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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 fede ral Clean Air Act’s (CAA) pollution control requirements for 1997 8-hour moderate ozone nonattainment areas, and to demonstrate attainment by J une 15, 2010. Louisiana is submitting this revision to the SIP for the Baton Rouge nonattainment area to the Environmental Protection Agency (EPA) which addresses th e CAA’s pollution control requirements as set forth in the March 21, 2008 Fede ral Register notice (73 FR 15087). On July 18, 1997, EPA promulgated a revi sed 8-hour ozone standard of 0.080 parts per million (ppm). This new standard wa s more stringent that the previous 1-hour standard. The Baton Rouge 8-hour ozone nonatta inment area consists of the parishes of Ascension, East Baton Rouge, Iberville, Livi ngston, and West Baton Rouge in southern Louisiana. The Baton Rouge area was initially designated nonattainme nt 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 ai r quality concern, is represented by the annual fourth-highest daily maximum 8-hour average ozone
concentration measured at each monitor av eraged over a three year period. The Baton Rouge nonattainment area did no t attain the 8-hour ozone standard by the June 15, 2007 deadline for marginal areas. Section 181(b)(2)(A) of the CAA provides th at, when EPA finds that an area fails to attain by the applicable date, the area is r eclassified, by operation of law, to the higher classification applicable to the area’s ozone de sign 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 m onitoring data from 2004-2006. Therefore, the Baton Rouge ozone nonattainment area wa s 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 monito red attainment and has requested a redesignation to attainment. A maintenance pl an is being submitted under separate cover.

### Further, the area has requested a formal dete rmination 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 th e 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 atta inment 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 availabl e control technology (RACT) and reasonably available control meas ures (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)).

# SECTION 1

PUBLIC NOTICE

### 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 he ld at 1:30 p.m. on September 24, 2009, in the Galvez Building, Oliver Pollock Conference R oom, 602 N. Fifth Street, Baton Rouge, LA 70802. Interested parties were invited to subm it 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.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 wh ite 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 epi sode 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 t horough documentation of the analyses performed regarding the meteorol ogical model performance is needed. Include any power point present ations or reports that are referenced in the state implement ation plan (SIP). These should be available to the public, in cluding the raw anal ysis 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 mo del performance can be found in Appendix C of the TSD.

COMMENT 4: Chapter 3 — The emi ssions discussion cites the Texas Commission on Environmental Q uality (TCEQ) 2008b. The files are no longer available on TCEQ’s ftp; therefore a mention should be included stating how the f iles can be obtained from LDEQ. Include a write-up to document what databases and assumptions were in the TCEQ emission files t hat were used for other states in the modeling domain for the 2006 and 2009 emission inventories.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, pl ots 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 C hapter 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 prov ide 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 addition al items could be pulled from the redesignation proposal and when added to this SIP revision would round out the WOE and support the m odeling conclusion that the area will be in attainment in 2009. For example, Chart 1 and Tables 1, 5, and 6 from t he Baton Rouge Ozone Redesignation and Maintenance proposed package w ould 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 mode ling for the days used in the modeled attainment test.
RESPONSE 6: Chapter 6 — These item s have now been addressed in Section 6.2 of the TSD.

COMMENT 7: Section 2.2 — Provide a t able/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 inMarch 11, 2010 Page 3 of 7 

### 40 CFR 93.118(e)(4)(iv)-(v). It will al so 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 t he nonattainment area by showing each step, discussing any assump tions made, and stating the origins of the numbers us ed in the calculations.
RESPONSE 9: Section 3 — Baton Rouge 1997 8-Hour Moderate Reclassification — No response necessary.

COMMENT 10: Section 3 — Reasonable Fu rther 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 attain ment demonstration are more stringent than the 2008 RFP budget s, 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 stri ngent than the motor vehicleMarch 11, 2010 Page 4 of 7 

### emissions in the 2008 RFP and supersede the 2008 RFP budget. The control measures used fo r RFP are found in Section 3 (Reasonable Further Progress) of the SIP and the reductions are shown in Table D-1, Se ction 3 of the SIP.

COMMENT 11: Section 3 — Contingen cy 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 — Contingen cy 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 — Contingen cy 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 Techni ques Guidelines (CTG) Rule Updates — No response necessary.

COMMENT 15: Section 5 — Reasonably Avai lable 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 demonstr ation. The state needs toMarch 11, 2010 Page 5 of 7 

### develop an adequate and thorough RACT SIP.
RESPONSE 15: Section 5 — Reasonably Av ailable Control Technology (RACT) — A RACT analysis has been includ ed in the final submittal.

COMMENT 16: Section 5 — Reasonably Available Control Measures (RACM) Demonstration — A statement abou t RACM in the context of RACT should be included in order to adequately discuss the required elements of RACT.

RESPONSE 16: Section 5 — Reasonabl y Available Control Measures (RACM) Demonstration — A RACM analysis has been included in the final submittal.

COMMENT 17: Section 5.1 — Major S ource 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 applic able reference has been made.

COMMENT 18: Section 5.1 — Major S ource Permits and Nonattainment New Source Review — Severe nona ttainment NSR requirements should be implemented in Baton Rouge.
RESPONSE 18: Section 5.1 — Major S ource 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 requir ed 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

.March 11, 2010 Page 6 of 7



### COMMENT 20: Section 5.3 — Reformulat ed Gasoline (RFG) — The state should consider what the impact on t he maintenance projections would be if RFG is implemented at some future date.

RESPONSE 20: Section 5.3 — Reformul ated Gasoline (RFG) — The state has considered the impact of the use of reform ulated gasoline in the Baton Rouge nonattainment area (BRNA). Modeling in June of 2004 indicated that the use of RFG would increase nitrogen oxide (NO x 

### ) 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 NO x 

### limited area.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

## Section 2, Attainment Demonstratio n, is in a separate document

# SECTION 3

REASONABLE FURTHER PROGRESS

### 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 th e 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 BR NA 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

### 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 BR NA 2002 inventory are described in the document “2002 Base Year Emissions Inventory for the Baton Roug e 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 4 5.3 2 6.5 Biogenic 0.0 99.6 Total 200.3 2 11.0

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

co ntrols between milestone years.

### 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 5 1.0 26.5 2 9.0

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 an d/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 B ase 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.

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

Description N Ox, TPD VOC , TPD Step 1: 2002 Base Year Inventory 200.3 211.0 Step 2: E missions from B iogenic S ources 0.0 99.6 Step 2a: Calculate the 2002 RFP Base Year Inventory (Step 1 minus Step 2) 200.3 1 11.4 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 10 7.0 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: Calculat e the 2008 Target Levels (Step 4 minus Step 5a) 16 4. 8 10 7.0

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.

### 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

- 11.5 4

- 4.1 5

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, recordkeepin g 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

### 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 sev ere , 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 remain ed 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 w ith EPA’s current version of the onroad emissions model, MOBILE6. Below is a brief summary of these mobile source control programs.

### (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 B RNA 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.

### 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 14 3. 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 N Ox an d/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) 16 4.3 10 3.5 Projected 2008 RFP Milestone Year Emissions (Table C

- 3) 1 4 3. 8 101.3 Are Mileston e Year Emissions less than Target Level of Emissions? Yes Yes Excess 2 0.5 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) 19 3. 9 10 3.5 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 1 4.7 2.2

# 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

## 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

### 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 Facility na 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 2007 (TPY) 2002 (TPY)

### 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 2007 (TPY) 2002 (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

### 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 2007 (TPY) 2002 (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.

## 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

## 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.

## 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

## 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

## 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

# SECTION 4

CONTINGENCY PLAN

## 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 th e applicability of the s tate’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.

### 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 Reforme rs

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.

### 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 Po int 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 200 8 (RFP

– Section B.4) 193.3 Maintenance Plan Contingency Require ment, 3% 5.8 Estimated Reduction from Contingency Measure 15 .9 Are Estimated Reductions Greater than the Contingency Requirement ? Yes Contingency Excess 10 .1

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

# Section 4 Appendix

Certified NOx Pollutant Emissions (tpy) by FacilityAppendix - 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 0.1Appendix - 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 2.0Appendix - 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 32.2Appendix - 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 15.9Appendix - 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: 1. Facilities in RED font ran in 2002 and were either shutdown or below reporting limit by 2006. 299.8 TPY 2. Facilities in GREEN font did not exist or were below the reporting limit in 2002 and new by 2006. 249.5 TPY

# SECTION 5

OUTSTANDING REQUIREMENTS

### 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 stan dard 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 classifica tion of "severe". This classifi cation brought with it new control measure requirements, one of which set the permitt ing 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 appli cable 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 design ation classification un der 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 date d April 29, 2009, from Lawrence E. Starfield, Acting Regional Administrator of EPA Re gion 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 cour t 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

### of Air & Radiation informed Regiona l Administrators that the decision effectively restored NSR applicability thresholds and emission offsets in ozone nonattainment areas pursuant to cl assifications previously in effect for the 1-hour standard. The memora ndum strongly encouraged States to comply with the court's decision in a timely manner.

In accordance with this memorandum, EPA expect s 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 additi on, 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 base d 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 thres hold of 50 TPY to ensure that the severe area major source threshold is a pplied to new sources and that those existing sources above the severe thre shold have obtaine d the appropriate NSR/PSD and/or Title V operating perm its. 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 sour ce” threshold at 100 tons per year (TPY) of NO x 

### or VOC and the “major modificat ion significant net increase threshold” at 40 TPY of NO x 

### or VOC for the purpose of determining whet her “netting” is requir ed and if a “net emissions increase” is considered significant. The mi nimum offset ratio is 1.15 to 1. LDEQ’s NNSR rules, however, are more stringent than ot herwise 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 NO x 

### or VOC and the “major modifi cation significant net increase
threshold” at 25 TPY of NO x 

### 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 we re applied, the NNSR “major st ationary source” threshold applicable in the BRNA would be reduced to 25 TPY of NO x 

### or VOC, and consideration of the
“net emissions increase” would be re quired for projects resulting in a NO x 

### or VOC increase of

### only 5 TPY. Further, the minimum offset ra tio 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 NO x 

### and/or VOC emissions of 25 TPY or more and not already classified as “Part 70 sources”) would be requi red 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 app lications. 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 mode rate attainment deadline without the institution of the severe area threshold implementation.

5.2: Section 185 Fees
Section 185 of the CAA requires each major st ationary source in any severe or extreme ozone nonattainment area to pay a fee to the stat e as a penalty for failur e to attain the ozone NAAQS. This provision is part of the original 1990 CAA Amen dments (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 specifica lly directed towards majo r 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 promulgati on 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 implementati on. 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 author ization with the applicable ex ceptions 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 reducti ons would not be a di rect result of its implementation. The

### courts in the South Coast case did not agree with EPA’s assertion and the Section 185 fees were
re-established as anti-backslid ing criteria for t hose 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 s hould be considered an adequate alternative program. Our reasoning fo llows from the fact that an area’s existing SIP measures, in conjuncti on 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 da ta 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 th e 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 th e CAA. Accordingly, EP A 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 extensi on to this deadline; EPA denied this request. Following the reques t denial, the Baton Rouge Chamber of Commerce

### 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 ru ling, the state of Louisi ana brings forth the following actions as support for the continuing us e of conventional gasolin e 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 Informa tion Administration, di vision 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. RF G was covered in this report. According to the report, the use of Tier 2 lo w-sulfur gasoline would meet or exceed the
NOx emission reductions of RFG in either the conventional or re formulated form. The report continues to say that with the use of Tier II, the only benefit from RF G would be VOC and toxic reductions. Therefore the Baton Rouge area meets th e requirements of 211(k)(2)(A) by default. (3.) Furthermore, in February 2006, EPA am ended the RFG regulations to remove the oxygen content requirement and the associated comp liance requirements. The effective date for this rule was May 5, 2006. (4.) According to the CAA, the benzene cont ent of the RFG shall not exceed 1.0 percent by volume. (Sect 211(k)(2)(C)) However, the conventional gasoline ben zene 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 stri ngent than the requirements of the
CAA.

### (5.) Beginning January 1, 1996, the CAA banned th e sale of leaded fuel for use in onroad vehicles. Therefore, gasoline sold in the Baton Rouge area meets Sec 211(k)(2)(D).