 48.0 14.0 0.0

1280 85652 AEP CORP/VENTURES LEASE CO/PLAQUEMINE COGEN 0.0 0.0 0.0 0.0

1280 86585 SHELL PIPELINE CO LP/GRAND RIVER BARGE LOADING 2.0 0.0 0.0 0.0

1280 89237 INEOS LLC/INEOS OXIDE 12.0 0.0 0.0 0.0

1280 89512 E&E PRODUCTION CO/DUGAS & LEBLANC LTD ET AL #1 3.0 0.0 20.6 5.0

1280 90197 EOTT ENERGY PIPELINE LP/BAYOU BLUE CRUDE OIL TERM 0.0 0.0 0.0 0.0

1280 101588 PETROQUEST ENERGY LLC/EEX CORP PF #1 20.0 11.0 30.2 10.9

1280 113166 Bayou Bouillon Production Facility na na 11.7 11.9

1280 118389 Bayou Bleu - Central Facility #1 na na 10.1 7.3

1280 119219 White Castle Deep Production Facility na na 32.1 3.7

1280 128487 Dent et al #1 Production Facility - Musson Field na na 16.3 0.8

1280 126578 Shintech Louisiana LLC - Plaquemine PVC Plant na na 0.0 0.0

1280 126748 Schwing 10 Production Facility - Frog Lake Field na na 14.2 2.7

1280 126750 Dow Chemical Co Production Facility - Frog Lake Field na na 8.3 7.8

1280 128638 Forest Home Partnership Facility na na 15.5 22.8

1280 134264 Gueymard Production Facility - St Gabriel Field na na 16.3 17.4

1280 138856 St Gabriel Dehy & NGL Production Facility na na 15.9 0.2

1280 139760 Bayou Bouillion etal #1 Production Facility na na 0.0 0.0

1740 1467 EAST JORDAN IRON WORKS 3.0 14.0 2.1 4.9

1740 4990 BP AMERICA PROD/LOCKHART CROSSING CF # 1 12.0 38.0 10.6 12.9

1740 6858 GRIFFIN INDUSTRIES, INC 0.0 1.0 0.0 0.6

1740 9154 THE SHAW GROUP/SUNLAND FABRICATORS 14.0 0.0 67.7 15.5

1740 11767 WASTE MANAGEMENT OF LA, LLC/WOODSIDE LANDFILL 37.0 12.0 4.0 8.9

1740 17042 DENBURY RESOURCES INC/LOCKHART CROSS WILCOX CF3 121.0 125.0 24.9 10.2

1740 19875 WEYERHAEUSER CO/HOLDEN SAWMILL & LOG PROCESS 219.0 22.0 223.9 19.4

1740 26884 PLAINS MARKETING LP/LOCKHART CROSSING 5.0 0.0 0.0 0.0

1740 32465 TMR EXPLORATION INC/ LVG WXI RA SU LB 19.6 0.2 25.0 1.1

1740 32466 Erva S Mayers # 1 na na 0.0 0.0

1740 80537 DELTA ENVIRONMENTAL PRODUCTS,INC 20.8 0.0 19.8 1.5

1740 99952 O M Barnett #2 Facility - Lockhart Crossing Field na na 0.8 0.0

1740 120886 SL 7729 #2 Wellsite - Lockhart Crossing Field na na 1.9 0.0

1740 130526 Blind River Facility (SL 18562 #1 Well) - Blind River Field Block 16 na na 0.0 0.0

1740 146741 Lockhart Crossing Central Processing Faciity na na 0.0 0.0

3120 302 T.T. BARGE SERVICE MILE 237, LLC/BR SHIPYARD 34.8 7.8 12.6 3.3

3120 858 EXXONMOBIL REF & SUPPLY CO/ANCHORAGE TNK FRM 32.0 0.0 25.2 2.5

3120 1648 CASTROL CONSUMER N AMER AUTO INC /PT ALLEN 16.5 3.3 17.4 7.6

3120 2366 PLACID REFINING CO LLC/PT ALLEN 204.0 967.0 240.7 743.9

3120 2519 DSM COPOLYMER/ADDIS PLANT 493.0 163.0 0.0 0.0

3120 2937 Shaw SS&S Fabricators Inc - Addis Facility na na 5.3 9.5

3120 3473 SHINTECH LOUISIANA LLC/ADDIS PLANT B 1.0 5.0 0.0 0.0

3120 4056 HARRY L. LAWS & CO,INC/CINCLARE CENTRAL FACTORY 10.0 121.0 0.0 0.0

3120 4174 SID RICHARDSON CARBON CO/ADDIS PLT 307.0 220.0 99.0 326.9

3120 9495 DISCOVERY ALUMINAS,INC/ALCOA PORT ALLEN WORKS 35.0 30.0 52.5 30.6

3120 11059 Specialty Application Services Inc - Port Allen Facility na na 7.6 4.8

3120 12096 Westway Terminal Co Inc na na 0.1 0.3

3120 17161 EXXONMOBIL PROD CO/BR GAS PLANT 26.0 114.0 17.9 63.8

3120 19338 PETROLEUM FUEL & TERM/PORT ALLEN 0.0 2.0 0.0 0.0

3120 19556 INTERCONTINENTAL TERMINALS CO/ANCHORAGE CHEM TERM 1.8 0.3 0.0 0.0

3120 25344 Criterion Catalysts & Technologies LP - HPA Port Allen Plant na na 8.1 7.7

3120 26217 INTL PAINTING CORP 35.0 0.0 29.8 0.0

3120 40198 B R FRACTIONATORS/PLT 1 21.0 42.0 18.8 60.7

3120 43634 TRINITY MARINE PRODUCTS INC/PLANT 48 14.0 4.0 9.5 0.2

3120 83425 SHINTECH LOUISIANA, LLC/ADDIS PLANT A 31.0 34.0 42.5 32.2

3120 98796 EXXONMOBIL PIPELINE CO/ANCHORAGE TERMINAL 8.0 0.0 11.2 0.1

3120 126510 Bueche Heirs Well #1 Facility SN 228905 - Profit Island Oil Field na na 10.8 8.1

3120 139063 Oliver #1 Tank Battery - Profit Island Field na na 21.5 7.9

Column Total 14660.0 42415.0 12492.8 26000.4

1. 2002 emissions from "2002 Base Year Emissions Inventory for the Baton Rouge Nonattainment Area" dated June 2007

2. 2007 emissions from LDEQ ERIC database.

570
Appendix - Calculation of Area Source Growth

Growth Factor

SCC Description NOx (TPD) VOC (TPD) 02 - 08 NOx (TPD) VOC (TPD) NOx (TPD) VOC (TPD)

2103006000 Commercial/Institution - Natural Gas 0.21 0.01 1.0971 0.23 0.01 0.02 0.00

2104006000 Residential - Natural Gas 0.79 0.05 1.0507 0.83 0.05 0.04 0.00

2104007000 Residential - LPG 0.06 0.00 1.0260 0.06 0.00 0.00 0.00

2104008000 Residential-Wood Fireplaces 0.04 1.24 1.0012 0.04 1.24 0.00 0.00

2104008010 Residential-Woodstoves - General 0.03 0.56 1.0012 0.03 0.56 0.00 0.00

2104008050 Residential-Woodstoves - Non-Catalytic 0.01 1.0012 0.01 0.00

2302002100 Commercial Cooking - Conveyorized Charbroiling 0.01 1.1251 0.01 0.00

2302002200 Commercial Cooking - Underfired Charbroiling 0.04 1.1251 0.05 0.01

2302003000 Commercial Cooking - Deep Fat Frying 0.01 1.1251 0.01 0.00

2302003100 Commercial Cooking - Flat Griddle Frying 0.01 1.1251 0.01 0.00

2401001000 Surface Coatings - Architectural Coatings 2.77 1.0880 3.01 0.24

2401005000 Surface Coatings - Auto Refinishing: SIC 7532 0.83 1.1390 0.95 0.12

2401008000 Surface Coatings - Traffic Markers 0.15 1.0448 0.16 0.01

2401015000 Surface Coatings - Factory Finished Wood 0.02 1.2328 0.02 0.00

2401025000 Surface Coatings - Metal Furniture: SIC 25 0.02 1.4386 0.03 0.01

2401040000 Surface Coatings - Metal Cans: SIC 341 0.03 1.2763 0.04 0.01

2401050000 Surface Coatings - Miscellaneous Finished Metals 4.50 1.2763 5.74 1.24

2401055000 Surface Coatings - Machinery and Equipment 0.06 1.4077 0.08 0.02

2401065000 Surface Coatings - Electronic and Other: SIC 36-363 0.04 1.3941 0.06 0.02

2401070000 Surface Coatings - Motor Vehicles: SIC 371 0.04 1.3117 0.05 0.01

2401080000 Surface Coatings - Marine: SIC 373 1.30 1.2909 1.68 0.38

2401090000 Surface Coatings - Miscellaneous Manufacturing 0.18 1.2407 0.22 0.04

2401100000 Surface Coatings - Industrial Maintenance Coatings 0.24 1.2328 0.30 0.06

2401200000 Surface Coatings - Other Special Purpose Coatings 0.23 1.0285 0.24 0.01

2415000000 Degreasing - All Processes, All Industries 1.14 1.2764 1.46 0.32

2420000000 Dry Cleaning - All Processes 0.88 1.1177 0.98 0.10

2425000000 Graphic Arts - All Processes 0.42 1.0754 0.45 0.03

2460100000 Consumer and Commercial Products - Personal Care 1.81 1.0094 1.83 0.02

2426020000 Consumer and Commercial Products - Household 0.62 1.0094 0.63 0.01

2460400000 Consumer and Commercial Products - Automotive 1.10 1.0094 1.11 0.01

2460500000 Consumer and Commercial Products - All Coatings 0.84 1.0094 0.85 0.01

2460600000 Consumer and Commercial Products - All Adhesives 0.46 1.0094 0.46 0.00

2460800000 Consumer and Commercial Products - FIFRA Related 1.50 1.0094 1.51 0.01

2460900000 Consumer and Commercial Products - Miscellaneous 0.06 1.0094 0.06 0.00

2461021000 Commercial - Cutback Asphalt 0.43 1.2986 0.56 0.13

2461850000 Commercial - Pesticide Application 0.01 1.0494 0.01 0.00

2002 08 Estimated Emissions Growth

AREA SOURCE - OZONE SEASON WEEKDAY EMISSIONS

571
Appendix - Calculation of Area Source Growth

Growth Factor

SCC Description NOx (TPD) VOC (TPD) 02 - 08 NOx (TPD) VOC (TPD) NOx (TPD) VOC (TPD)

2002 08 Estimated Emissions Growth

AREA SOURCE - OZONE SEASON WEEKDAY EMISSIONS

2501060050 Gas Service Stations - Stage 1:Total 0.19 1.0448 0.20 0.01

2501060052 Gas Service Stations - Stage 1:Splash Filling 0.45 1.0448 0.47 0.02

2501060053 Gas Service Stations - Stage 1:Submerged Filling 0.02 1.0448 0.02 0.00

2501060201 Gas Service Stations - UST: Breathing and Emptying 0.96 1.0448 1.00 0.04

2501080050 Airports Aviation Fuel - Stage 1:Total 0.19 1.3117 0.25 0.06

2501080100 Airports Aviation Fuel - Stage 2:Total 0.01 1.3117 0.01 0.00

2505000120 Petroleum Transport - All Transport Types 0.03 1.0448 0.03 0.00

2505030120 Petroleum Transport - Trucks 0.13 1.0448 0.14 0.01

2601000000 Onsite Incineration - All Categories 0.24 0.24 1.0094 0.24 0.24 0.00 0.00

2601020000 Onsite Incineration - Commercial/Institutional 0.42 0.42 1.2986 0.55 0.55 0.13 0.13

2610000100 Open Burning - Yard Waste: Leaves 0.03 1.0094 0.03 0.00

2610000400 Open Burning - Yard Waste: Brush 0.02 1.0094 0.02 0.00

2610000500 Open Burning - Land Clearing: Debris 0.51 1.17 1.0094 0.51 1.18 0.00 0.01

2610030000 Open Burning - Residential 0.14 0.70 1.0094 0.14 0.71 0.00 0.01

2620030000 Landfill - Municipal 0.01 0.06 1.2796 0.01 0.08 0.00 0.02

2630020000 Wastewater Treatment - Publicly Owned - 0.40 1.0717 0.43 0.03

2801500170 Agricultural Burning - Whole Field on Fire:Grass 0.00 0.01 1.0494 0.00 0.01 0.00 0.00

2801500250 Agricultural Burning - Whole Field on Fire:Sugarcane 1.23 2.45 1.0494 1.29 2.57 0.06 0.12

2801500261 Agricultural Burning-Whole Field on Fire:Wheat Headfire 0.03 0.05 1.0494 0.03 0.05 0.00 0.00

2801500262 Agricultural Burning-Whole Field on Fire:Wheat Backfire 0.01 0.02 1.0494 0.01 0.02 0.00 0.00

2810001000 Other Combustion - Forest Wildfires 0.17 0.38 1.0094 0.17 0.38 0.00 0.00

2810015000 Other Combustion-Prescribed Burning:Forest Management 0.03 0.37 1.0094 0.03 0.37 0.00 0.00

2810030000 Other Combustion - Structure Fires 0.00 0.02 1.1809 0.00 0.02 0.00 0.00

Column Total 3.92 29.94 4.18 33.23 0.26 3.29

1. 2002 Emissions from "2002 Base Year Emissions Inventory for the Baton Rouge Nonattainment Area" dated June 2007

2. Growth factors from EGAS 5.0

3. SCC Classifications with no estimated emissions are blank.

572
Appendix - Calculation of Nonroad Source Growth

Growth Factor

SCC Description NOx (TPD) VOC (TPD) 02 - 08 NOx (TPD) VOC (TPD) NOx (TPD) VOC (TPD)

2260000000 Gasoline except Rail and Marine - 2 Stroke

2260001010 Recreational Equipment - Motorcycles:Offroad 0.00 0.72 1.0143 0.00 0.73 0.00 0.01

2260001030 Recreational Equipment - All Terrain Vehicles 0.00 0.71 1.0143 0.00 0.72 0.00 0.01

2260002000 Construction & Mining, Total 0.00 0.30 1.0143 0.00 0.30 0.00 0.00

2260004000 Lawn & Garden, All 0.00 1.49 1.0143 0.00 1.51 0.00 0.02

2260006000 Commercial Equipment 0.00 0.13 1.0143 0.00 0.13 0.00 0.00

2260007005 Logging Equipment - Chain Saws, >6HP 0.00 0.06 1.0143 0.00 0.06 0.00 0.00

2265000000 Gasoline except Rail and Marine - 4 Stroke

2265001010 Recreational Eguipment - Motorcycles:Off-Road 0.00 0.02 1.0143 0.00 0.02 0.00 0.00

2265001030 Recreational Eguipment - All Terrain Vehicles 0.02 0.18 1.0143 0.02 0.18 0.00 0.00

2265001050 Recreational Eguipment - Golf Carts 0.00 0.01 1.0143 0.00 0.01 0.00 0.00

2265002000 Construction & Mining, Total 0.02 0.16 1.0143 0.02 0.16 0.00 0.00

2265003000 Industrial Equipment, All 0.08 0.06 1.0143 0.08 0.06 0.00 0.00

2265004000 Lawn & Garden, All 0.24 1.29 1.0143 0.24 1.31 0.00 0.02

2265006000 Commercial Equipment 0.17 0.71 1.0143 0.17 0.72 0.00 0.01

2265007010 Logging Equipment - Shredders >6Hp 0.00 0.02 1.0143 0.00 0.02 0.00 0.00

2265010010 Industrial Equipment - Oil Field Equipment 0.01 0.03 1.0143 0.01 0.03 0.00 0.00

2267000000 LPG Equipment except Rail and Marine

2267002000 Construction & Mining, All 0.01 0.00 1.0490 0.01 0.00 0.00 0.00

2267003000 Industrial Equipment, All 0.92 0.23 1.0490 0.97 0.24 0.05 0.01

2267004066 Lawn & Garden Equipment - Chippers/Stump Grinders (Com) 0.01 0.00 1.0490 0.01 0.00 0.00 0.00

2267006000 Commercial Equipment 0.07 0.01 1.0490 0.07 0.01 0.00 0.00

2268000000 CNG Equipment except Rail and Marine

2268003020 Industrial Equipment - Forklifts 0.06 0.00 1.0490 0.06 0.00 0.00 0.00

2268006000 Commercial Equipment 0.07 0.00 1.0490 0.07 0.00 0.00 0.00

2268010010 Industrial Equipment - Oil Field Equipment 0.03 0.16 1.0490 0.03 0.17 0.00 0.01

2270000000 CI Equipment except Rail and Marine - Diesel

2270002000 Construction & Mining, Total 7.66 0.79 1.0143 7.77 0.80 0.11 0.01

2270003000 Industrial Equipment, All 0.53 0.07 1.0143 0.54 0.07 0.01 0.00

2270004000 Lawn & Garden, All 0.10 0.02 1.0143 0.10 0.02 0.00 0.00

2270005000 Agricultural Equipment, All 0.39 0.05 1.0143 0.40 0.05 0.01 0.00

2270006000 Commercial Equipment 0.41 0.07 1.0143 0.42 0.07 0.01 0.00

2270007015 Logging Equipment - Forest Equipment:Feller?Bunch/Skidder 0.13 0.01 1.0143 0.13 0.01 0.00 0.00

2270008005 Airport Ground Support Equipment 0.02 0.00 1.0143 0.02 0.00 0.00 0.00

2270010010 Industrial Equipment - Oil Field Equipment 0.10 0.01 1.0143 0.10 0.01 0.00 0.00

2275020000 Commercial Aircraft 0.13 0.02 1.3117 0.17 0.03 0.04 0.01

2002 08 Estimated Emissions Growth

NONROAD SOURCE - OZONE SEASON WEEKDAY EMISSIONS

1

573
Appendix - Calculation of Nonroad Source Growth

Growth Factor

SCC Description NOx (TPD) VOC (TPD) 02 - 08 NOx (TPD) VOC (TPD) NOx (TPD) VOC (TPD)

2002 08 Estimated Emissions Growth

NONROAD SOURCE - OZONE SEASON WEEKDAY EMISSIONS

2275050000 General Aviation 0.00 0.01 1.3117 0.00 0.01 0.00 0.00

2275060000 Air Taxi 0.00 0.01 1.3117 0.00 0.01 0.00 0.00

2280002100 Commercial Marine Vessels - Diesel:Port Emissions 5.72 0.14 1.0747 6.15 0.15 0.43 0.01

2280002200 Commercial Marine Vessels - Diesel:Underway Emissions 4.10 0.09 1.0747 4.41 0.10 0.31 0.01

2280003100 Commercial Marine Vessels - Residual:Port Emissions 8.95 0.32 1.2214 10.93 0.39 1.98 0.07

2280003200 Commercial Marine Vessels - Residual:Underway Emissions 1.62 0.05 1.2214 1.98 0.06 0.36 0.01

2282000000 Recreational Marine/Pleasure Craft - All Fuels

2282005010 Pleasure Craft - Gasoline, 2-Stroke, Outboard 0.18 5.64 1.0143 0.18 5.72 0.00 0.08

2282005015 Pleasure Craft - Gasoline, 2-Stroke, Personal Water Craft 0.02 0.89 1.0143 0.02 0.90 0.00 0.01

2282010005 Pleasure Craft - Gasoline, 4-Stroke, Inboard/Sterndrive 0.16 0.29 1.0143 0.16 0.29 0.00 0.00

2282020005 Pleasure Craft - Diesel, Inboard/Sterndrive 0.11 0.00 1.0143 0.11 0.00 0.00 0.00

2285002006 Railroad Equipment - Diesel, Line Haul Locomotives 2.42 0.13 1.2017 2.91 0.16 0.49 0.03

2285002010 Railroad Equipment - Diesel, Yard Locomotives 0.44 0.03 1.2017 0.53 0.04 0.09 0.01

2285002015 Railroad Equipment - Diesel, Railway Maintenance 0.02 0.00 1.2017 0.02 0.00 0.00 0.00

Column Total 34.92 14.93 38.82 15.29 3.90 0.36

1. 2002 Emissions from "2002 Base Year Emissions Inventory for the Baton Rouge Nonattainment Area" dated June 2007

2. EGAS 5.0 growth factors for Aircraft, Commercial Marine, and Railroad classifications.

3. Growth for all other categories was projected from EGAS 4.0 factors.

2

574
Appendix - Calculation of Mobile Source Growth

Growth Growth

Parish 2002 (1) 2008 (2) 2002-08 2002 (1) 2008 (2) 2002-08

Ascension 7.5 5.1 -2.4 3.8 3.3 -0.5

E. Baton Rouge 18.9 12.4 -6.5 13.9 9.0 -4.9

Iberville 4.5 3.1 -1.4 2.0 1.5 -0.5

Livingston 8.9 6.1 -2.8 4.4 3.4 -1.0

W. Baton Rouge 5.5 2.9 -2.6 2.4 1.5 -0.9

Total, tpd 45.3 29.6 -15.7 26.5 18.7 -7.8

(1) Peak Ozone Season, RVP 7.8, 2002 VMT and Emission Factors

(2) Peak Ozone Season, RVP 7.8, 2008 VMT and Emission Factors

Growth factors projected from MOBILE6.2.03.

Mobile NOx Emissions Mobile VOC Emissions

MOBILE SOURCE - OZONE SEASON WEEKDAY EMISSIONS

575
SECTION 4 

CONTINGENCY PLAN 

576
577
SECTION 4 

Contingency Plan

Contingency Implementation 

Maintenance plans, under Section 175A of the CAA (Clean Air Act), include contingency 

measures to promptly address any violation of the national ambient air quality standards 

(NAAQS) that occurs. The contingency plan ensures that the contingency measures are adopted 

expeditiously once they are triggered. 

The contingency plan for the ozone maintenance area is triggered upon monitoring a violation of 

the 8-hour ozone standard. Implementation of contingency measures will occur within 24 

months of the triggering event. 

Implementation of the contingency plan involves analysis of data to determine the cause of the 

violation. If, after this analysis is complete, the state determines that the violation was caused by 

events that can be controlled within the state’s jurisdiction through regulatory actions, the state 

will determine the appropriate measures for implementation in the area and implement such 

measures within the 24 month period suggested by EPA guidance. 

Determination of the appropriate contingency measure(s) for implementation will involve the 

following actions: 

Identification of potential sources for emission reductions; 

Identification/evaluation of prospective control measures; 

Initiation of stakeholder process; and 

Implementation of contingency measures through promulgation of appropriate 

control rules adhering to public notice and comment requirement 

Contingency Measures Plan

In this state implementation plan (SIP) revision, LDEQ is submitting a contingency measures 

plan as part of the maintenance plan for the Baton Rouge nonattainment area (BRNA). The 

contingency requirement is three percent of the 2002 adjusted base year inventory. Since EPA 

guidance allows the use of either reductions of volatile organic compounds (VOC), or oxides of 

nitrogen (NOx) to satisfy the contingency requirement, LDEQ has chosen to rely on NOx 

reductions to meet the contingency measures requirement. For satisfying the contingency 

measures requirement LDEQ will extend the applicability of the state’s NOx control rule to 

include the months of April and October of each year. 

Chapter 22 in LAC 33:III, Control of Emissions of Nitrogen Oxides (NOx), that was promulgated 

in February 2002 (LR 28:290), sets emission factors for various categories of equipment in the 

BRNA. The regulation requires controls on boilers, heaters, furnaces, turbines, and internal 

combustion engines. In order to bring the area into attainment, the control requirements were 

selected to be more stringent than reasonably available control technology (RACT) requirements. 

The following table shows the requirements of the rule. 

578
Table 1: Chapter 22 Emission Factors 

Equipment Category Maximum Rated 

Capacity

Chapter 22 

Requirement

Utility Boilers

Coal-Fired

Oil-Fired

All Others (gas or liquid)

MMBtu/Hour

>/= 40 to <80

Pound/MMBtu

0.50

>/=80 0.21

>/= 40 to <80 0.30

>/=80 0.18

>/= 40 to <80 0.20

>/=80 0.10

Industrial Boilers >/= 40 to <80 0.20

>/=80 0.10

Process Heaters/Furnaces

Ammonia Reformers

All Others

>/=40 to <80 0.30

>/=80 0.23

>/= 40 to <80 0.18

>/=80 0.08

Stationary Gas Turbines

Peaking Service, Oil-Fired

Peaking Service, Gas-Fired

All Others

MW

>/= 5 to <10

Pound/MMBtu

0.37

>/=10 0.30

>/= 5 to <10 0.27

>/=10 0.20

>/= 5 to <10 0.24

>/=10 0.16

Stationary Internal Combustion Engines

Lean-Burn

Rich-Burn

Hp

>/=150 to <320

Grams/Hp-Hour

10

>/=320 4

>/=150 to <300 2

>/=300 2

Currently, the provisions of Chapter 22 apply during the ozone season (May 1 to September 30) 

of each year. Approximately 200 facilities in the BRNA are affected. All affected facilities were 

required to be in compliance by no later than May 1, 2005. 

The impact of Chapter 22 provisions on NOx emissions in the BRNA can be estimated by 

comparing the 2002 and 2006 point source inventories and adjusting for new and shutdown 

facilities. The 2002 and 2006 NOx point source inventories along with new and shutdown 

facilities information are detailed in the appendix. Table 2 below provides a summary. 

579
Table 2: Summary of Chapter 22 Estimated NOx Reductions 

Description NOx Emissions, TPD

1. Certified 2002 Point Source Emissions 116.4

2. Facilities Shutdown by 2006 0.7

3. Adjusted 2002 Inventory Relative to 2006 (1 – 2) 115.7

4. Certified 2006 Point Source Emissions 71.5

5. New Facilities by 2006 0.8

6. Adjusted 2006 Inventory (4 - 5) 70.7

7. Reductions Due to Chapter 22 (3 – 6) 45.0

Contingency Measures Calculation 

As stated above, LDEQ will extend the applicability of Chapter 22 to include the months of 

April and October of each year. This is appropriate since in the years 2003 to 2008, there were 

17 ozone exceedance days during April and October. In the same six-year period, there were 

only three ozone exceedance days in the other five months – January, February, March, 

November, and December. Reducing NOx emissions during April and October will further 

reduce the incidence of high ozone days in BRNA. 

The ratio of the number of days in the new, 7-month ozone season to the number of days in the 

current, 5-month ozone season can be used to provide a reasonable estimate of the amount of 

NOx emission reductions that can be expected if the contingency measures are triggered. The 

calculation follows: 

May – September Days 153 

April – October Days 214 

Additional Controlled Days 61 

Reductions from Chapter 22 40 TPD (*) 

Estimated Contingency Reductions 15.9 TPD ((61/153)*40) 

(*) Actual is 45 TPD; used 40 TPD as a conservative measure. 

EPA guidance states that the contingency measures must be equal to three percent of the 2002 

adjusted base year inventory. From Section B.4 of the SIP RFP document, this inventory is 193.3 

TPD. Three percent times this inventory is equal to 5.8 TPD. Table 3 below summarizes the 

calculation. 

Table 3: Maintenance Plan Contingency Demonstration 

Description NOx, TPD

2002 Adjusted NOx Base Year Inventory Relative to 2008 (RFP – Section B.4) 193.3

Maintenance Plan Contingency Requirement, 3% 5.8

Estimated Reduction from Contingency Measure 15.9

Are Estimated Reductions Greater than the Contingency Requirement? Yes

Contingency Excess 10.1

The contingency requirement is met and there is an excess in estimated reductions of 10.1 TPD. 

580
Section 4 Appendix 

Certified NOx Pollutant Emissions (tpy) by Facility 

581
Appendix - Certified NOx Pollutant Emissions (in tons per year) by Facility

2002 2006

Parish AI # 2002 Company/Facility Name 2006 Company/Facility Name NOx NOx

ASCENSION 529 UNIVAR USA, INC/GEISMAR Univar USA - Geismar Facility 0.0 0.0

ASCENSION 1093 MONOCHEM INC/GEISMAR FACILITY LC Geismar Services LLC - Geismar Facility 392.0 203.9

ASCENSION 1136 SHELL CHEMICAL LP/GEISMAR PLANT Shell Chemical Co - Geismar Plant 739.0 626.9

ASCENSION 1138 WESTLAKE VINYLS COMPANY LP/GEISMAR SITE Westlake Vinyls Co LP 130.0 107.0

ASCENSION 1433 CHEMTURA CORP/GEISMAR PLANT Lion Copolymer Geismar LLC - Geismar Facility 100.0 30.9

ASCENSION 1468 RUBICON, LLC Rubicon LLC - Geismar Plant 588.0 472.9

ASCENSION 2049 BASF CORPORATION/GEISMAR SITE BASF Corp - Geismar Site 671.0 796.2

ASCENSION 2082 HONEYWELL INTERNATIONAL INC/GEISMAR PLANT Honeywell International Inc - Geismar Complex 49.0 70.0

ASCENSION 2218 PRAXAIR INC/GEISMAR HYCO FACILITY Praxair Inc - Geismar HYCO Facility 199.0 167.8

ASCENSION 2245

TERRA MISSISSIPPI NITROGEN/TMNI 

DONALDSONVILLE

Terra Mississippi Nitrogen Inc - Donaldsonville Facility

2368.0

23.1

ASCENSION 2398

TERRA MISSISSIPPI NITROGEN 

INC/DONALDSONVILLE FAC shutdown or below reporting limit 2.0

ASCENSION 2416

CF INDUSTRIES INC/DONALDSONVILLE NITROGEN 

COMPLEX

CF Industries Inc - Donaldsonville Nitrogen Complex

3429.0

2637.6

ASCENSION 2679

AIR PRODUCTS & CHEMICALS INC/GEISMAR SMR 

FACILITY Air Products & Chemicals Inc - Syngas Plant 56.0 56.7

ASCENSION 3302

CROSSTEX PROCESSING SERVICES/RIVERSIDE 

FRACTIONATION

Crosstex Processing Services LLC - Riverside 

Fractionation 288.0

150.8

ASCENSION 3400 OCCIDENTAL CHEMICAL CORP/GEISMAR PLANT Occidental Chemical Corp - Geismar Plant 1286.0 150.7

ASCENSION 3420 ORMET CORP/BURNSIDE ALUMINA PLANT

Ormet Primary Aluminum Corp - Burnside Alumina 

Plant 6.0

679.4

ASCENSION 3732 PCS NITROGEN FERTILIZER LP/GEISMAR

PCS Nitrogen Fertilizer LP - Nitrate Group - Geismar 

Agricultural Nitrogen & Phosphate Plant 1329.0

269.9

ASCENSION 3990 WAGNER OIL CO/DARROW COMM LEASE shutdown or below reporting limit 0.0

ASCENSION 4762 ENTERPRISE GAS PROC LLC/TEBONE FRAC PLANT

Enterprise Gas Processing LLC - Tebone Fractionation 

Plant 49.0

44.2

ASCENSION 4803

BFI WASTE SYSTEMS OF LA INC/COLONIAL 

LANDFILL BFI - Colonial Landfill 11.0 5.7

ASCENSION 5565

WILLIAMS OLEFINS LLC/GEISMAR ETHYLENE 

PLANT Williams Olefins LLC - Geismar Ethylene Plant 703.0 724.9

ASCENSION 8142 WAGNER OIL CO/DARROW GRC BATTERY Darrow Field Facility - Darrow Field 41.0 5.5

ASCENSION 11416

BRIDGELINE HOLDINGS LP/SORRENTO 

UNDERGROUND GAS STORAGE FACILITY Sorrento Underground Gas Storage Facility 44.0 11.4

ASCENSION 17771 T. T. BARGE CLEANING MILE 183 INC T T Barge Cleaning Mile 183 Inc 1.8 2.8

ASCENSION 20506 ENTERPRISE PRODUCTS CO/SORRENTO PHT

Enterprise Products Operating LP - Sorrento Products 

Handling Terminal 3.0

2.9

ASCENSION 26272 DSI TRANSPORTS INC/GEISMAR LA TERMINAL Trimac - Geismar Terminal 1.0 0.9

ASCENSION 27834 EXXONMOBIL PIPELINE CO/SORRENTO STORAGE

ExxonMobil Pipeline Co - Sorrento Storage Facility

2.0

1.2

ASCENSION 30073 BASF CORPORATION/DINITROTOLUENE PLANT Air Products & Chemicals Inc 25.0 35.1

ASCENSION 31513

AIR LIQUIDE LARGE INDUSTRIES US/GEISMAR 

FACILITY Air Liquide Large Industries US LP - Geismar 269.0 112.3

ASCENSION 31514

GABRIEL CHEMICALS LLC/CHLOROSULFONIC ACID 

PLANT Gabriel Chemicals LLC - CSA Plant 0.0

ASCENSION

33564

did not exist or below reporting limit

Cooper T Smith Stevedoring Co - America Weigh Rig 

Loading & Transfer Facility 24.7

ASCENSION

33579

did not exist or below reporting limit

Cooper T Smith Stevedoring Co - Floating Grain 

Elevator Rig #1 0.0

ASCENSION 39945 ORMET CORP/BURNSIDE BULK MARINE TERMINAL

Ormet Corp - Burnside Bulk Marine Terminal - Division 

of Ormet Primary Aluminum Corp 89.0

12.1

ASCENSION 41417

SHELL PIPELINE CO LP/SORRENTO DOME 

STORAGE Shell Pipeline Co LP - Dome Storage Facility 2.0 1.9

ASCENSION 46968

MID-AMERICA RESOURCES 

CORPORATION/SORRENTO FIELD PRODUCTION 

FACILITY

Mid-America Resources Corp - Sorrento Field 

Production Facility 0.0

0.2

ASCENSION 67572

EI DUPONT DE NEMOURS & CO INC/BURNSIDE 

PLANT

E l Dupont de Nemours & Co Inc - Burnside Plant A 

H2SO4 Contact Facility 55.0

54.4

ASCENSION 83718

LOUIS DREYFUS OLEFINS LLC/GEISMAR FRAC 

PLANT LDH Energy Olefins LLC 44.0 59.4

ASCENSION 86181

TEXACO PIPELINES LLC/SORRENTO TENDS PUMP 

STATION Sorrento TENDS Pumping Station 0.0

ASCENSION 88164

ENTERPRISE PROD OPER LP/SORRENTO RAIL 

RACK

Enterprise Products Operating LLC - Sorrento Loading 

Facility 0.0

0.1

582
Appendix - Certified NOx Pollutant Emissions (in tons per year) by Facility

ASCENSION 90203 PLAINS MARKETING LP/DARROW CRUDE OIL TERM Plains Marketing LP - Darrow Crude Oil Terminal 0.0

ASCENSION 92534 HEXION SPECIALTY/FORMALDEHYDE PLANT

Hexion Specialty Chemicals Inc - Formaldehyde Plant

3.0

0.7

ASCENSION 97675

CHEMTECH CHEMICAL SERVICES LLC/GEISMAR 

BLENDING FACILITY

ChemTech Chemical Services LLC - Blending Facility

0.0

ASCENSION 99129 MEDCO ENERGI US LLC/UNITED LANDS #1 United Lands #1 Facility 1.0 2.0

ASCENSION 100581 WILLIAMS OLEFINS LLC/HC BARGE LOAD shutdown or below reporting limit 0.0

ASCENSION 100651

LOUIS DREYFUL OLEFINS LLC/SORRENTO GAS 

PROCESSING PLANT LDH Energy Olefins LLC - Convent Gas Plant 0.2 1.4

ASCENSION

122402

did not exist or below reporting limit

International Matex Tank Terminals - Geismar Logistics 

Center

ASCENSION 143528 did not exist or below reporting limit State Lease 17446 Tank Battery - Darrow Field

ASCENSION 143529 did not exist or below reporting limit SL 17446 Well - Darrow Field 0.3

ASCENSION 145270 did not exist or below reporting limit Sorrento Production Facility 0.0

E BATON ROUGE 248 DELTECH CORPORATION/BATON ROUGE FACILITY Deltech Corp - Baton Rouge Facility 256.0 77.0

E BATON ROUGE 285

EXXONMOBIL CHEMICAL CO/BATON ROUGE 

PLASTICS PLANT

ExxonMobil Chemical Co - Baton Rouge Plastics Plant

108.0

123.8

E BATON ROUGE 286

EXXONMOBIL CHEM CO/BATON ROUGE CHEMICAL 

PLANT

ExxonMobil Chemical Co - Baton Rouge Chemical Plant

2560.0

2175.5

E BATON ROUGE 288 FORMOSA PLASTICS CORPORATION, LA

Formosa Plastics Corp Louisiana - Baton Rouge Plant

570.0

367.8

E BATON ROUGE 289 HONEYWELL/BATON ROUGE PLANT

Honeywell International Inc - Baton Rouge South Works

21.0

15.3

E BATON ROUGE 332

EXXONMOBIL CORP/BATON ROUGE MARKETING 

TERMINAL ExxonMobil Corp - Baton Rouge Terminal #5005 0.0

E BATON ROUGE 582

PLANTATION PIPE LINE CO/BATON ROUGE 

BREAKOUT TANK FARM

Plantation Pipe Line Co - Baton Rouge Breakout Tank 

Farm 0.0

E BATON ROUGE 669

ALBEMARLE CORP/PROCESS DEVELOPMENT 

CENTER Albemarle Corp - Process Development Center 11.0 14.3

E BATON ROUGE 1000 ASHLAND CHEM CO/BATON ROUGE DISTRIBUTION Ashland Chemical Co 0.0

E BATON ROUGE 1157 STUPP CORP/BAKER shutdown or below reporting limit 0.0

E BATON ROUGE 1186 ENTERGY GSI/LA STATION 2 GENERATING PLANT

Entergy Louisiana Station Electrical Generating Plant

0.0

1694.0

E BATON ROUGE 1186 ENTERGY GSI/LA STATION 1 GENERATING PLANT (consolidated with Station 2) 1833.0

E BATON ROUGE 1314 RHODIA INC/BATON ROUGE FACILITY Rhodia Inc 74.0 58.8

E BATON ROUGE 1395 LION COPOLYMER/BATON ROUGE PLANT Lion Copolymer LLC - Baton Rouge Plant 127.0 246.8

E BATON ROUGE 1396 EXIDE TECHNOLOGIES/BATON ROUGE SMELTER Exide Technologies - Baton Rouge Smelter 9.0 16.2

E BATON ROUGE 1413 UOP LLC/BR PLANT UOP LLC - Baton Rouge Plant 46.0 34.5

E BATON ROUGE 1516 CLEAN HARBORS BATON ROUGE, LLC Clean Harbors Baton Rouge LLC 0.0 0.0

E BATON ROUGE 2617 GEORGIA PACIFIC/PORT HUDSON OPERATIONS

Georgia-Pacific Consumer Operations LLC - Port 

Hudson Operations 1916.0

1653.1

E BATON ROUGE 2638

EXXONMOBIL REF & SUPPLY CO/BATON ROUGE 

REFINERY

ExxonMobil Refining & Supply Co - Baton Rouge 

Refinery 3583.0

2245.3

E BATON ROUGE 3085 ETHYL CORPORATION/BATON ROUGE PLANT Ethyl Corp - Baton Rouge Plant 0.0

E BATON ROUGE 3230

EXXONMOBIL CHEM CO/BATON ROUGE RESIN 

FINISHING PLANT

ExxonMobil Chemical Co - Baton Rouge Resin Finishing 

Plant 16.0

15.2

E BATON ROUGE 3387 FERRO CORPORATION/BATON ROUGE SITE Ferro Corp - Baton Rouge Site 8.0 12.2

E BATON ROUGE 3519

EXXONMOBIL CHEM CO/BATON ROUGE 

POLYOLEFINS

ExxonMobil Chemical Co - Baton Rouge Polyolefins 

Plant 105.0

115.9

E BATON ROUGE 3587

PPG INDUSTRIES INC/BATON ROUGE SOLVENT 

PLANT - GROW AUTOMOTIVE PPG Industries Inc - Grow Automotive 0.0

E BATON ROUGE 3991 did not exist or below reporting limit Genesis Crude Oil LP - Truck Loading Facility

E BATON ROUGE 4407 did not exist or below reporting limit EBR Parish Renewable Energy Center 1.0

E BATON ROUGE 4993 BP AMERICA PROD/PORT HUDSON GAS PLANT Port Hudson Gas Plant 20.0 1.4

E BATON ROUGE 5190

ALLWASTE CONTAINER SVCS/BATON ROUGE 

PLANT Allwaste Tank Cleaning Inc 2.0 2.0

583
Appendix - Certified NOx Pollutant Emissions (in tons per year) by Facility

E BATON ROUGE 5540

LOUISIANA STATE UNIVERSITY/BATON ROUGE 

CAMPUS Louisiana State University - LSU 133.4 94.3

E BATON ROUGE 8007

FLORIDA GAS TRANSMISSION CO/ZACHARY 

COMPRESSOR STATION

Florida Gas Transmission Co - Zachary Compressor 

Station #8 940.0

331.8

E BATON ROUGE 11595 FLOWERS BAKING CO OF BATON ROUGE LLC

Flowers Baking Co of Baton Rouge LLC - Baton Rouge 

Facility 1.5

1.6

E BATON ROUGE 17129 HILCORP ENERGY CO/COMITE FIELD FACILITY Comite Field Facility 9.0 15.0

E BATON ROUGE 22750 EDO SPECIALTY PLASTICS EDO Specialty Plastics - Perkins Rd Fac 0.0

E BATON ROUGE 25383 LAMAR CORP/LAMAR GRAPHICS Lamar Graphics 0.0

E BATON ROUGE 27559 BAYOU COATING LLC Bayou Coating LLC 2.0 2.5

E BATON ROUGE 29884

GREAT LAKES CARBON LLC/BATON ROUGE 

CALCINED COKE PLANT

Oxbow Calcining LLC - Baton Rouge Calcined Coke Plant

380.0

182.7

E BATON ROUGE 31128 did not exist or below reporting limit East Baton Rouge Parish Landfill (BFI North) 4.5

E BATON ROUGE 32045 HILCORP ENERGY CO/MANCHAC POINT Manchac Point Oil & Gas Field Facility 19.0 22.7

E BATON ROUGE 32050

SCHERING-PLOUGH ANIMAL HEALTH CORP/VET 

OPERATIONS shutdown or below reporting limit 0.7

E BATON ROUGE 32056 EXXON MOBIL CORP/PROCESS RESEARCH (EMPR)

ExxonMobil Refining & Supply Co - Process Research 

Laboratories 4.0

1.2

E BATON ROUGE 88139

BP AMERICA PROD/PORT HUDSON CENTRAL TANK 

BATTERY Port Hudson Central Tank Battery 14.0 23.1

E BATON ROUGE 90176

BP PIPELINES NORTH AMERICA/PORT HUDSON 

TERMINAL Genesis Crude Oil LP - Port Hudson Terminal 0.0 0.0

E BATON ROUGE 95859 BRECHTEL ENERGY CORP/UNIVERSITY FIELD PF University Field Production Facility 10.0 9.6

E BATON ROUGE 98136 GOLDKING OPERATING CO/COBB #1 COMITE FIELD shutdown or below reporting limit 35.0

E BATON ROUGE 96336 did not exist or below reporting limit US Composite Pipe South LLC - Baton Rouge Plant 4.7

E BATON ROUGE 114658 did not exist or below reporting limit Siegen Production Facility - Siegen Field 5.8

E BATON ROUGE 114659 did not exist or below reporting limit Port Hudson Field Production Facility 0.2

E BATON ROUGE 119007 did not exist or below reporting limit Duplantier Tank Battery - University Field 24.0

E BATON ROUGE 119008 did not exist or below reporting limit Nelson Tank Battery - University Field 18.0

E BATON ROUGE

138716

did not exist or below reporting limit

North Burtville Field Facility - North Burtville Field 0.0

E BATON ROUGE

144826

did not exist or below reporting limit

Crown Paper #1 Production Facility - Profit Island Field

E BATON ROUGE

146877

did not exist or below reporting limit

Crown Paper #1 Treating Facility - Profit Island Field

IBERVILLE 1306 CORA TEXAS MFG INC/SUGAR MILL Cora Texas Manufacturing Co 215.0 201.0

IBERVILLE 1409 DOW CHEMICAL CO/LA OPERATIONS The Dow Chemical Co - Louisiana Operations 8611.0 4337.7

IBERVILLE 1607

TOTAL PETROCHEMICALS USA INC/COSMAR 

COMPANY STYRENE PLANT TOTAL Petrochemicals USA Inc - Cos-Mar Co 682.0 284.4

IBERVILLE 2043

PETROLOGISTICS OLEFINS LLC/CHOCTAW 

TERMINAL PetroLogistics Olefins LLC - Choctaw Terminal 12.0 10.8

IBERVILLE 2367

SYNGENTA CROP PROTECTION INC/ST. GABRIEL 

PLANT Syngenta Crop Protection Inc - St Gabriel Plant 215.0 175.2

IBERVILLE 2455

GEORGIA GULF CHEM & VINYLS LLC/PLAQUEMINE 

FACILITY

Georgia Gulf Chemicals & Vinyls LLC - Plaquemine 

Division 1265.0

1182.9

IBERVILLE 2625 ENTERGY GSI/WILLOW GLEN GENERATING PLANT

Entergy Gulf States Utilities Inc - Willow Glen Plant

2437.0

36.0

IBERVILLE 2644 PIONEER AMERICAS LLC/CHLOR-ALKALI PLANT Pioneer Americas LLC - St Gabriel Facility 16.7 23.4

IBERVILLE 3129

ASHLAND CHEMICAL CO/PLAQUEMINE METHANOL 

PLNT shutdown or below reporting limit 0.3

IBERVILLE 3263 TAMINCO HIGHER AMINES INC/ST. GABRIEL Taminco Higher Amines Inc 64.0 73.5

IBERVILLE 3492 LBC BATON ROUGE LLC/SUNSHINE TERMINAL LBC Baton Rouge LLC - Sunshine Terminal 1.0 2.6

IBERVILLE 4197 SOUTHERN NATURAL GAS/WHITE CASTLE CS

Southern Natural Gas Co - White Castle Compressor 

Station 404.0

160.9

IBERVILLE 5176

TOTAL PETROCHEMICALS USA INC/CARVILLE 

POLYSTYRENE

TOTAL Petrochemicals USA Inc - Carville Polystyrene 

Plant 33.0

22.5

IBERVILLE 7359

TEXAS EASTERN TRANSMISSION LP/WHITE 

CASTLE COMPRESSOR STATION

Texas Eastern Transmission LP - White Castle 

Compressor Station 180.0

0.0

IBERVILLE 8055 did not exist or below reporting limit State of Louisiana Military - Gillis W Long Center 32.2

584
Appendix - Certified NOx Pollutant Emissions (in tons per year) by Facility

IBERVILLE 8072 HILCORP ENERGY CO/BAYOU BOUILLON PF Bayou Bouillon Facility 60.0 5.0

IBERVILLE 14139 PLAINS MARKETING LP/ST GABRIEL TERMINAL Plains Marketing LP - St Gabriel Terminal 0.0

IBERVILLE 14535 INEOS FLUOR AMERICAS LLC/KLEA-134A PLANT INEOS Fluor Americas LLC - KLEA Plant 15.6 8.1

IBERVILLE 17383

CROSSTEX LIG LLC/MYRTLE GROVE 

COMPRESSOR STATION Crosstex LIG - Myrtle Grove Station 19.0 5.1

IBERVILLE 19184

CROSSTEX LIG LIQUIDS CO LLC/PLAQUEMINE GAS 

PROCESSING PLANT Crosstex LIG Liquids LLC - Plaquemine Gas Plant 151.0 122.8

IBERVILLE 20411

TEXAS PETRO INVESTMENT CO/BAYOU BLEU 

CENTRAL FAC #2 Bayou Bleu Central Facility #2 113.0 69.7

IBERVILLE 24479 SCS IBERVILLE COATINGS INC SCS Iberville Coatings Inc 0.0 0.2

IBERVILLE 26034

LA ENERGY & POWER AUTHORITY/PLAQUEMINE 

STEAM & DIESEL POWER PLANT

Louisiana Energy & Power Authority (LEPA) - 

Plaquemine Steam Electric Power Plant 1.1

0.7

IBERVILLE 26984

HUNTSMAN INTERNATIONAL LLC/ST. GABRIEL 

FACILITY Huntsman International LLC - St Gabriel Facility 4.0 2.1

IBERVILLE 27495 BCP INGREDIENTS INC. BCP Ingredients Inc 1.7 0.1

IBERVILLE 32133 BAYOU SORREL OIL/BAYOU SORREL CF Bayou Sorrel Commingling Facility 43.0 19.4

IBERVILLE 32135 JP OIL CO/WHITE CASTLE PRODUCTION FACILITY White Castle Field Production Facility 37.0 12.4

IBERVILLE 32141

BRIDGELINE HOLDINGS LP/TALLY HO 

COMPRESSOR STATION Tally Ho Compressor Station 1.0 0.1

IBERVILLE 32145 GOLDKING OPERATING CO/NW BAYOU CHOCTAW Northwest Bayou Choctaw Production Facility 16.0 6.8

IBERVILLE 32146

CLK ENERGY PARTNERS INC/BAYOU CHOCTAW 

FIELD PRODUCTION FACILITY shutdown or below reporting limit 32.8

IBERVILLE 32154 JP OIL CO/GRAND RIVER shutdown or below reporting limit 0.0

IBERVILLE 32160 did not exist or below reporting limit Bayou Bleu Field Production Facility 25.7

IBERVILLE 32161

OLEUM OPERATING CO LC/BAYOU HENRY FIELD 

PRODUCTIN FACILITIES Bayou Henry Field Production Facility 14.6 14.5

IBERVILLE 33667 did not exist or below reporting limit Basic Industries Inc - Sandblast & Spray Paint Yard 7.0

IBERVILLE 39633 did not exist or below reporting limit Command Services Inc 13.4

IBERVILLE 39978

KINDER MORGAN LIQUIDS TERMINALS ST. 

GABRIEL LLC Kinder Morgan Liquids Terminals St Gabriel LLC 0.0 0.6

IBERVILLE 40037 SOMERVILLE PARTNERS LP/STATE LEASE 14371 State Lease 14371 Production Facility 0.0 0.5

IBERVILLE 51854

CARVILLE ENERGY LLC/CARVILLE ENERGY 

CENTER Carville Energy LLC - Carville Energy Center 18.0 275.5

IBERVILLE 84377

OLEUM OPERATING CO, LC/BAYOU DES GLAISESWILBERT MINERAL B LEASE shutdown or below reporting limit 30.0

IBERVILLE 84483

SOUTHERN BAY OPERATING LLC/FROG LAKE 

FACILITY shutdown or below reporting limit 29.0

IBERVILLE 85393

PETRO HUNT LLC/BAYOU HENRY CENTRAL 

FACILITY Bayou Henry Central Facility 48.0

IBERVILLE 85652

DOW CHEMICAL CO/PLAQUEMINE COGEN 

FACILITY

The Dow Chemical Co - Plaquemine Cogeneration Plant

0.0

340.0

IBERVILLE 86585

SHELL PIPELINE CO LP/GRAND RIVER BARGE 

LOADING shutdown or below reporting limit 0.0

IBERVILLE 89237 INEOS LLC/INEOS OXIDE shutdown or below reporting limit 0.0

IBERVILLE 89512

LIBERTY RESOURCES INC/DUGAS & LEBLANC LTD 

ET AL #1 Dugas & LeBlanc Ltd et al #1 Production Facility 0.0 5.0

IBERVILLE 90197

EOTT ENERGY PIPELINE LP/BAYOU BLUE CRUDE 

OIL TERM shutdown or below reporting limit 0.0

IBERVILLE 101588 PETROQUEST ENERGY LLC/EEX CORP PF #1 EEX Corp Production Facility #1 11.0 23.6

IBERVILLE 113166 did not exist or below reporting limit Bayou Bouillon Production Facility 7.9

IBERVILLE 118389 did not exist or below reporting limit Bayou Bleu - Central Facility #1 10.4

IBERVILLE 119219 did not exist or below reporting limit White Castle Deep Production Facility 3.3

IBERVILLE 125240 did not exist or below reporting limit Chatham Farms #1 Production Facility

IBERVILLE 126487 did not exist or below reporting limit Dent et al #1 Production Facility - Musson Field 1.1

IBERVILLE 126578 did not exist or below reporting limit Shintech Louisiana LLC - Plaquemine PVC Plant

IBERVILLE 126748 did not exist or below reporting limit Schwing 10 Production Facility - Frog Lake Field 1.5

IBERVILLE

126750

did not exist or below reporting limit

Dow Chemical Co Production Facility - Frog Lake Field 4.3

IBERVILLE 128638 did not exist or below reporting limit Forest Home Partnership Facility 1.1

IBERVILLE

132984

did not exist or below reporting limit

Schwing #1 Production Facility - Sullivan Lake Field 0.2

IBERVILLE 134264 did not exist or below reporting limit Gueymard Production Facility - St Gabriel Field 0.5

IBERVILLE 135484 did not exist or below reporting limit Kessler #1 & Kessler #2 Production Facility 22.5

IBERVILLE 138856 did not exist or below reporting limit St Gabriel Dehy & NGL Production Facility 0.0

IBERVILLE 139760 did not exist or below reporting limit Bayou Bouillion etal #1 Production Facility

LIVINGSTON 1467 EAST JORDAN IRON WORKS East Jordan Iron Works 14.0 7.7

LIVINGSTON 4990 BP AMERICA PROD/LOCKHART CROSSING CF # 1 Lockhart Crossing CF #1 38.0 15.9

585
Appendix - Certified NOx Pollutant Emissions (in tons per year) by Facility

LIVINGSTON 6858 GRIFFIN INDUSTRIES, INC Griffin Industries Inc 1.0 0.6

LIVINGSTON 9154 THE SHAW GROUP/SUNLAND FABRICATORS Shaw Sunland Fabricators Inc 0.0 3.3

LIVINGSTON 11767

WASTE MANAGEMENT OF LA, LLC/WOODSIDE 

LANDFILL

Waste Management of LA LLC - Woodside Sanitary 

Landfill & Recycling Center 12.0

8.2

LIVINGSTON 17042

DENBURY RESOURCES INC/LOCKHART CROSS 

WILCOX CF3 Lockhart Crossing Central Facility #3 125.0 5.1

LIVINGSTON 19875

WEYERHAEUSER CO/HOLDEN SAWMILL & LOG 

PROCESS Weyerhaeuser Co - Holden Wood Products 22.0 28.3

LIVINGSTON 26884

PLAINS MARKETING LP/LOCKHART CROSSING 

STATION shutdown or below reporting limit 0.0

LIVINGSTON 32465 TMR EXPLORATION INC/LVG WXI RA SU LB LVG WX1 RA SU LB Facility 0.2 1.1

LIVINGSTON 32466

TUCKER OPER CO INC/ERVA S. MAYERS #1/1D 

PRODUCTION FACILITY Erva S Mayers # 1 0.0

LIVINGSTON 80537

DELTA ENVIRONMENTAL PRODUCTS INC/DENHAM 

SPRINGS FACILITY

Pentair Pump Group Inc - Delta Environmental 

Products Inc - Denham Springs Operations 0.0

1.5

LIVINGSTON 99952 did not exist or below reporting limit O M Barnett #2 Facility - Lockhart Crossing Field 17.1

LIVINGSTON 120886 did not exist or below reporting limit SL 7729 #2 Wellsite - Lockhart Crossing Field

LIVINGSTON

130526

did not exist or below reporting limit

Blind River Facility (SL 18562 #1 Well) - Blind River Field 

Block 16

LIVINGSTON 146741 did not exist or below reporting limit Lockhart Crossing Central Processing Faciity

W BATON ROUGE 302 T.T. BARGE SERVICE MILE 237, LLC/BR SHIPYARD TT Barge Services Mile 237 7.8 3.4

W BATON ROUGE 858

EXXONMOBIL REF & SUPPLY CO/ANCHORAGE 

TANK FARM

ExxonMobil Refining & Supply Co - Anchorage Tank 

Farm 0.0

4.7

W BATON ROUGE 1648 BP LUBRICANTS USA INC/PORT ALLEN FACILITY BP Lubricants USA Inc - Port Allen Facility 3.3 6.9

W BATON ROUGE 2366 PLACID REFINING CO LLC/PORT ALLEN REFINERY Placid Refining Co LLC - Port Allen Refinery 967.0 702.1

W BATON ROUGE 2519 DSM COPOLYMER/ADDIS PLANT shutdown or below reporting limit 163.0

W BATON ROUGE 3473 SHINTECH LOUISIANA LLC/ADDIS PLANT B shutdown or below reporting limit 5.0

W BATON ROUGE 4056

ALMA PLANTATION LLC/CINCLARE CENTRAL 

FACTORY

Harry L Laws & Co Inc - Cinclare Central Sugar Factory

121.0

W BATON ROUGE 4174 SID RICHARDSON CARBON CO/ADDIS PLANT Sid Richardson Carbon & Gasoline Co 220.0 307.9

W BATON ROUGE 9495 BASF CATALYSTS LLC/PORT ALLEN WORKS BASF Catalyst LLC - Port Allen Works 30.0 26.5

W BATON ROUGE

11059

did not exist or below reporting limit

Specialty Application Services Inc - Port Allen Facility 5.6

W BATON ROUGE 12096 did not exist or below reporting limit Westway Terminal Co Inc 0.3

W BATON ROUGE 17161

EXXONMOBIL PROD CO/BATON ROUGE GAS 

PLANT

ExxonMobil Production Corp - Baton Rouge Gas Plant

114.0

153.5

W BATON ROUGE 19338 PETROLEUM FUEL & TERM/PORT ALLEN shutdown or below reporting limit 2.0

W BATON ROUGE 19556

INTERCONTINENTAL TERMINALS CO/ANCHORAGE 

CHEM TERM Intercontinental Terminals Co 0.3

W BATON ROUGE

25344

did not exist or below reporting limit

Criterion Catalysts & Technologies LP - HPA Port Allen 

Plant 4.3

W BATON ROUGE

25344

did not exist or below reporting limit

Criterion Catalysts & Technologies LP - HPA Port Allen 

Plant 2.2

W BATON ROUGE 26217

TURNER INDUSTRIES GROUP/INTL PAINTING 

CORP Turner Industries Group LLC 0.0

W BATON ROUGE 40198

BATON ROUGE FRACTIONATORS/BATON ROUGE 

COMPLEX

Enterprise Products Operating LLC - Baton Rouge Act 

Frac/PCU 42.0

37.3

W BATON ROUGE 43634 TRINITY MARINE PRODUCTS INC/PLANT 48

Trinity Marine Products Inc - Plant #48 (Trinity Brusly)

4.0

0.2

W BATON ROUGE 83425 SHINTECH LOUISIANA, LLC/ADDIS PLANT A Shintech Louisiana LLC - Addis Plant A 34.0 31.5

W BATON ROUGE 98796

EXXONMOBIL PIPELINE CO/ANCHORAGE 

TERMINAL ExxonMobil Pipeline Co - Anchorage Terminal 0.0 0.2

W BATON ROUGE

126510

did not exist or below reporting limit

Bueche Heirs Well #1 Facility SN 228905 - Profit Island 

Oil Field 5.3

W BATON ROUGE 139063 did not exist or below reporting limit Oliver #1 Tank Battery - Profit Island Field 0.8

42497.0 26094.6

Notes:

 ran in 2002 and were either shutdown or below reporting limit by 2006. 299.8 TPY

t did not exist or were below the reporting limit in 2002 and new by 2006. 249.5 TPY

586
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588
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SECTION 5 

OUTSTANDING REQUIREMENTS 

630
631
SECTION 5: OUTSTANDING REQUIREMENTS 

5.1: Major Source Permits and Nonattainment New Source Review 

 On April 24, 2003, EPA published a final rule finding that the Baton Rouge 

nonattainment area did not attain the 1-hour standard by November 15, 1999, the attainment date 

set for "serious" nonattainment areas as set forth in the CAA. As a result, EPA reclassified the 

area to the next higher classification of "severe". This classification brought with it new control 

measure requirements, one of which set the permitting major source threshold at 25 tons per year 

(tpy) with an offset ratio of 1.3 to 1 with LAER or 1.5 to 1 without LAER. 

 LDEQ complied with these requirements by promulgating a revision to LAC 33:III.504.L 

and M. This rule revision was submitted to EPA along with the applicable VOC and NOx RACT 

revisions in June 2005 as a revision to the SIP. The rule revisions for Chapter 5 became 

applicable to administratively complete permit applications on June 23, 2003, in accordance with 

LAC 33:III:519.A. 

 On April 30, 2004, the Baton Rouge area was initially classified as marginal under the 

1997 8-hour NAAQS with a new attainment date of June 15, 2005. Following implementation 

of the 1997 8-hour NAAQS, LDEQ relaxed this requirement to the serious classification 

threshold of 50 tpy. According to the Phase I rule, nonattainment new source review (NNSR) 

thresholds should be based on the area's designation classification under the 8-hour NAAQS. 

This relaxation did not go as far as the Phase I rule allowed under the marginal classification, 

making the rule more stringent than otherwise required. 

 Litigation succeeded in striking this part of the Phase I rule (U.S. Court of Appeals for 

the District of Columbia Circuit’s decision in South Coast Air Quality Mgmt. Dist. v. EPA). 

EPA’s position is set forth in a letter dated April 29, 2009, from Lawrence E. Starfield, Acting 

Regional Administrator of EPA Region 6, to Dr. Harold Leggett, Secretary of the Department of 

Environmental Quality (LDEQ). Relevant passages from this letter follow. 

 On April 30, 2004, EPA published a “Phase 1” rule that removed the need 

for States to include 1-hour ozone NSR elements as part of their federally 

approved SIP after EPA revoked the 1-hour national ambient air quality 

standard [NAAQS] for ozone. The court vacated that provision and found 

that NSR was a “control” and that “withdrawing [it] from a SIP would 

constitute impermissible backsliding.” On October 3, 2007, EPA’s Office 

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of Air & Radiation informed Regional Administrators that the decision 

effectively restored NSR applicability thresholds and emission offsets in 

ozone nonattainment areas pursuant to classifications previously in effect 

for the 1-hour standard. The memorandum strongly encouraged States to 

comply with the court's decision in a timely manner. 

In accordance with this memorandum, EPA expects States to implement 1-

hour nonattainment NSR requirements using thresholds and emission 

offsets based on the classifications for areas designated nonattainment for 

the 1-hour ozone standard. In addition, we interpret the CAA 172(c)(5) and 

173 and regulations set forth at 40 CFR 51.165(a)(2)(i) to require 

nonattainment NSR permits to be based on the requirements that apply at 

the time of permit issuance, not those that applied at the time of permit 

application. 

 [W]e encourage LDEQ to institute that practice throughout your permitting 

process and to undertake all appropriate rulemaking to ensure that LDEQ’s 

permits can be issued consistent with the South Coast decision. LDEQ 

should also conduct an examination of facilities above the severe threshold 

of 25 TPY yet below the serious threshold of 50 TPY to ensure that the 

severe area major source threshold is applied to new sources and that those 

existing sources above the severe threshold have obtained the appropriate 

NSR/PSD and/or Title V operating permits. We will continue to review 

NSR permits, and will comment on any that do not implement the threshold 

and offset requirements set out in the South Coast decision. 

Because the Baton Rouge area did not meet the June 15, 2005 attainment date, the area 

was reclassified as “moderate,” effective April 21, 2008. For moderate ozone nonattainment 

areas, the CAA sets the “major stationary source” threshold at 100 tons per year (TPY) of NOx or 

VOC and the “major modification significant net increase threshold” at 40 TPY of NOx or VOC 

for the purpose of determining whether “netting” is required and if a “net emissions increase” is 

considered significant. The minimum offset ratio is 1.15 to 1. 

LDEQ’s NNSR rules, however, are more stringent than otherwise required by the CAA 

based on the area’s 8-hour designation. LAC 33:III.504.M sets the “major stationary source” 

threshold at 50 TPY of NOx or VOC and the “major modification significant net increase 

threshold” at 25 TPY of NOx or VOC. The minimum offset ratio is 1.2 to 1. Nevertheless, 

thresholds for severe ozone nonattainment areas are more stringent. 

If severe area thresholds were applied, the NNSR “major stationary source” threshold 

applicable in the BRNA would be reduced to 25 TPY of NOx or VOC, and consideration of the 

“net emissions increase” would be required for projects resulting in a NOx or VOC increase of 

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only 5 TPY. Further, the minimum offset ratio would increase to 1.3 to 1 (when Lowest 

Achievable Emission Rate (LAER) is applied) or 1.5 to 1 (when internal offsets are applied in 

lieu of LAER). Because major stationary sources under NNSR provisions are also major sources 

under 40 CFR 70, additional sources (i.e., those with potential NOx and/or VOC emissions of 25 

TPY or more and not already classified as “Part 70 sources”) would be required to apply for Part 

70 (Title V) permits. 

LDEQ encourages permit applicants in the BRNA to carefully consider EPA’s position 

and guidance in the preparation of air permit applications. Failure to follow this guidance may 

result in EPA objecting to a proposed permit pursuant to 40 CFR 70.8(c). It should also be noted 

that the area reached attainment prior to the moderate attainment deadline without the institution 

of the severe area threshold implementation. 

5.2: Section 185 Fees 

Section 185 of the CAA requires each major stationary source in any severe or extreme 

ozone nonattainment area to pay a fee to the state as a penalty for failure to attain the ozone 

NAAQS. This provision is part of the original 1990 CAA Amendments (Part D, Subpart 2 - 

Additional Provisions for Ozone Nonattainment Areas) and can be seen as a final, harsh 

punishment for failure to attain. It is specifically directed towards major stationary sources and 

not nonpoint (area), mobile, or biogenic sources. 

When the BRNA failed to reach the applicable attainment date and was bumped-up to the 

severe classification, Section 185 penalty fee rule promulgation was required. The state sought 

legislative authority to collect these fees in the event the area did not attain the standard which 

would then require immediate rule implementation. This authority was granted to the agency 

through Act No 441 of the 2003 Regular Session and Act No 588 of the 2008 Regular Session. 

Act No. 441 grants LDEQ authorization with the applicable exceptions for extension years and 

population densities of less than 250,000. Two separate rulemakings have been proposed, but all 

rulemaking ceased with the onset of the 8-hour Phase I Implementation rule because the 8-hour 

Phase I Implementation rule did not require Section 185 fees. 

Lawsuits were filed arguing against many of the components of the Phase I rule. As it 

applies to Section 185, EPA was of the opinion that Section 185 fees were not a control measure 

because realized emission reductions would not be a direct result of its implementation. The 

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courts in the South Coast case did not agree with EPA’s assertion and the Section 185 fees were 

re-established as anti-backsliding criteria for those areas that fell under the requirement. 

 On January 5, 2010 EPA issued Guidance on Developing Fee Programs Required by 

Clean Air Act Section 185 for the 1-hour Ozone NAAQS. In this document, EPA stated that: 

“for an area that we [EPA] determine is attaining either the 1-hour or 1997 

8-hour ozone NAAQS, based on permanent and enforceable emission 

reductions, the area would no longer be obligated to submit a fee program 

SIP revision to satisfy the anti-backsliding requirements associated with 

the transition from the 1-hour standard to the 1997 8-hour standard. In 

such cases an area’s existing SIP should be considered an adequate 

alternative program. Our reasoning follows from the fact that an area’s 

existing SIP measures, in conjunction with other enforceable federal 

measures, are adequate for the area to achieve attainment, which is the 

purpose of the section 185 program.” 

 Following this guidance, Louisiana submitted, on February 24, 2010, a Section 185 

Determination of Termination for the Baton Rouge Ozone Nonattainment Area. This SIP 

revision was submitted based upon monitoring data for the years, 2006, 2007, 2008 and 2009. 

The area reached attainment of the 1-hour and the 1997 8-hour ozone NAAQS on December 31, 

2008. EPA issued a final rule on February 10, 2010 (75 FR 6570) which determined that the 

Baton Rouge 1-hour ozone nonattainment area had attained the 1-hour ozone NAAQS. A 

determination of attainment proposal for the 1997 8-hour ozone NAAQS was published on June 

25, 2010 (75 FR 36316). 

5.3: Reformulated Gasoline 

On April 24, 2003, the EPA through final rule, reclassified the Baton Rouge area to 

severe nonattainment (68 FR 20077). In this notice, the EPA listed the various requirements 

Louisiana must fulfill in order comply with the CAA. Accordingly, EPA put the area on notice 

that reformulated gasoline (RFG) would be required in the area beginning one year from the 

effective date, which was June 23, 2003. The LDEQ requested an extension to this deadline; 

EPA denied this request. Following the request denial, the Baton Rouge Chamber of Commerce 

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filed suit against EPA in this same matter. EPA's enforcement of this federal RFG requirement 

was stayed by the U.S. Court of Appeals for the Fifth Circuit on June 18, 2004. EPA agreed to 

reconsider the requirement for RFG in Baton Rouge and the U.S. Court of Appeals for the Fifth 

Circuit signed the motion to remand on August 2, 2004. 

On July 10, 2009, the US Court of Appeals for the District of Columbia, in Natural 

Resources Defense Council versus EPA (No 06-1045), ruled that “EPA’s decision to address 

site-specific data and concerns in an individual waiver proceeding, rather than in general 

rulemaking, is reasonable.” Relying on this ruling, the state of Louisiana brings forth the 

following actions as support for the continuing use of conventional gasoline in the nonattainment 

area. 

(1.) The Baton Rouge area has not yet instituted RFG as a control strategy and has since 

reached attainment of the 1-hour ozone NAAQS as well as the 1997 8-hour NAAQS. Attainment 

of these standards without the implementation of RFG stands as a weighted argument against 

having the area implement this requirement. 

(2.) In September 2002, the Energy Information Administration, division of the U.S. 

Department of Energy, issued a report on transportation fuel issues associated with proposed 

energy legislation at the request of Senator Jeff Bingaman, Chairman of the Senate Committee 

on Energy and Natural Resources. RFG was covered in this report. 

According to the report, the use of Tier 2 low-sulfur gasoline would meet or exceed the 

NOx emission reductions of RFG in either the conventional or reformulated form. The report 

continues to say that with the use of Tier II, the only benefit from RFG would be VOC and toxic 

reductions. Therefore the Baton Rouge area meets the requirements of 211(k)(2)(A) by default. 

(3.) Furthermore, in February 2006, EPA amended the RFG regulations to remove the 

oxygen content requirement and the associated compliance requirements. The effective date for 

this rule was May 5, 2006. 

(4.) According to the CAA, the benzene content of the RFG shall not exceed 1.0 percent 

by volume. (Sect 211(k)(2)(C)) However, the conventional gasoline benzene requirements were 

lowered by energy legislation in 2007. New benzene requirements put the annual average 

benzene standard at 0.62 percent by volume, which is more stringent than the requirements of the 

CAA. 

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(5.) Beginning January 1, 1996, the CAA banned the sale of leaded fuel for use in onroad vehicles. Therefore, gasoline sold in the Baton Rouge area meets Sec 211(k)(2)(D). 

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