## DRAFT

2007 Regional SO 2 

## Emissions and Milestone Report

December 23, 2008

Arizona

Corky Martinkovic

Arizona Dept. of Environmental Quality

Air Quality Divisi on, Planning Section

1110 West Washington Street

Phoenix, AZ 85007

Fax: 602-771-2366

dam@azdeq.gov City of Albuquerque

Dario W. Rocha

City of Albuquerque

Air Quality Division

P.O. Box 1293

Albuquerque, NM 87103

Fax: 505-768-1977

drocha@cabq.gov

New Mexico

Ronald Duffy

New Mexico Environment Department

Air Quality Bureau

2048 Galisteo St.

Santa Fe, NM 87505

Phone: 505-955-8011

Fax: 505-827-1543

ronald.duffy@state.nm.us Utah

Kimberly Kreykes

Utah Department of Environmental Quality

Division of Air Quality

150 North 1950 West

Salt Lake City, UT 84114-4820

Phone: 801-536-4042

Fax: 801-536-0085

kkreykes@utah.gov

Wyoming

Brian Bohlmann, P.E.

Wyoming Department of Environmental

Quality, Air Quality Division

Herschler Building, 2-East

122 West 25th Street

Cheyenne, Wyoming 82002

Phone: 307-777-6993

Fax: 307-777-7682

bbohlm@wyo.gov

### December 23, 2008

ES-1 Based on the adjusted milestone and

emissions data, the average of 2005,

2006, and 2007 emissions is about

33% below the 2007 four state

regional milestones. 

## DRAFT

2007 Regional SO 2 

## Emissions and Milestone Report

Executive Summary

Under Section 309 of the federal Regional H aze Rule, nine western states and tribes

within those states have the option of submitti ng plans to reduce regional haze emissions that

impair visibility at 16 Class I national parks and wilderness areas on the Colorado Plateau. Five

states -- Arizona, New Mexico, Oregon, Utah, and Wyoming -- initially exercised this option by

submitting plans to EPA by December 31, 2003. Ore gon elected to cease pa rticipation in the

program in 2006. The tribes were not subject to th e deadline and still can opt into the program at

any time. Under the Section 309 plans, the four remaining participating states have tracked the

emissions of the applicable stationary sources as part of the pre-trigger portion of the SO 2 

### Milestone and Backstop Trading Program. Th e Western Regional Air Pa rtnership (WRAP) is

assisting these states with the implementa tion and management of the regional emission

reduction program.

As part of this program, th e participating states must s ubmit an annual Regional Sulfur

Dioxide (SO 2 

### ) Emissions and Milestone Report that co mpares emissions to milestones. A

milestone is a maximum level of annual emi ssions for a given year. The first report was

submitted in 2004 for the calendar year 2003.

This year, the four part icipating states have either revi sed their Section 309 plans or are

currently in the process of revi sing their plans. The revised pl ans modified the annual regional

milestone for 2007. Because two of the four stat es are currently operating under revised rules,

this transition year report compares annual em issions to 2007 milestones under both the revised

and 2003 plans. All states are expected to ha ve revised plans by next year's report.

The four-state region milestone for 2007 is 422,194 tons under the original 2003 plans,

and 420,637 tons under the revised plans. To dete rmine whether or not the milestone was met,

the 2005, 2006, and 2007 adjusted emissions were av eraged, and this average was compared to

the 2007 milestones. Oregon's emissions were re moved from the 2005 emission totals before the

average was calculated, to stay consistent with the 2006 and 2007 emissions total. The

adjustments to reported emissions were required to allow the current emission estimates to be

comparable to the emissions monitoring or calcu lation method used in the initial base year

inventory (1999 for utilities and 1998 for all other sources).

The states of Arizona, New Mexico, Utah,

and Wyoming reported 257,234 tons of SO 2 

### emissions for the calendar year 2007. The total

emissions increased to 273,663 tons of SO 2 

### after

making adjustments to account for changes in

monitoring and calculation methods. The

adjustments result in an additional 16,429 tons of

SO 2 

### emissions, which is about 6% of the report ed total emissions. Adjustments required for

### Executive Summary

December 23, 2008

ES-2 changes in Part 75, Acid Rain Program, flow monitor quality assurance methods account for

about 15,225 tons (93%) of the increase in the estimate, with the remaining 1,204 tons from

other types of monitoring and calculation method changes. The adjusted emissions values for

2005 and 2006 were 288,040 tons and 279,134 tons, respectively. The 2007 adjusted emissions

total of 273,663 tons was lower than both the 20 05 and 2006 adjusted annual emissions. The

average of 2005, 2006, and 2007 adjusted emissions is 280,279 tons.

Based on this average adjusted annual emi ssions estimate, a preliminary determination

has been made that the four states have met the 2007 regional SO 2 

### milestone under both the 2003

and revised plans. The plans cont ain provisions to adjust the mile stones to reflect variations in

smelter operations, and to account for enforcemen t actions (to reduce th e milestones where an

enforcement action identified that emissions in the baseline period were greater than allowable

emissions). Based on emissions data received from the states and SIP requirements regarding

adjustments to the milestones, the 2007 peri od requires a smelter ad justment under the 2003

plans (increasing the regional milestone by 2,000 t ons); no smelter adjustment is required under

the revised plans.

The plans also require that the annual repor t identify changes in the source population

from year to year and significant changes in a source's emissions from year to year. The

significant emission changes from 2006 to 2007 are incl uded in Section 7 of this report. A list of

facilities added to or removed from the list of subject sources included in the base year

inventories is included in Appendix B.

### Executive Summary

December 23, 2008

ES-3 Table ES-1

Overview of 2007 Regional Milestones and Emis sions for Section 309 Participating States

2007 Sulfur Dioxide Milestones

Revised SIPs

Regional 2007 Milest one* ....................................................................................................... ............... 420,637 tons

Smelter-specific Set-aside* .................................................................................................. ............... 0 tons

Adjusted Four-State 2007 Milestone............................................................................................. .......... 420,637 tons

2003 SIPs

Regional 2007 Milest one* ....................................................................................................... ............... 420,194 tons

Smelter-specific Set-aside* .................................................................................................. ........ 2,000 tons

Adjusted Four-State 2007 Milestone............................................................................................. .......... 422,194 tons



### 2007 Sulfur Dioxide Emissions

Reported Four-State 2007 Emissions ............................................................................................ ......... 257,234 tons

Adjustments**

Part 75 Flow RATA Procedures 15,225 ton

Other Emission Monitoring and Calculation Methods 1,204 to n Adjusted Four-State 2007 Emissions 273,663 to n



### Average Sulfur Dioxide Emissions (2005, 2006, & 2007)

Adjusted Four-State 2007 Emissions ............................................................................................ ......... 273,663 tons

Adjusted Four-State 2006 Emissions ............................................................................................ ......... 279,134 tons

Adjusted Four-State 2005 Emissions ............................................................................................ ......... 288,040 tons

Average of 2005, 2006, & 2007 Adjust ed Four-State Em issions ........................................................... 280,279 tons



### Comparison of Emissions to Milestone

Average of 2005, 2006, & 2007 Adju sted Four-State Emissions............................................................ 280,279 tons

Adjusted Four-State 2007 Milestone Re vised SIPs ................................................................................ 420



### , 637 tons

Adjusted Four-State 2 007 Milestone 2003 SIPs ................................................................................... .. 422,194 tons

Difference (negative value = emissions < milestone) Revised SIPs ..................................................... -140,358 tons

Difference (negative value = emissions < milestone) 2003 SIPs .......................................................... -141,91 5 tons

2005 - 2007 Emissions Average as Pe rcent of 2007 Revise d SIP Mile stone........................................................6 7%

2005 - 2007 Emissions Average as Percent of 2007 200 3 SIP Mile stone ............................................................ 66%

* See the Regional Milestones s ection of each state's 309 SIP.

** See the Annual Emissions Re port section of each state's 309 SIP.

### Executive Summary

December 23, 2008

ES-4 [This page intentionally left blank.]

### December 23, 2008

1 

## 2007 Regional SO 2 

## Emissions and Milestone Report

1.0 Introduction

1.1 Background

Under Section 309 of the federal Regional Haze Rule (40 CFR Part 51), nine western

states and the tribes within those states have the option of submitting plans to reduce regional

haze emissions that impair visibility at 16 Cl ass I national parks and wilderness areas on the

Colorado Plateau. Five states -- Arizona, Ne w Mexico, Oregon, Utah, and Wyoming -- and the

city of Albuquerque, New Mexico exercised this option by submitting plans to EPA by

December 1, 2003. Oregon has since electe d to cease participation in the SO 2 

### Milestone and

Backstop Trading Program by not resubmitting a Section 309 SIP. The tribes were not subject to

this deadline and still can opt into the program at any time.

Under the Section 309 State Implementation Plan s (SIPs), these four states have been

tracking emissions under the pre-tr igger requirements of the SO 2 

### Milestone and Backstop

Trading Program since 2003. The We stern Regional Air Partnershi p (WRAP) is assisting these

states with the implementation and management of this regional emission reduction program.

Under the milestone phase of the program, the states have established annual SO 2 

### emissions targets (from 2003 to 2018). These vo luntary emissions reduction targets represent

reasonable progress in reducing the emissions that contribute to regional haze. If the

participating sources fail to meet the milestone s through this voluntary program, then the states

will trigger the backstop trading program and implement a regulatory emissions cap for the

states, allocate emissions allowa nces (or credits) to the affect ed sources based on the emissions

cap, and require the sources to hold sufficient allowances to cover their emissions each year.

This report is the fifth annual report for the milestone phase of this program. The report

provides background on regional haze and the Se ction 309 program, the milestones established

under the program, and the emissions reported for 2007. Based on the first five years, the

voluntary milestone phase of the program is wo rking, and emissions are well below the target

levels.

What is Regional Haze ?

Regional haze is air pollution th at is transported long distance s and reduces visibility in

national parks and wilderness areas across the countr y. Over the years, this haze has reduced the

visual range from 145 kilometers (90 miles) to 24-50 kilometers (15-31 miles) in the East, and

from 225 kilometers (140 miles) to 56-145 kilome ters (35-90 miles) in the West. The pollutants

that create this haze are sulf ates, nitrates, organic carbon, elemental carbon, and soil dust.

Human-caused haze sources include industry, moto r vehicles, agricultural and forestry burning,

and windblown dust from roads and farming practices.

### Draft Report

December 23, 2008

2 What U.S. EPA Requirements Apply ?

In 1999, the Environmental Protection Agency (EPA) issued regulations to address

regional haze in 156 national parks and wilderne ss areas across the countr y. These regulations

were published in the Federal Register on July 1, 1999 (64 FR 35714). The goal of the Regional

Haze Rule (RHR) is to eliminate human-caused visibility impairment in national parks and

wilderness areas across the country. It contains strategi es to improve visibility over the next 60

years, and requires states to adopt implementation plans.

EPA's RHR provides two paths to address re gional haze. One is 40 CFR 51.308 (Section

308), and requires most states to develop long -term strategies out to the year 2064. These

strategies must be shown to make "reasonable pr ogress" in improving visibi lity in Class I areas

inside the state and in neighbor ing jurisdictions. The other is 40 CFR 51.309 (Section 309), and

is an option for nine states -- Arizona, Ca lifornia, Colorado, Idaho, Nevada, New Mexico,

Oregon, Utah, and Wyoming -- and the 211 tribes lo cated within these states to adopt regional

haze strategies for the period from 2003 to 2018. These strategies are based on

recommendations from the Grand Canyon Visi bility Transport Co mmission (GCVTC) for

protecting the 16 Class I areas on the Colorado Pl ateau. Adopting these strategies constitutes

reasonable progress until 2018. These same strategi es can also be used by the nine western

states and tribes to protect the other Cla ss I areas within their own jurisdictions.

EPA revised the RHR on July 6, 2005 ( 70 FR 39104), and again on October 13, 2006 (71

FR 60612) in response to two legal challenge s. The October 13, 2006 revisions modified

Section 309 to provide a methodol ogy consistent with the Court's decision for regional

alternatives like the strategy base d on the GCVTC recommendations.

How Have the WRAP States Re sponded to EPA Requirements ?

Of the nine states (and trib es within those states) that have the option under Section 309

of participating in a regi onal strategy to reduce SO 2 

### emissions, five states had originally

submitted Section 309 SIPs to EPA. These stat es were Arizona, New Mexico, Oregon, Utah,

and Wyoming. In addition, the City of Albuquer que had also submitted a Section 309 SIP.

EPA, however, never approved these SI Ps due to the legal challenges.

Oregon has opted out of submitting a revise d Section 309 SIP under the modified RHR,

which leaves four participating states. Utah and Wyoming have already submitted revised SIPs

to EPA, and Arizona and New Mexico are in th e process of revising th eir SIPs. To date, no

tribes have opted to participate under Section 309, and the other four states of the original nine

opted to submit SIPs under Section 308 of the RHR.

The following summarizes a few key elements of the Section 309 process for the four

states:

1. Section 309(d)(4)(i) requires SO 2 

### milestones in the SIP, a nd includes provisions for

making adjustments to these milestones if necessary. The milestones must provide for

steady and continuing emission reductions through 2018, and provide for greater

reasonable progress than the provisions of Section 308.

### Draft Report

December 23, 2008

3 2. Section 309(d)(4)(iii) requires monitori ng and reporting of stationary source SO 2



### emissions in order to ensure the SO 2 

### milestones are met. The SIP must commit to

reporting to the WRAP as well as to EPA.

3. Section 309(d)(4)(iv) requires that a SIP cont ain criteria and proce dures for activating the

trading program within 5 year s if an annual milestone is exceeded. A Section 309 SIP

also must provide assessments in 2013 and 2018.

This report responds to Item 2, above, and pr ovides the annual report that compares the

2007 emissions against the milestones for the stat es that have submitted Section 309 SIPs to

EPA.

What Elements Must the Regional SO 2 

### Emissions and Milestone Report Contain ?

To facilitate compliance with the Sec tion 309 SIPs, the WRAP has committed to

compiling a regional report on emissions for each y ear. In accordance with the SIPs, the WRAP

will compile the individual state emission report s into a summary report that includes:

1. Reported regional SO 2 

### emissions (tons/year).

2. Adjustments to account for:

● Changes in flow rate measurement methods;

● Changes in emissions monitori ng or calculation methods; or

● Enforcement actions or settlement agreem ents as a result of enforcement actions.

3. As applicable, average adjusted emissions for the last three years (w hich are compared to

the regional milestone). Since this is th e fifth report, 2005, 2006, and 2007 emissions are

averaged.

4. Regional milestone adjustments to account for production increases at certain smelters.

How Is Compliance with the SO 2 

### Milestone Determined ?

While the WRAP assists with the preparati on of this report, each state reviews the

information in the report, and proposes a draft determination that the regional SO 2 

### milestone has

either been met or exceeded. The draft determ ination is then submitted for public review and

comment during the first part of 2009, culminati ng in a final report sent to EPA by March 31,

2009.

SIP Transition Period and Milestones

The revised SIPs modified the annual regi onal milestone for 2007. Because only two of

the four states are operating unde r revised rules, this report in cludes comparisons to milestones

under both the revised and the 2003 SIPs. All states are expected to have revised SIPs by next

year's report.

### Draft Report

December 23, 2008

4 1.2 Report Organization

This report presents the regional SO 2 

### emissions and milestone information required by

the 309 SIPs for the four states. The report is divided into the following sections, including two

appendices:

● Reported SO 2 

### Emissions in 2007;

● Monitoring Methodology Emissions Adjustments;

● Three-year Average Emissions;

● Enforcement Milestone Adjustments;

● Smelter Milestone Adjustments;

● Quality Assurance (including Source Change information);

● Preliminary Milestone Determination;

● Appendix A - Facility Emissions and Emissions Adjustments; and

● Appendix B - Changes to SO 2 

### Emissions and Milestone Source Inventory.

2.0 Reported SO 2 

### Emissions in 2007

All stationary sources with reported emissi ons of 100 tons or more per year in 2000 or

any subsequent year are re quired to report annual SO 2 

### emissions. Table 1 summarizes the annual

reported emissions from applicable sour ces in each state. The 2007 reported SO 2 

### emissions for

each applicable source are in Appendix A, Table A-1.

Table 1

Reported 2007 SO 2 

### Emissions by State

State Reported 2007 SO 2 

### Emissions (tons/year)

Arizona 85,922

New Mexico 30,786

Utah 30,733

Wyoming 109,793

TOTAL 257,234



### 3.0 Monitoring Methodol ogy Emissions Adjustments

The annual emissions reports for each stat e include proposed emissions adjustments to

ensure consistent comparison of emissions to the milestones. The adjustments account for any

differences in emissions that result from changes in the monitoring or calculation methodology

used in 2007 as compared to the methodology us ed to calculate baselin e year emissions (1998

and 1999). The following sections detail what adjustments apply for 2007. Note that the revised

Section 309 SIPs establish new milestones fo r 2008-2018 using an updated baseline of 2006.

### Draft Report

December 23, 2008

5 Therefore, the adjustments described in the following sections will not be performed in

subsequent reports under th e revised SIPs.

3.1 Changes in Part 75 Flow Rate Methodology

The Section 309 SIPs spell out three specifi c methods for adjusting Part 75 Acid Rain

Program electric generating unit em issions due to changes in quali ty assurance procedures for

the flow monitor component of SO 2 

### continuous emission monitori ng systems. These changes

involve the use of new flow re ference methods in the Relative Accuracy Test Audit (RATA),

which were not available in the 1999 baseline year. The use of these new methods (reference

methods 2F, 2G, 2H, and 2J) are expect ed to result in a decrease in the SO 2 

### emissions

measurement.

The three methods in the SIPs for adjusti ng for flow RATA reference method changes are

outlined below:

1. Directly determine the difference in flow ra te through a side-by-side comparison of data

collected with the new and old flow reference methods during a RATA test.

2. Compare the annual average heat rate using Ac id Rain heat input data (mmBtu) and total

generation (MWhrs) as reported to the federa l Energy Information Administration (EIA).

Under this approach, the flow adjustment f actor shall be calculated using the following

ratio:

Heat input/MW for first full year of data using new flow rate method

Heat input/MW for last full year of data using old flow rate method



### 3. Compare the standard CFM per MW before and after the new flow reference method

based on CEM data submitted in the Acid Rain Program, as follows:

SCF/Unit of Generation for first full year of data using new flow rate method

SCF/Unit of Generation for la st full year of data using old flow rate method



### New Mexico, Utah, Arizona, and Wyoming provi ded adjusted emissions for changes in

the Part 75 flow RATA reference method for seve ral plants: the Public Service Corp of New

Mexico San Juan plant and the Tri-State Escalante plant in Ne w Mexico; the PacifiCorp Carbon,

Hunter, and Huntington plants a nd the Intermountain Power Servic e Corporation plant in Utah;

the AEPCO Apache Station and Pinnacle West - C holla Generating Station in Arizona; and the

Pacificorp Dave Johnston, Jim Bridger, Naughton, and Wyodak plants in Wyoming. Changes in

the RATA flow reference method result in an upward adjustment for the 2007 SO 2 

### emissions of

15,225 tons.

The adjustment for each of these plants is listed below in Table 2. The Appendix table

A-1 provides additional information on the flow RATA reference method changes, and which

adjustment method was used for each plant.

### Draft Report

December 23, 2008

6 Table 2

Adjustments for Changes in Part 75 Flow RATA

State Source Reported 2007

SO 2 

### Emissions

(tons) Flow RATA

Adjustment

(tons) Adjusted 2007

SO 2 

### Emissions

(tons)

AZ AEPCO - Apache Station 2,662 2,675 13

AZ Pinnacle West - Cholla Generating

Station 23,522 23,650 128

NM Public Service Co. of New

Mexico/San Juan Generating

Station 15,305 17,683 2,378

NM Tri-State Gen &

Transmission/Escalante Station 1,124 1,591 467

UT Intermountain Power Service

Corporation - Intermountain

Generation Station 4,764 4,788 24

UT PacifiCorp - Carbon Power Plant 6,511 7,537 1,026

UT PacifiCorp - Hunter Power Plant 6,672 7,658 986

UT PacifiCorp - Huntington Power

Plant 4,351 4,931 580

WY PacifiCorp - Dave Johnston 21,356 25,791 4,435

WY PacifiCorp - Jim Bridger 19,053 20,486 1,433

WY PacifiCorp - Naughton 21,588 24,873 3,285

WY PacifiCorp - Wyodak 7,835 8,305 470



### 3.2 Changes in Emissions Monitoring and Calculation Methodology

In addition to the specific flow reference method related requirement for Part 75 program

sources, there is also a genera l requirement to account for any changes in emissions monitoring

or calculation methods. Th e reported emissions are adjusted so that the adjusted emissions levels

are comparable to the levels that would result if the state used the same emissions monitoring or

calculation method that was used in the base ye ar inventory (1999 for utilities and 1998 for all

other sources). The net impact throughout the re gion as a result of these adjustments is an

increase of 1,204 tons from the reported 2007 emi ssions. Table 3 summarizes these results, and

Appendix A provides additional source information. Some key aspects of the adjustments

include:

● Utah adjusted their emissions upward by 338 tons.

● Wyoming adjusted their emissions downward by 284 tons.

### Draft Report

December 23, 2008

7 ● Arizona did not report any emissions adjustments.

● The city of Albuquerque, New Mexico report ed that plant baseline emissions were

incorrect for two facilities, which should not have been included in milestone

calculations. In each case, the 1998 baseline emissions were based on the facility

potential to emit, and not on reported emissions, which were less than 100 tons per year

in 1998 and in each year since then. Thus , their emissions would not typically be

included in this report, but until the milestones can be revised in the next SIP revision to

correct the baseline error, these sources will be included and adjusted up to their potential

to emit so that "paper decr eases" in emissions are not counted towards meeting the

milestones. The adjustment increased emissions by 1,150 tons.

● New Mexico did not have information on th e baseline year emissi ons calculation and

monitoring methodologies, and thus did not make any adjustments for facilities under the

state's jurisdiction. The 1998 baseline year corresponded to a period when New Mexico's

inventory relied on the sources to calculate and report emissions. Also, during that

period, New Mexico prepared an emissions inventory every ot her odd year (1997 and

1999).

### Draft Report

December 23, 2008

8 Table 3

Adjustments for Changes in Monitoring Methodology

(Albuquerque, New Mexico, Utah, and Wyoming)

State Source Reported

2007 SO 2



### Emissions

(tons) Adjusted

2007 SO 2



### Emissions

(tons) Monitoring

Methodology

Adjustment

(tons) Comment

NM GCC Rio Grande

Cement 16 1,103 1,087 Facility potential to emit

was used for the baseline

year calculation.

Adjustment is equal to the

difference between

reported and potential

emissions.

NM Southside Water

Reclamation Plant 57 120 63 Facility potential to emit

was used for the baseline

year calculation.

Adjustment is equal to the

difference between

reported and potential

emissions.

UT Chevron Products Co. -

Salt Lake Refinery 1,104 1,085 -19 AP42 emission factor

changed. In calculating

flares, method changed

from AP42 to engineering

data.

UT Graymont Western US

Inc. - Cricket Mountain

Plant 31 415 384 AP42 emission factors

changed. Method of

calculating kiln emissions

changed from permit limit

to stack test.

UT Tesoro West Coast -

Salt Lake City Refinery 909 878 -31 Reported emissions

include SO 3 . SO 3 was not

included in 1998.

UT Holly Ref. - Phillips

Refinery 579 582 3 Changed in the estimation

method from AP42 in

1998 to CEM.

WY Burlington Resources -

Lost Cabin Gas Plant 2,461 2,459 -2 Change in the calculation

method for emissions from

the Train 3 sulfur pit.

WY Solvay Chemicals -

Soda Ash Plant (Green

River Facility) 56 104 48 Change in calculation

method from base year.

WY Sinclair Oil Company -

Sinclair Refinery 1,035 705 -330 FCC unit used stack test

and hours of operation in

1998; went to CEM in

2004.

### Draft Report

December 23, 2008

9 4.0 Three-Year Average Emissions (2005, 2006, and 2007)

The SIPs require multi-year averaging of em issions from 2004 to 2017 for the milestone

comparison. From 2005 to 2017, a three-year aver age (which includes the reporting year and the

two previous years) will be calculated to compar e with the milestone. The average of the three

years' emissions from 2005 to 2007 is 280,279 tons. Table 4 shows the adjusted emissions for

each year and three year average emissions. The following report sections describe the adjusted

milestone determination.

Table 4

Average Sulfur Dioxide Emissions (2005, 2006, & 2007)

Year Adjusted SO 2 

### Emissions (tons/year)

2005 288,040

2006 279,134

2007 273,663

Three Year Average (2005, 2006, 2007) 280,279



### 5.0 Enforcement Milestone Adjustments

The SIPs require that each st ate report on proposed milestone adjustments that are due to

enforcement actions, which affect baseline year em issions. The purpose of this adjustment is to

remove emissions that occurred above the allowabl e level in the baseline year from the baseline

and the annual milestones. The enforcement milestone adjustments require an approved SIP

revision before taking effect.

Enforcement Milestone Adjustment

There were no proposed enforcement action related milestone adjustments reported for

2007.

6.0 Smelter-Specific Set-Asi de Milestone Adjustments

Smelter Adjustment Scenarios

Each state or tribe determines the amount of fac ility specific set-aside, if any, that will be

added to the milestone to account for operational increases at th e remaining smelters in the

region. This set-aside is only available for use if the annual sulfur input and emissions from the

copper smelter is above the baseline levels listed in the applicable SIP. The increase to the

milestone is based on a smelter's proportional in crease above its baseli ne sulfur input.

### Draft Report

December 23, 2008

10 The revised Section 309 SIPs establish ne w updated milestones for the years 2008 - 2018.

This update revised the baseline year, and also changed the smelte r-specific set-aside table. For

purposes of this milestone report, both the old and new baseline year a nd smelter specific setasides were used to calculate 2007 milestones c onsistent with both SIP methodologies.

2007 Smelter Adjustment - 2003 SIPs

A comparison of smelter 2007 emissions to baseli ne levels in the milestone section of the

2003 SIPs is provided in Table 5, and shows that the Phelps Dodge Miami smelter in Arizona is

the only operating smelter with reported 2007 SO 2 

### emissions above the baseline emissions.

Table 5

Smelter 2007 SO 2 

### Emissions and Baseline SO 2 

### Emissions

State Source Reported 2007 SO 2 

### Emissions (tons) SO 2 

### Baseline Emissions

(tons)

AZ BHP San Manuel 0 16,000

AZ Asarco Hayden 20,339 23,000

AZ Phelps Dodge Miami 9,111 8,000

NM Phelps Dodge Hurley 0 16,000

NM Phelps Dodge Hidalgo 0 22,000

UT Kennecott Salt Lake 975 1,000



### The sulfur throughput for the Phelps Dodge Miami smelter in 2007 was also greater than

the baseline throughput, triggering the smelter adjustment. The emissions and throughput

comparisons, and the smelter adju stment calculation for Phelps Dodge Miami are shown in Table

6. The adjustment based on a comparison of 2007 sulfur throughput to baseline sulfur

throughput is 2,480 tons. This is greater than th e available set-aside of 2,000 tons, and thus only

an amount up to the 2,000 tons set-asid e is allowable per the Arizona SIP.

### Draft Report

December 23, 2008

11 Table 6

Phelps Dodge Miami - Smelter Adjustment

SO 2 

### Emission Comparison

2007 Reported Emissions........................................................................................................ .................... 9,111 tons

Baseline Em issions............................................................................................................. ......................... 8,000 tons

Reported 2007 emissions are 1,111 tons greater than baseline emissions.



### Sulfur Throughput Comparison

2007 Sulfur Throughput......................................................................................................... ................. 274,150 tons

Baseline Sulfur Throughput* .................................................................................................... .............. 208,700 tons

2007 Through put Increase ....................................................................................................... ..................65,450 tons

2007 Throughput Increase as a Percent of Base line Thro ughput................................................................... .......31%



### Smelter Adjustment

2007 Calculated Adjustment (Baseline Emissions x Percent Throughput Increase)** .............................. 2,480 tons

Smelter Set-Aside* ............................................................................................................. ........................ 2,000 tons

2007 Adjustment (The lesser of the Calculat ed Adjustment or Se t-Aside)** ............................................ 2,000 tons

* See the Arizona SIP, Table 8-3 (Table 3 in the 2003 Model SIP)

** See Arizona SIP, Section 8.1.3(4)(e)



### 2007 Smelter Adjustment - Revised SIPs

The smelter baseline has decreased, from 86,000 tons SO 2 

### in the 2003 SIPs to 24,000

tons SO 2 

### in the revised SIPs, due to the permanent closure of the BHP San Manuel, Phelps

Dodge Chino, and Phelps Dodge Hidalgo smelters. The revised set-aside is only available if

sulfur input and emissions from an individual copper smelter is above the baseline level listed in

Table 7 in any particular year as a result of increased capacity. The Phelps Dodge Miami smelter

is not included in Table 7 because the smelter is currently operating at its permitted limit, and

therefore does not have a smelter-specific set-aside.

Table 7

Revised SIP - Smelter Baselines and Set-Aside

State Source Baseline Sulfur

Input

(tons S) Baseline

Allocation

(tons SO2) Smelter Specific

Set-Aside

(tons SO2)

AZ Asarco Hayden 235,000 23,000 3,000

UT Kennecott Salt Lake 340,269 1,000 100

Total 575,269 24,000 3,100

### Draft Report

December 23, 2008

12 A smelter set-aside is not available fo r 2007 under the revised SIPs. The 2007 emissions

from the Asarco Hayden and Kennecott smelters (s ee Table 6) are below the baseline allocations

in Table 7.

7.0 Quality Assurance

The states provided 2007 emissions data based on their state emissions inventories. For

this report, additional quality assurance (QA) procedures were used to supplement the normal

QA procedures the states follow for their emissions inventories. First, each state submitted a

source change report, and second, the states compared their inve ntory data for utility sources

against 40 CFR Part 75 Acid Ra in Program monitoring data.

7.1 Source Change Report

The SIPs require that this annual SO 2 

### emissions and milestone report include a

description of source changes or exceptions report to identify:

● Any new sources that were not contained in the previous calendar year's emissions report,

and an explanation of why the sour ces are now included in the program;

● Identification of any sources that were includ ed in the previous year's report and are no

longer included in the program, and an explan ation of why this change has occurred; and

● An explanation for emissions variations at any applicable source that exceeds ± 20

percent from the previous year.

No sources were added to the program inve ntory in 2007. Phelps Dodge Hidalgo smelter

and Phelps Dodge Hurley smelter/concentrator were both closed in 2006, but are being included

in the inventory for the smelter adjustment. Ap pendix B provides a list of all sources added or

removed from the program inventor y in previous reporting years. Table 8 provides explanations

for the emissions variations from 2006 - 2007 that are greater than 20 pe rcent. Plants with

variations greater than 20 percent, but reported emissions of less than 20 tons, are not included in

Table 8. Information on these plan ts is provided in Appendix A.

### Draft Report

December 23, 2008

13Table 8Sources with an Emissions Change of > ± 20% from the Previous YearStateCountyFIPSCodeStateFacility IDReported 2006SO2Emissions(tons)Reported 2007SO2Emissions(tons)Facility NameReason for ChangeAZ 017 1807 1,895 1,504 Abitibi - Snowflake Pulp Mill Used low sulfur coal.AZ 019 2869 7 48 Arizona Portland Cement Emissions based on factor derived fromperformance test.AZ 007 2435 16,088 20,339 Asarco - Hayden Smelter Increase in operations without increasein capacity.AZ 015 5992 1,047 1,979 CLC - Nelson Lime Plant Increase in operations without increasein capacity.AZ 007 5992 6,383 9,111 Phelps Dodge - Miami Smelter Increase in operations without increasein capacity.AZ 001 4477 13,520 16,882SRP - Coronado GeneratingStationScrubber downtime reduced controlefficiency.NM 015 350150024 26365 Agave Energy/Agave DaggerDraw Gas PlantPlant burned only sweet gas after backfield explosion.NM 015 350150011 162 68 DCP Midstream/Artesia GasPlantAcid Gas Injection system installed in2006 has significantly loweredemissions.NM 025350250035 1,558 253 DCP Midstream/Linam RanchGas Plant [Old name: GPMGAS/LINAM RANCH GASPLANT]Plant did not have any shut downs, andimplemented revised upset procedures.NM 031 350310008 840 1,278 Giant Industries/Ciniza Refinery[Old name: GIANTREFINING/CINIZA]Production increased with higher heaterand boiler utilization rates. Installed aCEMS on flare gasline which increasedability to monitor SO2emissions.NM 025 350250007 1,125 354 J L Davis GasProcessing/Denton PlantThe reason for the change has not beenreported.(cont.)

### Draft Report

December 23, 2008

14Table 8Sources with an Emissions Change of > ± 20% from the Previous Year (cont.)StateCountyFIPSCodeStateFacility IDReported 2006SO2Emissions(tons)Reported 2007SO2Emissions(tons)Facility NameReason for ChangeNM 015 350150010 160 62 Navajo Refining Co/ArtesiaRefineryChanges in inlet gas composition, bettermaintenance, and decrease in plantupsets.NM 007 350070001 149 0 Raton Pub. Service/RatonPower PlantDid not operate in 2007.NM 025 350250008 1,435 2,895 Sid Richardson Gasoline/Jal #3 SRU malfunctions caused significantemission events.NM 025 350250063 277 335 Targa MidstreamServices/Saunders Plant [Oldnames: Dynegy MidstreamServices/Saunders Plant;WARRENPETROLEUM/SAUNDERSPLANT]SRU was shut down part of the year tochange catalyst, and all acid gas wasflared during the shut down. Gascomposition had higher S content in2007.UT 011 10119 2,201 1,174 Chevron Products Co. - SaltLake RefineryCompany added a tail gas treating unitand a vacuum gas oil hydro treating unitto their process.UT 049 10796 118 0 Geneva Steel - SteelManufacturing FacilityCompany has gone out of business, andthe plant equipment dismantled.UT 011 10123 478 579 Holly Refining and MarketingCo. - Phillips RefinerySource test changed due to a change inthe heating value of the fuel, andbreakdown emissions also increased.UT 035 10346 737 976 Kennecott Utah Copper Corp. -Smelter & RefineryIncrease in operational hours of variousequipment, and changes in the fuelsulfur content.UT 015 10238 17,402 4,351 PacifiCorp. - Huntington PowerPlantFGD control installed and operated onBoiler 2. Boiler 2 also increasedoperation - 1939 more hours than in2006.(cont.)

### Draft Report

December 23, 2008

15Table 8Sources with an Emissions Change of > ± 20% from the Previous Year (cont.)StateCountyFIPSCodeStateFacility IDReported 2006SO2Emissions(tons)Reported 2007SO2Emissions(tons)Facility NameReason for ChangeUT 007 10096 858 447 Sunnyside CogenerationAssociates - SunnysideCogeneration FacilitySource test showed decreased emissionrate due to increase in scrubberlimestone and decrease in fuel burned.WY 041 0012 2,257 1,205 BP America - Whitney CanyonGas PlantEmissions decreased due to reducedinlet gas rates, and permanent shutdownof the main plant on September 4, 2007.WY 013 0028 1,715 2,461 Burlington Resources - LostCabin Gas PlantIncreased emissions primarily caused byproblems with the Train 3 SRU reactionfurnace and the SRU combustions airblowers.WY 041 219 1 Chevron - Whitney CanyonCarter Creek Well FieldEmissions decreased due to decreasedfield flaring.WY 041 0009 205 46 Chevron USA - Carter CreekGas PlantThere was no plant turnaround in 2007,a decrease in maintenance issues, anddecrease in flaring.WY 013 57 6 Devon Energy - Beaver CreekFieldEmissions decreased due to decreasedfield flaring.WY 023 0013 2,205 846 Exxon - Shute Creek TreatingFacilityEmissions decreased due to shut downof the tail gas incinerators.WY 037 0010 161 249 FMC Wyoming Corp. - GrangerSoda Ash PlantIncrease in emissions due to increasedsoda ash production.WY 029 0007 447 348 Marathon Oil Co. - OregonBasin Gas PlantIncreased length of annual plantturnaround resulted in more untreatedacid gas incineration and increase inemissions. Increase offset by decreasedue to boiler downtime.WY 029 265 164 Marathon Oil Co. - OregonBasin FieldDecreased plant downtime resulted indecreased flaring and emissions.WY 015 0001 143 202 The Western Sugar Cooperative- Torrington PlantIncrease in emissions due to increasedsulfur content of coal.

### Draft Report

December 18, 2008

16 7.2 Part 75 Data

Federal Acid Rain Program emissions m onitoring data (required by 40 CFR Part 75)

were used to check reported power plant emi ssions, and whether or not a monitoring method

adjustment was required for changes in Part 75 quality assurance proced ures as described in

section 3.1 of this report.

Sources in the region subject to Part 75 emitted about 67% of the region's reported

emissions in 2007. We compared Acid Rain Pr ogram power plant emission data from EPA's

Data and Maps website to plant totals reported by each state. The SIPs require the use of Part 75

methods for Part 75 sources, so the reported emissions should match.

We also queried EPA's database for the Acid Rain Program to obtain the flow reference

method used in the RATAs reported by the plants since th e 1999 baseline year. This information

was used to check if there had been a change in flow reference methods since the 1999 baseline

year.

8.0 Preliminary Milestone Determination

The 2007 milestone based on the revised SIPs is 420,637 tons. No adjustment is required

for changes in smelter operation.

The 2007 milestone was also determined based on the 2003 SIPs. First, the 682,000 ton

regional milestone is adjusted for states and trib es that have not opted to participate in the 309

program by subtracting the amount for each state or tribe. The milestone is also adjusted to

account for changes in smelter operations. No ad justment is required for enforcement actions.

This results in an adjusted milestone of 422,194 tons. Table 9 shows each element of the 2007

milestone calculation under the 2003 SIPs.

The average of 2005, 2006 and 2007 adjusted emissions were determined to be 280,279

tons. Therefore, the participating states have met the milestones in the revised SIPs and 2003

SIPs (420,637 and 422,194 tons respectively).

### Draft Report

December 18, 2008

17 Table 9

Regional 2007 SO 2 

### Emissions Milestone for the Four States - Based on 2003 SIPs

Base Regional 2007 Milestone* ..................................................................................................... 682,00 0 tons



### Milestone Adjustments*

States and Tribes not participating in the backstop program:

California.................................................................................................................... ................ -37,784 tons

Colorado ...................................................................................................................... ............... -98,897 tons

Idaho......................................................................................................................... .................. -18,016 tons

Nevada........................................................................................................................ ................ -20,187 tons

Oregon ........................................................................................................................ ................ -26,268 tons

Shoshone-Bannock Tribe of the Fo rt Hall Reservatio n................................................................ -4,994 tons

Navajo Nation.................................................................................................................. ........... -53,147 tons

Ute Indian Tribe of the Uintah and Ouray Reserva tion................................................................ -1, 129 ton s

Wind River Reserva tion ........................................................................................................ ....... -1,384 tons

Smelter Set-Aside* ........................................................................................................... ............ 2,000 tons

Enforcement................................................................................................................... ............................. 0 tons



### Adjusted Four-State 2007 Milestone

(Arizona, New Mexico , Utah, Wyoming) ........................................................................................... .. 422,194 tons

* See the Regional Milestones s ection of each state's 2003 Section 309 SIP.

### A-1 December 18, 2008Appendix ATable A-12007 Reported and Adjusted Emissions for SourcesSubject to Section 309 - Regional Haze RuleStateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsAZ 017 1807 Abitibi -Snowflake PulpMill2621 322121 1,504 1,504 Low sulfur coal used.AZ 003 3532 160 AEPCO - ApacheGeneratingStation4911 221112 2,662 2,675 13 Low sulfur coal used.AZ 019 2869 Arizona PortlandCement3241 32731 48 48 Unexplained baseline yearemissions based on test factor.AZ 007 2435 Asarco - HaydenSmelter3331 331411 20,339 20,339 Reduced operations.AZ 021 15582 BHP - SanManuel Smelter3331 331411 0 0 Facility has been shut down.AZ 003 2148 CLC - DouglasLime Plant3274 32741 963 963 Facility operating at capacity.AZ 015 5992 CLC - NelsonLime Plant3274 32741 1,979 1,979 Facility operating at capacity.AZ 007 5129 Phelps Dodge -Miami Smelter3331 331411 9,111 9,111 Increased production due to shutdown of BHP smelter.AZ 025 2393 Phoenix Cement 3241 32731 7 7 Old kiln shut down. New kilnin operation.AZ 017 447 113 Pinnacle West -Cholla GeneratingStation4911 221112 23,522 23,650 128(cont.)

### A-2 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsAZ 001 4477 6177 SRP - CoronadoGenerating Station4911 221112 16,882 16,882AZ 019 126 TEP - IrvingtonGenerating Station4911 221112 2,908 2,908AZ 001 3222 8223 TEP - SpringervilleGenerating Station4911 221112 5,997 5,997 New permit limits.NM 015 350150024 AgaveEnergy/AgaveDagger Draw GasPlant1311 211111 65 65 Agave Gas Plant and Duke DaggerDraw merged to form Agave DaggerDraw.NM 015 350150002 BP AmericaProduction/EmpireAbo Plant [Oldname: ArcoPermian/EmpireAbo Plant]1321 211112 300 300NM 015 350150011 DCPMidstream/ArtesiaGas Plant1321 211112 68 68 New Owner - DCP Midstream.NM 025 350250044 DCPMidstream/EuniceGas Plant [Oldname: GPM GASEUNICE GASPLANT]1321 211112 1,063 1,063 New Owner - DCP Midstream.NM 025 350250035 DCPMidstream/LinamRanch Gas Plant[Old name: GPMGAS/LINAMRANCH GASPLANT]1321 211112 253 253 New Owner - DCP Midstream.(cont.)

### A-3 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsNM 025 350150138 Duke -Magnum/PanEnergy - BurtonFlats1321 211112 0 0 No longer a major source.NM 015 350150285 DukeEnergy/DaggerDraw Gas Plant1321 211112 0 0 Agave Gas Plant and Duke DaggerDraw merged to form Agave DaggerDraw.NM 025 350250060 Dynegy MidstreamServices/EuniceGas Plant [Oldname: WARRENPETROLEUM/EUNICE GASPLANT]1321 211112 2,355 2,355NM 025 350250004 Frontier FieldServices/MaljamarGas Plant1321 211112 2,520 2,520NM 001 00008 GCC Rio GrandeCement3241 327310 16 1,103 1,087 Facility potential to emit was usedfor the baseline year calculation.Adjustment is equal to thedifference between potential andreported emissions.NM 031 350310008 GiantIndustries/CinizaRefinery (Gallup)[Old name: GIANTREFINING/CINIZA]2911 32411 1,278 1,278NM 025 350250007 J L Davis GasProcessing/DentonPlant1311 211111 354 354NM 015 350150008 MarathonOil/Indian BasinGas Plant1321 211112 680 680(cont.)

### A-4 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsNM 015 350150010 Navajo RefiningCo/Artesia Refinery2911 32411 62 62NM 023 350230003 Phelps DodgeHidalgo Smelter3331 331411 0 0NM 017 350170001 Phelps DodgeHurley Smelter/Concentrator3331 331411 0 0NM 045 350450902 2451 Public Service Co.of New Mexico/San JuanGenerating Station4911 221112 15,305 17,683 2,378NM 007 350070001 Raton Pub.Service/RatonPower Plant4911 221112 0 0 Did not operate in 2007.NM 025 350250008 Sid RichardsonGasoline/Jal #31321 211112 2,895 2,895NM 001 00145 Southside WaterReclamation Plant4952 22132 57 120 63 Facility potential to emit was usedfor the baseline year calculation.Adjustment is equal to thedifference between potential andreported emissions.NM 025 350250051 Targa MidstreamServices/EuniceSouth Gas Plant1321 211112 0 0 Eunice South Gas Plant is nowowned by Versado Gas Processors,LLC and operated by TargaMidstream Services, LP. No longera major source.NM 025 350250061 Targa MidstreamServices/MonumentPlant [Old name:WARRENPETROLEUM/MONUMENT PLANT]1321 211112 1,235 1,235 New Owner - Versado GasProcessors, LLC and operated byTarga Midstream Services, LP.(cont.)

### A-5 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsNM 025 350250063 Targa MidstreamServices/SaundersPlant [Old name:WARRENPETROLEUM/SAUNDERS PLANT]1321 211112 335 335 New Owner - Versado GasProcessors, LLC and operated byTarga Midstream Services, LP.NM 031 350310032 87 Tri-State Gen &Transmission/Escalante Station4911 221112 1,124 1,591 467NM 045 350450247 Western GasResources/San JuanRiver Gas Plant1321 211112 393 393NM 045 350450023 Western RefiningSouthwest Inc./SanJuan Refinery(Bloomfield) [oldname: GIANTINDUSTRIES/BLOOMFIELD REF]2911 32411 428 428UT 049 10790 Brigham YoungUniversity - MainCampus8221 611310 97 97UT 027 10311 Brush ResourcesInc. - Delta Mill1099 212299 0 0UT 011 10119 Chevron ProductsCo. - Salt LakeRefinery2911 324110 1,104 1,085 -19 AP42emission factor change.Change from AP42 emission factorto engineering data in calculatingflares.UT 037 10034 EnCana Oil & Gas(USA) Incorporated(was Tom BrownIncorporated) -Lisbon Natural GasProcessing Plant2911 211111 97 97(cont.)

### A-6 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsUT 011 10122 Flying J Refinery -(Big West OilCompany)2911 324110 390 390UT 027 10313 Graymont WesternUS Inc. - CricketMountain Plant1422 212312 31 415 384 AP42 emission factors changed.Method of calculating kilnemissions changed from permit limitto stack test.UT 029 10007 Holcim - Devil'sSlide Plant3241 327310 454 454UT 011 10123 Holly Refining andMarketing Co. -Phillips Refinery2911 324110 579 582 3 The company changed theestimation methods from massbalance and AP42 in 1998 to CEM.UT 027 10327 6481 IntermountainPower ServiceCorporation -IntermountainGeneration Station4911 221112 4,764 4,788 24 Wall Adjustment Factor (WAF) of0.995 used on Flow RATA.UT 035 10572 Kennecott UtahCopper Corp. -PowerPlant/Lab/TailingsImpoundment1021 212234 3,207 3,207UT 035 10346 Kennecott UtahCopper Corp. -Smelter & Refinery3331 331411 976 976UT 007 10081 3644 PacifiCorp. -Carbon Power Plant4911 221112 6,511 7,537 1,026 The RATA method changed frommethod 2 in 1999 to method 2FH.The Flow Adjustment Factorcalculated is 1.17 for unit 1 and 1.15for unit 2.(cont.)

### A-7 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsUT 015 10237 6165 PacifiCorp. - HunterPower Plant4911 221112 6,672 7,658 986 Two RATA methods were used in1999, 2 and 2FH. The RATAmethod changed to method 2FH forthe entire year. The FlowAdjustment Factor calculated is 1.09for unit 1, 1.21 for unit 2, and 1.15for unit 3.UT 015 10238 8069 PacifiCorp. -Huntington PowerPlant4911 221112 4,351 4,931 580 Two RATA methods were used in1999, 2 and 2FH. The RATAmethod changed to method 2FH forthe entire year. The FlowAdjustment Factor calculated is 1.11for unit 1 and 1.18 for unit 2.UT 007 10096 SunnysideCogenerationAssociatesSunnysideCogenerationFacility4911 221112 447 448 1 AP42 emission factor changed from157S to 142S (< 0.5 change).UT 035 10335 Tesoro West CoastSalt Lake CityRefinery2911 324110 909 878 -31 The actual emissions included SO3in 2007. SO3was not included inthe 1998 emissions.UT 043 10676 Utelite Corporation- Shale Processing3295 144 144 Added to the inventory in 2003.WY 011 0002 American ColloidMineral Co. - EastColony1459 212325 65 65 Dryer SO2Emissions werecalculated using a Sulfur Content of0.34% & a Control Efficiency of65%.WY 011 0003 American ColloidMineral Co. - WestColony1459 212325 46 46 Dryer SO2Emissions werecalculated using a Sulfur Content of0.34% & a Control Efficiency of65%.WY 037 0008 Anadarko E&P Co.LP - Brady GasPlant1321 211112 90 90 Calculation Methods (CEMMonitoring, & Mass Balance).(cont.)

### A-8 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsWY 037 Anadarko E&P Co.L.P. - Table RockGas Plant1321 153 153 Calculation Methods (CEMMonitoring, & Mass Balance).WY 031 0001 6204 Basin Electric -Laramie RiverStation4911 221112 10,387 10,387 Calculation Method (CEMS Part75).WY 003 0012 Big Horn Gas Proc.- Big Horn/ByronGas Plant1311 22121 0 0 Switched to sweet gas in Feb. 2001,and continues to process only sweetgas.WY 005 0002 4150 Black HillsCorporation - NeilSimpson I4911 22112 984 984 Calculation Method (Chemical MassBalance).WY 005 0063 7504 Black HillsCorporation - NeilSimpson II4911 22112 613 613 Calculation Method (CEMS Part75).WY 045 0005 4151 Black HillsCorporation - OsagePlant4911 22112 2,994 2,994 Calculation Method (1998 BaseYear & 1988 stack test).WY 005 0146 55479 Black HillsCorporation -Wygen 14911 22112 688 688 Calculation method: (CEMS Part75).WY 041 0012 BP AmericaProductionCompany - WhitneyCanyon Gas Plant1311 211111 1,205 1,205 Calculation methods: CEM Data,Metered Flow, & Emissions Testing.WY 041 BP AmericaProductionCompany - WhitneyCanyon WellField1311 3 3 Minimal flaring at well sites in2007.(cont.)

### A-9 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsWY 013 BurlingtonResources -Bighorn Wells1311 0 0 No flaring at well site in 2007.WY 013 0028 BurlingtonResources - LostCabin Gas Plant1311 211111 2,461 2,459 -2 Emission volumes based upon datasubmitted in quarterly reports, andare same as base year, except for theTrain 3 sulfur pit. New method =hours pit vent valve is open x pitemission rate.WY 041 0009 Chevron USA -Carter Creek GasPlant1311 211111 46 46 Turnaround in August 2005 & achange in the operating plan.WY 037 Chevron USA -Table Rock Field1311 328 328 Flaring at wellsites in 2007.WY 041 Chevron USA -WhitneyCanyon/CarterCreek Wellfield1311 1 1 SO2calculation in Chapter 6 Section2 page B14.WY 013 Devon EnergyProduction Co.,L.P. - Beaver CreekGas Field6 6 Tons H2S (flared) * 1.8797 = SO2emitted.WY 013 0008 Devon GasServices, L.P. -Beaver Creek GasPlant1311 211111 84 84 Tons H2S (flared) * 1.8797 = SO2emitted.WY 023 Exxon MobilCorporation -Labarge BlackCanyon Facility1311 133 133 Calculation Method (AP-42 andactual volumes).WY 023 0013 Exxon MobilCorporation - ShuteCreek1311 211111 846 846 Turbines in operation since 2004;therefore, not a change inmethodology. (CEMs & AP-42).(cont.)

### A-10 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsWY 037 0048 FMC Corp. - GreenRiver SodiumProducts (Westvacofacility)2812 327999 4,234 4,234 SO2emissions from "2" emissionpoints: (NS-1A & NS -1B). CEMlb/mmbtu * Annual heat input.WY 037 0049 FMC WyomingCorporation -Granger Soda AshPlant1474 212391 249 249 Boilers #1 & #2 operated acombined 16,012 hours in 2007.WY 021 0001 Frontier Oil &Refining Company- CheyenneRefinery2911 32411 1,033 1,033 Source 43 Coker Flare had a wet gascompressor installed in January2006 which routes coker off-gasback into the refinery fuel gassystem.WY 037 0002 General Chemical -Green River Plant(Facility Name:General Chemical)1474 327999 5,701 5,701 SO2emissions from "2" emissionpoints: (C Boiler & D Boiler). Fueluse, fuel heat value, CEM.WY 043 0003 Hiland Partners,L.L.C. - Hiland GasPlant1321 48621 145 145 SO2emissions from acid gas;process & safety flares. Gas flowmeasurement, H2S conc. &engineering calculations.WY 029 0012 Howell PetroleumCorp. - Elk BasinGas Plant1311 211111 1,309 1,309 SO2emissions from "2" emissionpoints: (SRU & F-1). CEM andMass Balance.WY 029 0007 Marathon Oil Co. -Oregon Basin GasPlant1321 211112 348 348 Using the old methodology, thecalculations result in negativeemissions. Oregon Basin went to amass CEM in 2002, but used a massbalance calculation in the base year.However, they no longer keepadequate records of inlet gasconcentration to utilize the massbalance method.(cont.)

### A-11 Draft Appendix A

December 23, 2008Table A-12007 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsWY 029 Marathon Oil Co. -Oregon BasinWellfield164 164 Flaring at wellsites in 2007.WY 001 0002 Mountain CementCompany - LaramiePlant3241 23571 94 94 SO2Emissions from "2" emissionpoints: (Kiln #1 & Kiln #2). CEM.WY 037 0003 P4 Production,L.L.C. - RockSprings CoalCalcining Plant3312 331111 653 653 New stack test results used foremission calculation. Does notrepresent a change in methodology.WY 009 0001 4158 Pacificorp. - DaveJohnston Plant4911 221112 21,356 25,791 4,435 SO2emissions from "4" emissionpoints: (BW41, BW42, BW43 &BW44 & Flow Adjustment Factors:1.11, 1.23, 1.19 & 1.28). SO2emissions using EPA acceptedvalues from the Acid Rain EDRs.WY 037 1002 8066 PacifiCorp. - JimBridger Plant4911 221112 19,053 20,486 1,433 SO2emissions from "4" emissionpoints: (BW71, BW72, BW73 &BW74 & Flow Adjustment Factors:1.04, 1.13, 1.03 & 1.13). SO2Emissions using EPA acceptedvalues from the Acid Rain EDRs.WY 023 0004 4162 PacifiCorp. -Naughton Plant4911 221112 21,588 24,873 3,285 SO2emissions from "3" emissionpoints: (1, 2, & 3 & FlowAdjustment Factors:1.05, 1.14, &1.29). SO2Emissions using EPAaccepted values from the Acid RainTitle IV EDRs.WY 005 0046 6101 PacifiCorp. -Wyodak Plant4911 221112 7,835 8,305 470 SO2emissions from "1" emissionpoint: (BW91 & a Flow AdjustmentFactor of 1.06). SO2Emissionsusing EPA accepted values from theAcid Rain Title IV EDRs.(cont.)

### A-12 Draft Appendix A

December 23, 2008Table A-12006 Reported and Adjusted Emissions for Sources Subject to Section 309 - Regional Haze Rule (cont.)StateCountyFIPSStateFacilityIdentifierORISPlant NamePlantSICPlantNAICSReported2007 SO2Emissions(tons)Adjusted2007 SO2Emissions(tons)Part 75FlowRATAEmissionAdjustment(tons)GeneralNewMonitoringCalculationMethodAdjustment(tons)Description/CommentsWY 037 0022 Simplot PhosphatesL.L.C. - RockSprings Plant2874 325312 2,052 2,052 (Source Test x Op Hours, AP-42estimates, & AP-42 x Op Hours).WY 007 0001 Sinclair OilCompany - SinclairRefinery2911 32411 1,035 705 -330 FCC Unit used stack test x hours in1998; went to a CEM in 2004.WY 025 0005 Sinclair WyomingRefining Company- Casper Refinery2911 32411 792 792 SO2emissions from "23" emissionpoints. Calculation Method is thesame as the Base Year.WY 037 0010 Solvay Chemicals -Soda Ash Plant(Green RiverFacility)1474 56 104 48 SO2Emissions from "5" emissionpoints: (AQD #18, #19, #33, #73 Y). Calculation method:(lb/MMBtu x MMBtu & pph stacktest x hr/yr). The base year forAQD #18 & #19 were calculatedwith pph stack test x hr/yr.WY 015 0001 The Western SugarCooperative -Torrington Plant2063 311313 202 202 Coal-fired Sterling Boilers #3, #4,#5, & #6 (increase in operatinghours).WY 001 0005 University ofWyoming - HeatPlant8221 61131 71 71 SO2emissions from "5" emissionpoints: (#1 thru #4 Boilers & adiesel generator).WY 045 0001 Wyoming Refining- NewcastleRefinery2911 32411 690 690 Base year emissions estimate wasbased upon Tutweiler sampleanalysis. Base year estimatecalculations are no longer available.

### December 23, 2008

Appendix B

Table B-1

Sources Added to the SO 2 

### Emissions and Milestone Report Inventory

State County FIP

Code State

Facility ID Facility Name Report

Year of

Change

UT 043 10676 Utelite Corporation - Shale processing 2003

WY 011 0002 American Colloid Mineral Company - East Colony 2003

WY 011 0003 American Colloid Mineral Company - West Colony 2003

WY 037 Anadarko E&P Company LP - Table Rock Gas

Plant 2003

WY 005 0146 Black Hills Corporation - Wygen 1 2003

WY 041 BP America Production Company - Whitney

Canyon Well Field 2003

WY 013 Burlington Resources - Bighorn Wells 2003

WY 037 Chevron USA - Table Rock Field 2003

WY 041 Chevron USA - Whitney Canyon/Carter Creek

Wellfield 2003

WY 013 0008 Devon Energy Corp. - Beaver Creek Gas Plant 2003

WY 035 Exxon Mobil Corporation - Labarge Black Canyon

Facility (also identified as Black Canyon Dehy

Facility) 2003

AZ 019 2869 Arizona Portland Cement 2004

WY 013 Devon Energy Corp. - Beaver Creek Gas Field 2004

### Draft Appendix B

December 23, 2008

B-2 Table B-2

Sources Removed from the SO 2 

### Emissions and Milest one Report Inventory

State County

FIP

Code State

Facility

ID Facility Name Baseline

Emissions

(tons/year) Reason for Change Report

Year of

Change

WY 043 0001 Western Sugar

Company - Worland 154 Emissions did not meet

100 TPY program criteria. 2003

WY 017 0006 KCS Mountain

Resources - Golden

Eagle 942 Emissions did not meet

100 TPY program criteria. 2003

WY 003 0017 KCS Mountain

Resources - Ainsworth 845 Closed since 2000. 2003

WY 017 0002 Marathon Oil - Mill

Iron 260 Emissions did not meet

100 TPY program criteria. 2003

AZ 021 15582 BHP - San Manuel

Smelter 10,409 Facility is permanently

closed. 2004

UT 049 10796 Geneva Steel - Steel

Manufacturing Facility 881 Plant is shut down and

disassembled. 2004

WY 023 0001 Astaris Production -

Coking Plant 1,454 Plant is permanently shut

down and dismantled. 2004