# Technical Memorandum

To: WRAP Forums and Workgroups

From: Paula Fields ( paula.fields@erg.com ) and Marty Wolf ( marty.wolf@erg.com )

Subject: WRAP 2018 Preliminary Reasonable Progress Emissions Inventory – Final,

Revised 1



# Copy: WRAP Staff

Date: June 18, 2007

INTRODUCTION

The objective of this project is to provide the technical basis for making preliminary evaluations

of reasonable progress toward individual Class I area visibility goals by the Western Regional

Air Partnership (WRAP). This was done by updating the WRAP region 2018 point and area

sources emission inventory projections from the 2018 Base Case version 1 project, completed by

Eastern Research Group, Inc. (ERG) in January 2006. 2 

# The resulting emissions inventory is the

WRAP region Preliminary Reasonable Progr ess emissions inventory for 2018 (PRP18).

The focus of this project was the most significan t point and area sources of visibility-impairing

pollution within each state, and on the specifi c source categories whos e 2018 emissions were

known to be incorrect or needed to be revise d. The scope of this project was purposely limited

and focused on the most significant sources of 2018 em issions in order to complete the work in a

timely and efficient manner for both the State an d Local (S/L) agencies reviewing the data and

providing comments, as well as for the Contra ctor performing the analysis and making the

updates.

The remaining contents of this memo describe the project scope, explain the methodology used

to compile data and prepare the WRAP 2018 PR P emissions inventory, and present summary

results for the WRAP region and de tailed results for each jurisdiction. 3 

# The summary results are

contained in Attachment 1 (for point sources, by state) and At tachment 2 (for area sources, by

state) to this memo.

1 

# The final memo was revised to correct errors in the area source emissions summaries for oil and gas.

2 

# http://wrapair.org/forums/ssjf/documents/eictts/ docs/WRAP_2018_EI-Version_1-Report_Jan2006.pdf

3 

# The Regional Haze Rule explicity reco gnized the authority of tribes to impl ement the provisions of the Rule, in

accordance with principles of Federal Indian law, and as provided by the Clean Air Act §301(d) and the Tribal

Authority Rule (TAR) (40 CFR §§49.1-.11). It is our hope that the finding and recommendations in this report

will prove useful to tribes, whether they choose to subm it full or partial 308 or 309 Tribal Implementation Plans

(TIPs), or work with the U.S. EPA to develop Federal Implementation Plans (FIPs). The authors of this memo

have striven to ensure that all references to tribes in the document are consistent with principles of tribal

sovereignty and autonomy as reflected in the regulatory framework. Any inconsistency with this framework is

strictly inadvertent and not an attempt to impose requirem ents on tribes which are not present under existing law.

# Technical Memorandum – Final, Revised June 18, 2007

Page 2



# SCOPE

The scope of this project is on stationary point and area sources located with the WRAP states of

Alaska, Arizona, California, Colorado, Idaho, Montana, Nevada, New Mexico, North Dakota,

Oregon, South Dakota, Utah, Washi ngton, and Wyoming; as well as tribal sources within those

states. Certain area sources are excluded because they are being dealt with by other contractor

teams: (i.e., fugitive dust, fires, area ammonia s ources, etc.). Updates to the oil and gas (O&G)

area source emissions, and O&G point source SO 2 

# emissions were developed by ENVIRON

under another project, and provided to ERG for inclusion with the other point and area sources in

the WRAP PRP18 emissions inventory. 4 

# The California emissions were not modified in any

way, and were simply retained as-is from the previous WRAP 2018 base case version 1

inventory.

In some limited cases, changes were also ma de to the 2002 baseline inventory when these

changes were straightforward and did not affect emission values (e.g., correction of missing or

erroneous source classification c odes [SCCs], changing facility na mes to be consistent across

records, etc.). In only a few instances (described below in this memo) were records added to the

2002 inventory, and subsequently, were projec ted to 2018 and added to the WRAP PRP18

inventory. Additional 2002 changes were identified, but were deferred until the next update of

these 2002 and 2018 WRAP inventories.

The deliverables produced under this project includ e, in addition to a draft and final technical

memorandum, WRAP PRP18 and revised 2002 inventor y pivot tables (similar to those provided

under ERG’s previous project). ERG also provid ed PRP18 files formatted for modeling (i.e.,

SMOKE/IDA format) and for use in the WRAP EDMS (i.e., NIF3.0).

METHODOLOGY

The methodology used to develop the WRAP PR P18 emissions inventory for point and area

sources is described below.

Developed 2018b Base Case Summary Tables and List of Potential Changes

ERG updated the existing WRAP 2018 version 1 data base to be consistent with the 2018b “base

case” emissions inventory used by the WRAP Regional Modeling Center (RMC) for the 2108

base case modeling analysis completed in June 2006. These changes are itemized in the RMC

2006 final report, Appendix A. 5 

# After discussion with the RMC, and comparison to the 2018b

base case emissions inventory, a few other cha nges were necessary to make the 2018 version 1

inventory consistent with the 2018b base case inventory, including the following: 6



# ● Added NO

x 

# and CO emissions for four new ( post-2002) compressor stations in ND;

● Added SO 2 

# emissions for 4 facilities in WY; and

● Added NO

x 

# , VOC, and CO emissions for 7 compressor stations in WY.

4 

# http://www.wrapair.org/forums/ssjf/documents/eictts/oilgas.html

5 

# http://pah.cert.ucr.edu/aqm/308/docs.shtml

6 

# Telephone conversation with Zac Adelman, RMC, February 6, 2007.

# Technical Memorandum – Final, Revised June 18, 2007

Page 3



# Using the updated 2018b base case emissions databa se, spreadsheets were developed to show the

top 80% of emissions of point source and area source emissions, by SCC, for each state. Also, a

spreadsheet entitled “Proposed Changes & Feedb ack Request” itemized other potential changes

that might need to be made to each jurisd iction’s 2018b base case inventory to update it for

PRP18 purposes. The types of changes proposed and feedback requested from each state and

local (S/L) agency included the following:

● Confirmation of changes in SO 2 

# emissions from major sources located in §309 st ates (i.e.,

AZ, NM, UT, and WY); 7



# ● Request for BART emission limits;

● Request for information on any new post-2004 “on-the-books” controls or permit limits;

● Request to provide missing SCCs (and itemized list of records with missing SCCs was

provided); and

● Confirmation that all dual-fue led sources were accounted fo r in the emissions inventory.

These spreadsheets were e-mailed to each S/L ag ency for review prior to holding conference

calls to explain the spreadsheets and rece ive initial comments from the agencies.

Collected Comments from S/L Agencies

Conference calls were held with each S/L ag ency from March 9 through March 19, 2007. (Note

that no call was held with CA since there are no changes to be made to their existing 2018b base

case emissions for PRP18 purposes.) All comm ents received during these calls were

summarized. After the calls, and until April 18, ER G received additional written comments from

all S/L agencies. These comments, along with ERG’s responses, form the basis for the changes

made to each state inventory as part of the PR P18 process. Summaries of the call notes, and the

comments/responses table are located on the WRAP SSJF website. 8



# Developed the WRAP 2018 PRP Emissions Inventory

The types of revisions made in order to tr ansition the WRAP 2018b base case emissions

inventory into the WRAP PRP18 emissi ons inventory are described below.

Addressed S/L Agency Comments

After ERG assimilated the comments received dur ing the conference calls, via e-mails, and from

numerous follow-up data requests to the agenci es, changes were made to the 2018b base case

database. In some cases, the changes did not a ffect emissions (e.g., fixed missing SCCs, changed

facility name, etc.). In othe r cases, significant changes were made (e.g., added new sources or

removed inactive sources).

7 

# “2018 SO 2 

# Emissions Evaluation for Non-Utility Sources”, Pechan, October 2006.

http://www.wrapair.org/f orums/ssjf/docs.html

8 

# http://www.wrapair.org/forums/ssjf/documents/eictts/projections.html

# Technical Memorandum – Final, Revised June 18, 2007

Page 4



# Corrected CAMD EGU Facility IDs and Added Missing Records

The basis of the WRAP 2002 emissions inve ntory, and thus the WRAP 2018 version 1

projections, were the data submitted by S/L agen cies and tribes for the U.S. EPA National

Emissions Inventory (NEI). During the develo pment of the NEI, ERG (as an U.S. EPA

contractor) was requested to use NO

x 

# and SO 2 

# emissions data for subject EGUs from the U.S.

EPA Clean Air Markets Division (CAMD) databa se, instead of the emissions submitted by the

S/L agencies for those EGUs reporting to CAMD. When these NO

x 

# and SO 2 

# emissions data were

placed into the NEI, they were assigned a unique facility ID beginning with “EGU” in order to

distinguish that record from the record submitted by the state. Generally, the NO

x 

# and SO 2 

# emissions values from CAMD varied only slightly from those submitted by the S/L agency (i.e.,

ERG observed results showing about a 1-2% di fference in emissions between CAMD and S/L

agency emissions). However, the use of the CAMD “EGU” numbering scheme caused there to

be two different facility IDs for the same EGU in the resulting dataset. This eventually became

recognized as a problem when these data were used in the WRAP 2002 and 2018 pivot tables

and in the WRAP Emissions Data Management System (EDMS). 9



# Also, another problem had occurred during the data replacement activities, that resulted in some

NO

x 

# and SO 2 

# emission records for non-CAMD units opera ting at facilities with CAMD units

being deleted, causing non-CAMD EGU emissions to be underreported in th e resulting dataset.

For these reasons, ERG performed a task to (1) replace the CAMD “EGU” facility IDs with the

S/L agency facility IDs as or iginally submitted to the NEI, and (2) to replace the dropped NO

x 

# and SO 2 

# emission records in the 2002 inventory database and project these to 2018. These

corrections are now reflected in the draft WRAP 2018 PRP emissions inventory.

Revised EGU Projections

In addition to the EGU corrections just described, ERG, with the assistance from WRAP staff,

updated the analysis of future coal-fired EGUs (i.e ., units that will need to be built in order to

meet future projected electricity demand) . ERG obtained the most recent annual energy

projections from the Energy Information Administration (EIA). 10 

# The previous analysis relied

on EIA projections released in 2005 with estimate s out to 2025; the most current projections

were released in February 2007 and provide estima tes out to 2030. As with the original analysis,

generation projections for 2018 were used for the revised analysis. A comp arison of the original

and revised generation projecti ons are shown in Table 1.

The revised analysis of future electricity gene ration for coal is summarized in Table 2, which

shows that the required 2018 generation in the revised analysis increased by 7.3% (i.e., 27.40

billion kWh) relative to the original analysis . This growth is offset by increased generation

capacity (i.e., 52.51 billion kWh) that is currently being permitted. A list of facilities that are

currently under construction or currently being permitted is provided in Table 3.

9 

# “SO

x 

# and NO

x 

# Emissions Data from Electricity Generating Units (EGUs): Issues related to the substitution of

state/local/tribal (S/L/T) data in the 2002 National Em issions Inventory (NEI) and the WRAP-EDMS data base.”

Whitepaper prepared by Matt Poppen, Eric Raisanen and Bob Downing, Emissions Inventory Unit, Maricopa Co.

Air Quality Dept. (MCAQD). April 2006.

10 

# Annual Energy Outlook 2007 with Projections to 2030 . DOE/EIA-0383(2007). Energy Information

Administration, Washington, DC. February 2007.

# Technical Memorandum – Final, Revised June 18, 2007

Page 5



# Table 1. EIA Electricity Projections (billion kWh)

Electricity Market Module Region 2018 Required Coal-Fired

Generation (2005 EIA) 2018 Required Coal-Fired

Generation (2007 EIA)

California a 

# 77.76 83.17

Northwest Power Pool b 

# 88.37 106.05

Rocky Mountain Power Area c 

# 162.18 167.05

Mid-Continent Area Power Pool (ND and SD portions only) 45.61 45.05

Total 373.92 401.32

a 

# Portions of CA.

b 

# ID, OR, UT, WA, and WY; portions of CA, MT, NV, and SD.

c 

# AZ and CO; portions of NV and NM.



# Table 2. Future Electricity Ge neration Analysis (billion kWh)

Growth Parameter Original 2018 ERG Analysis

(2005 EIA) Revised 2018 ERG Analysis

(2007 EIA)

2002 Electricity Generation 258.70 258.70

2018 Electricity Generation 373.92 401.32

Needed Generation 115.22 142.62

Unused Capacity at Existing 2002 Facilities 16.60 16.60

New Capacity at 2003-2004 Facilities 0.66 0.66

Capacity Currently Under Construction 9.61 9.83

Capacity Currently Being Permitted 21.82 74.33

Remaining Capacity to be Allocated 66.53 41.20



# Table 3. Coal-Fired EGUs Under C onstruction or Being Permitted (MW)

Original 2018 ERG Analysis Revised 2018 ERG Analysis

Facility Name State Under

Construction Being

Permitted Under

Construction Being

Permitted

Rocky Mountain Power/Hardin Gen.

Station MT 160 160

Bull Mountain Plant/ Roundup Plant MT 750 780

Wygen Station #2/ Black Hills Corp WY 100 100

Two Elk (#1)/ Bechtel WY 280 280

Springerville (#3 and #4) AZ 760 800

Comanche (#3) CO 750 750

Northern Nevada Energy/ Newmont NV 200 200

NEVCO Energy Company UT 270 270

Intermountain Power Plant (#3) UT 950 950

Ft. Morgan/ LS Power CO 600

Akron/ AES Power CO 640

Highwood/ Southern Montana Electric MT 270

White Pine Energy Association/ LS Power NV 1,500

Gascoyne #1/ Montana Dakota Utility ND 175

Gascoyne #2/ Montana Dakota Utility ND 500

South Heart/ Great Northern Power ND 500

Great River Energy ND 66

Wygen (#3) WY 100

Two Elk (#2) WY 740

Dry Fork/ Basin Electric WY 422

Desert Rock/Sithe Global Power Navajo

(NM) 1,500

Total 1,290 2,180 2,070 9,983

# Technical Memorandum – Final, Revised June 18, 2007

Page 6



# Assuming that a typical future coal-fired EGU has a nameplate capacity of 500 MW and operates

at the capacity threshold of 0.85, then a total of 11 future coal-fired EGUs are required under the

revised analysis compared to the 18 EGUs estimat ed with the original analysis. The state-level

allocation of the future coal-fired EGUs in th e original analysis wa s based upon current statelevel capacity (i.e., sum of capacity at existing, under construction, and permitted facilities). This

same state-level allocation was maintained for the revised analysis with three exceptions.

First, no additional future coal-fired EGUs we re assigned to ND; the ND and SD generation

analysis was conducted separately from the othe r Western states because ND and SD are in a

different electricity market module region and lign ite coal is preferenti ally used, instead of

bituminous and sub-bituminous coal. Three future coal-fired EGUs (i.e., total of 1,500 MW)

were allocated to ND and SD in the original an alysis; the newly identified permitted facilities

located in ND (i.e., Gascoyne #1 and #2, South H eart, and Great River Energy) have a total

capacity of 1,241 MW. In addition, the ND and SD projected coal-fired electricity generation

decreased slightly in the new EIA data. Theref ore, no additional EGUs were assigned to ND.

The second exception is that the one future coal -fired EGU assigned to Idaho in the original

analysis was removed. This is based upon a morato rium on the construction of coal-fired EGUs

in Idaho. Although this moratorium is not necessari ly permanent, WRAP staff indicated that the

future coal-fired EGU assigned to Idaho s hould be removed from the revised analysis.

The third exception is the identification of the Desert Rock/Sithe Global Power EGU consisting

of two 750 MW units that is being permitted for the Navajo Nation (San Juan County, New

Mexico). Desert Rock will “rep lace” the two future coal-fired EGUs allocated to the Navajo

Nation in the original ERG analysis, as well as one other EGU located elsewhere from the

original ERG analysis. Because the highest numbe r of allocated future coal-fired EGUs were

located in Wyoming, in the previous analysis, th e number of these EGUs was reduced from three

to two in the PRP18 analysis.

The state-level allocations are presented in Table 4. WRAP st aff indicated that the county-level

allocations used in the original analysis (based upon announcements of plans to build coal-fired

EGUs and locations of existing coal-fired EGUs and associated infrastructure) should be

maintained in the PRP18 analysis.

In addition to new generation proj ections and future plant allocations, the revised EGU analysis

included a review of permitted emission rates for new EGUs. The previous analysis used

emission rates derived from a range of values from 12 Western fac ilities that were reported to

U.S. EPA; the revised analysis uses permitted emission rates collected by WRAP staff. 11 

# These

emission rates are shown in Table 5; blank cells in the table indicated no reported permit limit. It

should be noted that the EGUs shown in Tables 3 and 5 do not correspond exactly. In particular,

Hardin Generating Station and Desert Rock ar e included in Table 3, but not in Table 5.

Conversely, Otter Tail and Neil Simpson #2 are in cluded in Table 5, but not in Table 3. The

Otter Tail and Neil Simpson #2 EGUs were included in the 2002 inventory (thus not considered

as an “under construction” or “being permitted” facility in Table 3), bu t their permitted emission

rates were obtained during the development of Table 5. The Hardin Generating Station permitted

emission rates were not obtained during the de velopment of Table 5, while the Desert

11 

# Listing of permitted coal-fired emission rates provided by Lee Gribovicz, WRAP.

# Technical Memorandum – Final, Revised June 18, 2007

Page 7



# Table 4. State-Level A llocation of Future Placehol der Coal-Fired EGUs

Required to Match Total Electricity De mand Forecasts (Number of 500 MW Units)

State Original ERG 2018b Base Case

Analysis Revised ERG PRP18

Analysis

Arizona 2 2

Colorado 2 2

Idaho 1 0

Montana 1 1

Nevada 1 1

New Mexico 1 1

North Dakota 3 0

Oregon 0 0

South Dakota 0 0

Utah 2 2

Washington 0 0

Wyoming 3 2

Tribes (Navajo) 2 0

Total 18 11



# Table 5. Permitted Emissions Rates for Coal-Fired EGUs (lb/MMBtu)

Facility Name State NO

x 

# SO 2 

# VOC CO PM 10 

# Springerville #3 AZ 0.090 0.090 0.055 a



# Springerville #4 AZ 0.054 0.077 0.055 a



# AES Power/Akron CO 0.070 0.100 0.012

Comanche #3 CO 0.080 0.100 0.0035 0.130 0.013

LS Power/Ft. Morgan CO 0.070 0.078 0.012

Roundup Power/Bull Mountain #1 MT 0.070 0.100 0.0030 0.15 0.012

Roundup Power/Bull Mountain #2 MT 0.070 0.100 0.0030 0.15 0.012

Southern Mont ana Electric/

Highwood MT

0.070 0.038 0.0030 0.10 0.012

Nevada Energy/Newmont NV 0.067 0.090 0.150 0.012

LS Power/ White Pine Energy NV 0.070 0.078 0.012

Great River Energy ND 0.090 0.060 0.013

Montana Dakota Utility/Gascoyne #1 ND 0.090 0.038 0.0050 0.150 0.013

Montana Dakota Utility/Gascoyne #2 ND 0.090 0.060 0.012

Great Northern Power/South Heart ND 0.090 0.039 0.0025 0.150 0.010

Otter Tail Power Company SD 0.0036 0.150 0.030

Intermountain Power #3 UT 0.070 0.090 0.0027 0.15 0.012

Nevco/Sevier Power UT 0.100 0.022 0.115 0.0154

Basin Electric/ Dry Fork WY 0.050 0.080 0.0039 0.15 0.012

Black Hills Power/ Neil Simpson #2 WY 0.023 0.200 a 

# 0.0150 0.15 0.02

Two Elk #1 WY 0.090 0.132 0.0135 0.135 0.018

Two Elk #2 WY 0.070 0.084 0.0035 0.15 0.015

Black Hills Power/ Wygen #2 WY 0.070 0.100 0.0100 0.15 0.012

Black Hills Power/ Wygen #3 WY 0.050 0.090 0.15 0.012

Average New Unit Rates 0.072 0.078 0.0056 0.143 0.014

Previous Analysis New Unit Rates 0.090 0.090 0.0022 0.150 0.018

Current Analysis New Unit Rates 0.072 0.078 0.0022 0. 143 0.014

# Technical Memorandum – Final, Revised June 18, 2007

Page 8



# Rock permitted emission rates were obtained after the completion of Table 5 and represent a

special case of an EGU to be built on tribal lands.

The permitted emission rates were used at their respective permitted EGU. Average emission

rates were calculated from these collected emission rates. Three permitted emission rates (i.e.,

PM 10 

# at Springerville #3 and #4 and SO 2 

# at Neil Simpson #2) were excluded from the calculation

of the average emission rates because they were significant outliers. In addition, the VOC rate

(0.0022 lb/MMBtu) used in the previous analysis was used instead of the average calculated

VOC rate (0.0056 lb/MMBtu; based upon only about half of the permitted EGUs). The emission

rates applied to each of the future allocated EGUs are identified in the bottom row of Table 5.

The emission profile of the future allocated EGUs is presented in Table 6. This emission profile

is based upon assumed parameters for a 500 MW EGU operating year-round at 0.85 capacity

with a conversion factor of 10 MMBtu/MWh.

Table 6. Emissions Profile for 500 MW Future Allocated Coal-Fired EGU

Facility Name NO

x 

# SO 2 

# VOC CO PM 10 

# Emission Factors from Table 5 (lb/MMBtu) 0.072 0.078 0.0022 0.143 0.014

Annual Emissions (tpy) 1,340.3 1,452.0 41.3 2,661.9 260.6



# Applied BART Limits

With assistance from WRAP staff, ERG collected information on specific BART limits for all

coal-fired EGU sources subject to BART in CO , ND, and UT, as well as the Boardman EGU in

OR. These were used in place of the 2018 proj ections in the WRAP 2018 PRP inventory. The

information related to BART limits is summarized in Table 7.

In addition to these specific BART limits , the presumptive limit of 0.15 lb of SO 2 

# /MMBtu was

applied to all coal-fired EGUs th at have been determined to be either subject to BART (but for

which a specific limit had not yet been determ ined) or eligible for BART, according to the

WRAP’s latest WRAP BART Clearinghouse. 12 

# The methodology used to estimate the annual

SO 2 

# emissions based on the presumptive BART rate was to multiply the rate times the 2018 heat

input (MMBtu) from U.S. EPA’s CAMD database. 13 

# A summary of changes made as a result of

applying presumptive BART limits is shown in Table 8.

12 

# http://www.wrapair.org/

13 

# Listing of 2006 CAMD heat input rates provided by Pat Cummins, WRAP.

# Technical Memorandum – Final, Revised June 18, 2007

Page 9



# Table 7. Summary of BART Limits for Subject Coal Fired EGUs

2018b Base Case BART Limits Changes Due to BART Facility Name and Unit

NO

x 

# (tpy) SO 2 

# (tpy) NO

x 

# (tpy) SO 2 

# (tpy) NO

x 

# (tpy) SO 2 

# (tpy)

Colorado

Colorado Springs Utilities – Nixon Unit 1 2,416 4,774 2,331 4,073 -85 -701

Colorado Springs Utilities – Drake Unit 5 838 1,581 752 1,464 -86 -117

Colorado Springs Utilities – Drake Unit 6 1,493 2,999 1,344 566 -149 -2,433

Colorado Springs Utilities – Drake Unit 7 1,918 3,991 2,412 941 +494 -3,050

Public Service – Valmont Unit 5 2,190 709 2,279 879 +89 +170

Public Service – Cherokee Unit 4 3,834 1,457 4,317 1,750 +483 +293

Public Service – Comanche Un it 1 3,090 1,858 2,317 1,856 -773 -2

Public Service – Comanche Un it 2 3,053 1,828 2,587 1,830 -466 +2

Public Service – Hayden Unit 1 4,083 1,234 3,819 1,265 -264 +31

Public Service – Hayden Unit 2 4,018 1,530 3,488 1,633 -530 +103

Public Service – Pawnee Unit 1 4,900 13,700 3,942 2,225 -958 -11,475

Tri-State Generation – Craig Un it 1 4,685 657 5,426 1,066 +741 +409

Tri-State Generation – Craig Unit 2 5,866 1,891 5,548 1,051 -318 -840

Trigen – Colorado Energy Corp Unit 4 464 452 508 733 +44 +281

Trigen Colorado Energy Corp Unit 5 776 987 677 1,891 -99 +904

Change in CO Due to BART -1,877 -16,425

North Dakota

Coal Creek – Unit 143 5,186 14,706 4,285 3,781 -901 -10,925

Coal Creek – Unit 144 5,941 12,638 4,104 3,621 -1,837 -9,017

Leland Olds – Unit 121 2,811 17,322 2,661 3,578 -150 -13,744

Leland Olds – Unit 122 10,550 33,531 5,904 3,205 -4,646 -30,326

M.R. Young – Unit 152 9,071 19,997 3,857 2,571 -5,214 -17,426

M.R. Young – Unit 152 14,332 10,160 6,392 5,661 -7,940 -4,499

R.M. Heskett – Unit 154 945 2,754 858 1,660 -87 -1,094

Stanton – Unit 141 2,101 6,296 1,720 1,179 -381 -5,117

Change in ND Due to BART -21,156 -92,148

Oregon

Boardman 9,418 14,917 4,960 3,235 -4,458 -11,682

Total Change in OR Due to BART -4,458 -11,682

Utah

Hunter – Unit 1 6,564 2,610 4,851 2,239 -1,713 -371

Hunter – Unit 2 6,430 2,477 4,734 2,185 -1,696 -292

Hunter – Unit 3 6,255 950 5,717 1,682 -538 +732

Huntington – Unit 1 5,757 2,693 4,445 2,052 -1,312 -641

Huntington – Unit 2 5,294 13, 519 3,776 1,743 -1,518 -11,776

Total Change in UT Due to BART -6,777 -12,348

Overall Total Change Due to BART -34,268 -132,603

# Technical Memorandum – Final, Revised June 18, 2007

Page 10



# Table 8. Summary of Presumpti ve BART Limits for Subject and

Eligible Coal-Fired EGUs

Facility Name and Unit 2018b Base

Case

(tons SO 2 

# ) a 

# Presumptive

BART - Rate

(lb/MMBtu) 2018 Heat

Input

(MMBtu) Presumptive

BARTAnnual (tons

SO 2 

# )

Alaska – GVEA Healy Power Plant – Unit 1 366 0.15 140

Change in AK Due to Presumptive BART -226 tons SO 2



# Arizona

AZ Electric Power Cooperative, Inc. - Apache 2 1,439 0.15 15,248,939 1,144

AZ Electric Power Cooperative, Inc. - Apache 3 1,225 0.15 14,487,789 1,087

Coronado Generating Station – Unit 1B 6,449 0.15 28,551,063 2,141

Coronado Generating Station – Unit 2B 7,030 0.15 31,029,812 2,327

Irvington Generating Station – Unit 4 5,374 0.15 13,393,547 1,005

Change in AZ Due to Presumptive BART -13,813 tons SO 2



# Montana

Colstrip Steam Electric Station – Unit 1 b 

# 5,517 0.15 29,843,850 2,238

Colstrip Steam Electric Station – Unit 2 b 

# 5,640 0.15 29,276,157 2,196

PPL Montana – JE Corette Plant – Unit 2 3,757 0.15 14,895,194 1,160

Change in MT Due to Presumptive BART -9,320 tons SO 2



# New Mexico

San Juan Generating Station – Unit 1 2,630 0.15 26,974,922 2,023

San Juan Generating Station – Unit 2 2,677 0.15 27,460,582 2,060

San Juan Generating Station – Unit 3 4,288 0.15 43,863,371 3,290

San Juan Generating Station – Unit 4 4,444 0.15 45,582,346 3,419

Change in NM Due to Presum ptive BART -3,247 tons SO 2



# South Dakota -- Otter Tail Power Company 12,220 0.15 37,111,681 2,783

Change in SD Due to Presumptive BART -9,437 tons SO 2 

# Wyoming

Basin Electric – Laramie River Station – Unit 1 4,043 0.15 48,061,878 3,605

Basin Electric – Laramie River Station – Unit 2 4,096 0.15 48,607,657 3,646

Basin Electric – Laramie River Station – Unit 3 3,789 0.15 44,354,715 3,327

Pacificorp – Dave Johnston – Unit 3 8,555 0.22 c 

# 19,819,756 2,180

Pacificorp – Dave Johnston – Unit 4 4,250 0.15 c 

# 30,030,412 2,252

Pacificorp – Jim Bridger – Unit 1 7,069 0.15 c 

# 45,621,694 3,422

Pacificorp – Jim Bridger – Unit 2 6,906 0.15 c 

# 43,634,528 3,273

Pacificorp – Jim Bridger – Unit 3 6,537 0.15 c 

# 46,238,491 3,468

Pacificorp – Jim Bridger – Unit 4 4,107 0.15 c 

# 45,075,468 3,381

Pacificorp – Naughton Power Plant – Unit 1 6,518 0.41 c 

# 12,813,313 2,627

Pacificorp – Naughton Power Plant – Unit 2 8,694 0.41 c 

# 16,715,747 3,427

Pacificorp – Naughton Power Plant – Unit 3 5,980 0.21 c 

# 28,425,577 2,985

Pacificorp – Wyodak – Unit 1 8,281 0.32 c 

# 35,685,720 5,710

Change in WY Due to Presumptive BART -35,522 tons SO 2



# U.S. EPA Sources on Navajo Tribal Land lo cated in New Mexico

Four Corners Power Plant – Unit 1 1,385 0.21 d 

# 14,846,431 1,559

Four Corners Power Plant – Unit 2 1,687 0.21 d 

# 16,632,804 1,746

Four Corners Power Plant – Unit 3 2,122 0.21 d 

# 19,873,582 2,087

Four Corners Power Plant – Unit 4 8,509 0.21 d 

# 57,929,739 6,083

Four Corners Power Plant – Unit 5 9,729 0.21 d 

# 56,778,871 5,962

Change on Navajo Tribal Land Due to SO 2 

# Control Levels Proposed by U.S. EPA -5,995 tons SO 2

# Technical Memorandum – Final, Revised June 18, 2007

Page 11



# Table 8. Continued

Facility Name and Unit 2018b Base

Case

(tons SO 2 

# ) a 

# Presumptive

BART - Rate

(lb/MMBtu) 2018 Heat

Input

(MMBtu) Presumptive

BARTAnnual (tons

SO 2 

# )

Overall Total Change Due to Presumptive

BART -77,560 tons SO 2 e

a 

# 2018-18b emissions are based on 2004 heat input data from CAMD.

b 

# Colstrip Units 1 and 2 fire on both coal and petroleum coke. The BART limit was applied to the combined heat

input for 2018 and will be applied across both SCCs based on a percentage of the 2018-18b emissions.

c 

# Pacificorp unit emission rates are from BART control analysis performed by Pacificorp.

d 

# Emission rate is based on current U.S. EPA proposal for APS Four Corners. http://www.epa.gov/fedrgstr/EPAAIR/2006/September/Day-12/a15097.pdf

e 

# Totals may not equal sum of columns due to rounding.



# Several EGUs either have permit limits below the presumptive BART limit, or they operated below

the presumptive BART level in 2006 (i.e., lb SO 2 

# /MMBtu was calculated using 2006 heat input

[MMBtu] and 2006 mass emissions [tons of SO 2 

# ]). Therefore no presumptive BART reductions

were applied for the 2018 PRP inventory for th ese BART subject or eligible sources:

● Cholla Power Plant (AZ) Units 1-4, have pe rmitted emission limits based on the use of

baghouses and absorbers for SO 2 

# control; therefore no additional reductions are expected as a

result of BART implementation. PRP18 emissi ons were changed to reflect new permitted

limits.

● Navajo Generating Station (U.S . EPA source on Navajo Tribal land, located in northern AZ)

Units 1-3, operate at 0.1 lb of SO 2 

# /MMBtu. 2018b emissions were retained for PRP18.

● Reid Gardner (NV) Units 1-3, operate be low BART levels (i.e., 0.03 to 0.04 lb SO 2 

# /MMBtu).

2018b emissions were retained for PRP18.

● Mohave Power Plant (NV) Units 1-2, are permitted at 0.15 lb SO 2 

# /MMBtu. 2018b emissions

were retained for PRP18.

● TransAlta Centralia Units (WA) BW21 and BW 22, operate below BA RT levels (i.e., 0.04

and 0.05 lb SO 2 

# /MMBtu). PRP18 emissions were cal culated based on projected 2018 heat

input and current lb SO 2 

# /MMBtu emission rates.

Incorporated ENVIRON Revisions for Oil and Gas Point and Area Sources

Under a separate contract, ENVI RON revised 2018 estimates of SO 2 

# emissions from selected oil and

gas (O&G) point sources and all pollutants (NO

x 

# , SO 2 

# , VOC, CO) for O&G area sources in the

WRAP region. 14 

# ERG incorporated these revised 2018 O&G em issions into the overall database of

2018 point and area source emissions developed for this project, and the revised 2018 O&G

emissions are included in the emission summaries proved in the next section.

14 

# http://www.wrapair.org/forums/ssjf/documents/eictts/oilgas.html

# Technical Memorandum – Final, Revised June 18, 2007

Page 12



# Incorporated Pechan Revisions Related to SO 2 

# from Sources in §309 States

A study was conducted for the WRAP SSJF in 2006 by Pechan to update the 2018 SO 2 

# emission

projections (originally estimat ed by ERG and ENVIRON) for purposes of establishing SO 2 

# milestones for the 309 State Regional Haze State Implementation Plans. 15 

# The focus of that project

was to update some of the projected 2018 versio n 1 emissions estimates for non-utility sources

emitting more than 100 tons of SO 2 

# in the five milestone states (AZ, NM, UT, WY). (Note that

changes by Pechan to sources in OR were made as part of this project, although OR is no longer a

§309 state.) The Pechan proj ect resulted in revised 2018 SO 2 

# emissions from these industries:

copper smelters, lime manufacturing, pulp and pa per, oil and gas, chemical manufacturing,

petroleum refining, and cement production.

For the WRAP PRP18 inventory, ERG summarized th e changes from the Pechan report by state,

distributed these to the applicable S/L agencies as part of the collection of comments process

described above, and requested that each agency confirm these changes. Also, ERG obtained SCC

level changes from Pechan, in order to make the detailed changes at the SCC level for this WRAP

PRP18 inventory project. 16



# Most of the changes described in the Pechan repo rt (Tables III-1 through III-5) were made. However

not all of the changes should or could be made for the reasons described below:

● ASARCO-Ray Complex-Copper Sm elter and Mill (AZ): the 2018 SO 2 

# emissions were

already changed as part of the adjustment for the 2018b base case to 23,000 tons (not 21,000

as in the Pechan report). Th e correct value of 23,000 tons wa s confirmed by Arizona DEQ.

● Phelps Dodge-Miami Smelter (AZ): the 2018 SO 2 

# emissions were changed to 10,368 tons

(not 10,000 as in the Pechan report) base d on information provided by Arizona DEQ.

WRAP PRP18 Results (Final) – Summary

Tables 9 and 10 present the WRAP 2018b base case emissions for point and area sources, the net

changes made as a result of this project (i.e., total by state), and the re sulting draft WRAP PRP18

emissions inventory, at the state/tribal level.

WRAP PRP18 Results (Final) – Detailed Tables

Attachment 1 contains point sources summary tabl es for each state/tribe, which show the WRAP

2018b base case emissions, the net changes made duri ng this project (i.e., at the facility-, unit-,

emission point- or SCC-level), and the resulting final WRAP PRP18 emissions inventory. Tables are

provided for each state for point sources (first) and area sources (second). Attachment 2 contains the

area source summary changes, which show the WR AP 2018b base case emissions, the net changes

made during the project (i.e., SCC- level), and the resulting final WRAP PRP18 emissions inventory.

It should be noted that the records that were deleted are not itemized in these tables. The result of all

deletions is shown as a single line item on each table (if applicable), as these were extensive in many

15 

# “2018 SO 2 

# Emissions Evaluation for Non-Utility Point Sources,” Final Report. Prepared for the WRAP Stationary

Sources Joint Forum by Pechan. October, 2006. http://www.wrapair.org/forums/ssjf/documents/eictts/projections.html

16 

# E-mail from Jim Wilson, Pechan, to Pa ula Fields, ERG, February 27, 2007.

# Technical Memorandum – Final, Revised June 18, 2007

Page 13



# cases and would have made the length of the tabl es unmanageable for this memo. The S/L agencies

should refer to the comments/responses spreadshee t posted on the WRAP website as a reminder of

the records they requested to be delete d and how ERG responded to that request.

2002 Emission Inventory Changes

Although the focus of this project was on the most significant source s in the 2018 inventory

projections, many comments were received from the S/L agencies concerning the 2002 emissions.

The majority of requested changes affecting emissions were deferred based on guidance from

WRAP staff (i.e., these may be addressed durin g a future emissions inventory update). The 2002

changes that were made fe ll into these categories:

● Added missing non-CAMD emissions (see “Corr ected CAMD EGU Fac ility IDs and Added

Missing Records” above).

● Added and/or changed point source SCCs.

● Changed facility/plant IDs and/or names.

● Fixed tribal codes on some point sources.

● Modified BART flags to reflect st atus in states that have made definitive findings related to

“Subject” and “Not Subject” sources. (Note that prior to completion of the final PRP18

inventory, other flags related to “Eligible” or “Potentially Eligible” sources will be updated

to reflect the latest data in WRAP’s BART Clearinghouse.)

● Added new PM 10 

# and PM 2.5 

# records for 6 facilities in Nevada . These were also projected to

2018 and added to the PRP18 emissions inventory.

● Added new SO 2 

# and NO

x 

# records for 1 refinery in Wyomi ng. These were also projected to

2018 and added to the PRP18 emissions inventory.

● Added new area source fuel combustion emissions in South Dakota.

Attachment 3 includes a list of out standing issues that were identif ied during the project but have

been deferred until the next inventory update.

Next Steps

In conjunction with this memo, ERG prepared the final PRP18 em issions inventory and developed

SMOKE/IDA files that have been submitted to the WRAP RMC. By June 1, 2007, ERG will

develop updated PRP18 and 2002 pivot tables (whi ch will be posted on the WRAP Web site and

incorporated into the TSS web database), and PRP18 NIF files for subsequent upload to WRAP

EDMS.

The WRAP plans to complete two additional regi onal emissions and modeling analyses to support

Western haze planning in late 2007 or early 2008. A final baseline period (2000-04) emissions and

modeling analysis will be conduc ted in conjunction with a fina l Reasonable Progress 2018 (FRP18)

emissions and modeling analysis. Th e final baseline period analyses will have a limited focus, on

correcting inventory e rrors that affect the Reasonable Progres s demonstration, as the inventory from

that time period will have been supplanted by more recent and complete data (e.g., see Attachment 3

for some improvements that have already been iden tified). The associated FRP18 analysis will be

completed when the 13 contiguous WRAP states a nd U.S. EPA are able to provide their permitted

emission limits for sources subject to BART requirements. Other remaining 2018 inventory

projection corrections will also be applied in thos e analyses. These final analyses for regional haze

planning in the West will conducted simultaneously.

# Technical Memorandum – Final, Revised June 18, 2007

Page 14Table 9. Summary of 2018b Base Case Emissions Inventory, Net Changes Made by State and Resulting WRAPPRP18 Emissions Inventory – Point Sources (Tons per Year)StateNOxSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):AK 67,959.43 7,781.59 6,637.31 25,881.08 2,884.91 357.32 1,103.95AZ 77,738.22 94,407.68 9,466.23 33,242.90 9,893.22 1,644.24 729.29CA 109,514.89 49,631.75 54,631.70 123,795.15 33,191.68 19,496.84CO 112,239.70 69,213.14 98,629.89 58,211.27 28,697.25 306.79 623.03ID 14,048.16 25,467.31 3,060.02 38,019.05 1,741.19 643.01 1,649.87MT 62,583.10 45,321.07 10,445.96 62,353.62 11,266.02 691.74 421.68ND 92,097.99 162,704.76 2,493.21 22,589.46 4,369.38 3,051.53 522.95NM 74,874.05 41,392.29 26,187.38 57,506.25 3,391.82 1,749.33 123.26NV 69,016.45 24,040.65 4,112.87 20,745.67 6,200.35 1,534.57 1,172.78OR 31,760.79 21,686.48 41,168.92 53,654.91 13,517.81 16,659.86 1,016.13SD 24,725.86 15,268.20 3,522.79 6,858.87 1,044.86 256.93 101.60UT 96,974.44 52,952.88 13,599.53 98,373.32 18,381.76 5,812.25 2,081.94WA 49,396.97 51,355.44 28,013.12 187,705.34 12,096.19 4,676.22 5,495.06WY 132,115.76 145,099.58 27,541.60 60,503.77 42,819.39 19,495.90 810.87Tribal 92,580.06 32,894.77 2,864.32 12,987.96 7,748.84 3,206.27 125.44Net Changes to 2018b Base Case Emissions Inventory (TPY):AK -226.34 -1,118.54AZ -4,666.91 -24,070.72 211.84 796.24 984.32 44.41 23.80CACO 1,120.93 -12,234.64 -21,100.97 5,782.57 -401.45 -211.29 -85.85ID -1,675.35 -15,522.06 -41.37 -2,792.25 -335.07 -87.42 -31.09MT -217.91 -8,840.88 55.17 1,000.74 -131.79 -246.52ND -21,041.97 -95,626.23 1.79 -1,593.89 1,020.96 -262.26 -61.07NM -273.61 -9,011.88 -0.04 -130.31 -74.46 -87.43 -4.94NV -1,391.45 4,126.30 -247.12 6,968.94 -164.13 1,058.37 -308.31OR -6,813.49 -13,734.49 -530.41 -3,502.51 -433.54 -15,377.31 -184.31SD 1.00 -9,433.88 0.00UT -17,213.16 -15,014.36 -406.18 -1,920.34 -2,903.88 -1,311.37 -31.44WA 59.34 -13,911.46 -1,801.03 -80,108.37 -2,370.47 -289.69 -29.27WY 1,099.95 -49,955.64 728.59 4,278.61 19.80 -328.70 0.00Tribal 7,922.92 -4,495.17 317.51 572.15 1,293.29 536.03 31.44Table 9. Continued 

# Technical Memorandum – Final, Revised June 18, 2007

Page 15StateNOxSO2VOCCOPM10PM2.5NH3WRAP PRP18 Emissions Inventory (TPY):AK 67,959.43 7,555.25 6,637.31 25,881.08 1,766.37 357.32 1,103.95AZ 73,071.31 70,336.96 9,678.07 34,039.14 10,877.54 1,688.65 753.09CA 109,514.89 49,631.75 54,631.70 123,795.15 33,191.68 19,496.84CO 113,360.63 56,978.50 77,528.92 63,993.84 28,295.80 95.50 537.19ID 12,372.81 9,945.25 3,018.65 35,226.80 1,406.12 555.59 1,618.78MT 62,365.19 36,480.19 10,501.13 63,354.36 11,134.23 445.22 421.68ND 71,056.02 67,078.53 2,495.01 20,995.57 5,390.34 2,789.28 461.88NM 74,600.43 32,380.40 26,187.34 57,375.95 3,317.36 1,661.90 118.32NV 67,625.00 28,166.95 3,865.76 27,714.61 6,036.22 2,592.94 864.46OR 24,947.30 7,951.99 40,638.51 50,152.40 13,084.26 1,282.55 831.82SD 24,726.86 5,834.32 3,522.79 6,858.87 1,044.86 256.93 101.60UT 79,761.28 37,938.52 13,193.35 96,452.98 15,477.88 4,500.88 2,050.49WA 49,456.32 37,443.99 26,212.09 107,596.98 9,725.72 4,386.52 5,465.79WY 133,215.71 95,143.95 28,270.19 64,782.38 42,839.19 19,167.21 810.86Tribal 100,502.99 28,399.61 3,181.83 13,560.10 9,042.14 3,742.30 156.88

# Technical Memorandum – Final, Revised June 18, 2007

Page 16Table 10. Summary of 2018b Base CaseEmissions Inventory, Net Changes Made by State and Resulting WRAPPRP18 Emissions Inventory – Area Sources (Tons per Year)StateNOxSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions InventoryAK 9,293.35 6,043.71 16,539.14 29,055.82 21,531.05 6,877.71 639.23AZ 12,558.62 3,410.26 171,414.85 70,097.25 137,883.20 39,332.92 9,457.14CA 117,716.62 9,772.22 357,745.55 384,966.70 190,987.09 84,801.21CO 44,040.52 7,498.70 173,092.43 94,594.76 185,238.34 48,422.51 96.76ID 42,067.89 2,720.52 194,210.06 40,971.48 62,880.57 7,702.74 2,288.40MT 36,052.99 3,432.14 67,476.71 41,415.20 173,892.25 40,015.47 607.92ND 21,128.65 5,856.27 82,650.71 21,606.83 311,272.53 64,978.37 462.99NM 172,318.92 15,753.24 399,205.01 47,997.02 144,289.23 34,664.44 909.55NV 7,487.60 14,194.42 47,609.85 17,479.33 97,755.67 23,312.88 1,645.65OR 17,027.19 8,421.88 334,872.12 380,523.74 225,924.68 81,744.55 249.80SD 7,206.93 11,667.18 50,072.09 25,112.44 226,750.11 48,648.35 502.02UT 21,635.69 3,586.90 173,344.04 45,962.17 34,279.28 5,760.83 1,679.83WA 22,745.95 8,667.27 253,709.83 252,446.63 348,329.35 113,984.70 7,021.73WY 79,196.38 23,109.16 436,884.86 34,463.27 45,027.21 12,435.80 514.06Tribal 6,639.04 2.08 18,240.28 563.99 2,062.46 412.22 0.07Net Changes to 2018b Base Case Emissions InventoryAK -115.65 -0.11 -79.74 -0.42AZ 240.28 -2.06 -457.15 7,867.05 -1,122.80 291.68CACO 5,808.28 2.10 6,581.27 4,673.24ID 332.78MT -16,649.19 -1.64 6,553.79 -98.40ND 12,191.55 1.33 4,915.99 39.17NM -63,903.42 -4.84 -60,801.51 37,955.98 -2,689.03 -926.94NV -9.20 0.08 5,570.15 -1.23OR -3.99 -5.32 0.06SD -2,203.33 -7,582.58 166.01 -1,025.64 -2,674.01 -491.15 -6.22UT -5,700.69 -4.10 -13,395.34 -6.57WAWY -25,390.88 -12.16 -99,885.56 4,553.73TribalTable 10. Continued 

# Technical Memorandum – Final, Revised June 18, 2007

Page 17StateNOxSO2VOCCOPM10PM2.5NH3WRAP PRP18 Emissions InventoryAK 9,177.70 6,043.60 16,459.40 29,055.40 21,531.10 6,877.70 639.23AZ 12,798.90 3,408.20 170,957.70 77,964.30 136,760.40 39,624.60 9,457.14CA 117,716.62 9,772.22 357,745.55 384,966.70 190,987.09 84,801.21CO 49,848.80 7,500.80 179,673.70 99,268.00 185,238.30 48,422.50 96.76ID 42,067.90 3,053.30 194,210.10 40,971.50 62,880.60 7,702.70 2,288.40MT 19,403.80 3,430.50 74,030.50 41,316.80 173,892.30 40,015.50 607.92ND 33,320.20 5,857.60 87,566.70 21,646.00 311,272.50 64,978.40 462.99NM 108,415.50 15,748.40 338,403.50 85,953.00 141,600.20 33,737.50 909.55NV 7,478.40 14,194.50 53,180.00 17,478.10 97,755.70 23,312.90 1,645.65OR 17,023.20 8,421.90 334,866.80 380,523.80 225,924.70 81,744.60 249.80SD 5,003.60 4,084.60 50,238.10 24,086.80 224,076.10 48,157.20 495.80UT 15,935.00 3,582.80 159,948.70 45,955.60 34,279.30 5,760.80 1,679.83WA 22,745.95 8,667.27 253,709.83 252,446.63 348,329.35 113,984.70 7,021.73WY 53,805.50 23,097.00 336,999.30 39,017.00 45,027.20 12,435.80 514.06Tribal 6,639.04 2.08 18,240.28 563.99 2,062.46 412.22 0.07

# ATTACHMENT 1:

WRAP PRP18 EMISSIONS INVENTORY - FINAL

STATE SUMMARY TABLES

POINT SOURCES

These results incorporate changes made as a result of:

● Comments received from state/local agen cies. See page 3 of this memo and

comments/responses table for more

details: http://www.wrapair.org/forums/ssjf/ documents/eictts/projections.html )

● Addition of NO

x 

# and SO 2 

# records for non-CAMD units ope rating at facilities with

CAMD units. These had been dropped from the NEI, which was the basis for the WRAP

2018b inventory. See page 4 of this memo for details.

● Revised EGU projections to incorporate chan ges to the number and location of future

coal-fired EGUs projected to begin opera tion by 2018 in North Dakota, Idaho, and the

Navajo Tribal Lands. Also, emission rates for NO

x 

# , SO 2 

# , CO, and PM 10 

# at all future

EGUs were revised based on recently permitted coal-fired EGUs. See pages 4-8 of this

memo for details.

● Application of BART limits to coal-fired EGUs in Colorado, North Dakota, Utah, and

Oregon. See pages 8-9 of this memo for details.

● Application of presumptive BART limits for SO 2 

# for coal-fired EGUs in Alaska, Arizona,

Montana, New Mexico, South Dakota, Wyom ing, and U.S. EPA sources on Navajo

Tribal Land located in New Mexico. See pages 8-11 of this memo for details.

● Changes by ENVIRON to the SO 2 

# oil and gas point source emissions in Wyoming and

New Mexico. See page 11 of this memo for more information.

● Changes made to significant non-EGU SO 2 

# emitters (i.e., >100 TPY) as a result of an

update by Pechan for the §309 states (i.e., Ar izona, New Mexico, Utah, Wyoming) and

Oregon. See page 12 of this memo an d Pechan report for more details:

http://www.wrapair.org/forums/ssj f/documents/eictts/projections.html

# A1-1Alaska – Point SourcesStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY)All 67,959.4 7,781.6 6,637.3 25,881.1 2,884.9 357.3 1,104.0Net Changes to 2018-18b Emissions Inventory (TPY)2068 229000003 US Air Force - Clear Air Force Station 1 1A 10100224 1 -14.42068 229000003 US Air Force - Clear Air Force Station 2 2A 10100224 2 -13.12068 229000003 US Air Force - Clear Air Force Station 3 3A 10100224 3 -20.02090 209000001 Eielson Air Force Base 1 1A 10100224 1 -91.82090 209000001 Eielson Air Force Base 2 2A 10100224 2 -78.32090 209000001 Eielson Air Force Base 3 3A 10100224 3 -87.32090 209000001 Eielson Air Force Base 4 4A 10100224 4 -99.12090 209000001 Eielson Air Force Base 5 5A 10100224 5 -42.52090 209000001 Eielson Air Force Base 6 6A 10100224 6 -49.22090 20900004 US Army Fort Wainwright 3 3A 10100224 3 -84.12090 20900004 US Army Fort Wainwright 4 4A 10100224 4 -71.02090 20900004 US Army Fort Wainwright 5 5A 10100224 5 -104.32090 20900004 US Army Fort Wainwright 6 6A 10100224 6 -150.82090 20900002 Aurora Energy 3 3A 10100224 3 -132.32090 20900002 Aurora Energy 4 4A 10100225 4 -33.62090 20900002 Aurora Energy 5 5A 10100225 5 -37.12090 20900002 Aurora Energy 6 6A 10100224 6 -9.62090 0229000002 GVEA Healy Power Plant 1 1A 1 -226.3WRAP 2018 PRP Emissions Inventory (TPY)All 67,959.4 7,555.3 6,637.3 25,881.1 1,66.4 1,766.4 1,104.0

# A1-2Arizona – Point SourcesStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 77,738.2 94,407.7 9,466.2 33,242.9 9,893.2 1,644.2 729.3Net Changes to 2018-18b Emissions Inventory (TPY):04001 0400100059 SALT RIVER PROJECT 15.604001 040013222 TUCSON ELECTRIC POWER CO-SPRINGERVILLE -2,322.1 -2,405.6 3.2 14.9 1,128.8 294.504001 040014477 CORONADO GENERATING STATION -9,010.504001 PRJEGU03 Future Coal EGU (A)-335.1 -223.4 0.0 -130.3 -74.5 -87.404003 0400300037 AZ ELECTRIC POWER COOPERATIVE INC 145.5 0.404003 040032148 DOUGLAS LIME PLANT 979.804003 040033532 AZ ELECTRIC POWER COOPERATIVE INC -433.004003 PRJEGU04 Future Coal EGU (B)-335.1 -223.4 0.0 -130.3 -74.5 -87.404007 0400701391 PHELPS DODGE - MIAMI SMELTER 2,356.804013 3316 SRP AGUA FRIA GENERATING STATION 138.7 0.404013 3317 KYRENE GENERATING STATION 2.0 0.304017 040171807 SNOWFLAKE PULP MILL -62.504017 0401734839 Snowflake White Mountain Power240.0 225.0 22.0 225.0 49.004017 04017447 CHOLLA POWER PLANT -2,570.8 -11,492.504019 040192869 ARIZONA PORTLAND CEMENT COMPANY 128.004019 EGU0047 IRVINGTON GENERATING STATION -4,369.404021 V20621 000 Cactus Waste Systems (landfill)12.8 -145.004025 040252393 PHOENIX CEMENT -83.604025 040255992 NELSON LIME PLANT 291.104027 Arizona Clean Fuels Refinery395.5 250.7175.2 817.0 175.7 23.8Deleted Records -25.6 -15.0 -1.3 -75.3 -75.3WRAP 2018 PRP Emissions Inventory (TPY):All 73,071.3 70,337.0 9,678.1 34,039.110,877.5 1,688.7 753.1

# A1-3California – Point SourcesState CountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case EmissionsInventory (TPY)All 109,514.949,631.8 54,631.7 123,795.2 33,191.7 19,496.8Net Changes to 2018b Base CaseEmissions Inventory (TPY)No ChangesWRAP PRP18 Emissions Inventory(TPY)All 109,514.9 49,631.8 54,631.7 123,795.2 33,191.7 19,496.8

# A1-4Colorado – Point SourcesStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 112,239.7 69,213.1 98,629.9 58,211.3 28,697.3 306.8 623.0Net Changes to 2018-18b Emissions Inventory (TPY):All 40400311 -21,239.108041 0030 COLORADO SPRINGS UTILITIES - NIXON PLT 1 222 10100222 222-84.6 -700.808041 0030 COLORADO SPRINGS UTILITIES - NIXON PLT 002 01 10100501 002 5.5 1.808041 0004 COLORADO SPRINGS UTILITIES-DRAKE PLT 6 222 10100222 222 -148.9 -2,433.408041 0004 COLORADO SPRINGS UTILITIES-DRAKE PLT 5 222 10100222 222 -85.9 -116.908041 0004 COLORADO SPRINGS UTILITIES-DRAKE PLT 7 222 10100222 222 493.8 -3,050.308099 PRJEGU07 Future Coal EGU (A) #1 0110100201 01 -335.1 -223.4 0.0-130.3 -74.5 -87.408121 Future Coal EGU (Akron/ AES Power) #101 10100201 01 1,667.9 2,382.752.9 3,407.3 285.908087 PRJEGU06 Future Coal EGU (B) #1 0110100201 01 -335.1 -223.4 0.0-130.3 -74.5 -87.408087 Future Coal EGU (Ft. Morgan/ LS Power) #1 01 10100201 01 1,563.7 1,742.4 49.6 3,194.3 268.108031 0008 PUBLIC SERVICE CO - ARAPAHOE 019 01 20100101 019 12.4 0.608031 0008 PUBLIC SERVICE CO - ARAPAHOE 018 01 20100102 018 6.3 0.108031 0008 PUBLIC SERVICE CO - ARAPAHOE 012 01 20100102 012 3.4 0.208031 0008 PUBLIC SERVICE CO - ARAPAHOE 014 01 20100201 014 39.0 0.608013 0001 PUBLIC SERVICE CO - VALMONT 5 226 10100226 226 88.7 170.308013 0001 PUBLIC SERVICE CO - VALMONT 003 01 10200602 003 3.5 0.008013 0001 PUBLIC SERVICE CO - VALMONT 013 01 20100201 013 39.0 0.308013 0001 PUBLIC SERVICE CO - VALMONT 002 01 20100201 002 12.1 0.408077 0002 PUBLIC SERVICE CO CAMEO PLT 001 01 10100222 001 657.4 964.108001 0001 PUBLIC SERVICE CO CHEROKEE PLT 4 226 10100226 226 482.7 293.408001 0001 PUBLIC SERVICE CO CHEROKEE PLT 006 01 20100102 006 4.1 0.608001 0001 PUBLIC SERVICE CO CHEROKEE PLT 017 01 20100102 017 3.6 0.608101 0003 PUBLIC SERVICE CO COMANCHE PLT #3 Fut 1 10100201 01 -366.2 -457.835.7 -558.5 -139.6 -36.408101 0003 PUBLIC SERVICE CO COMANCHE PLT 2 222 10100222 222 -466.1 2.008101 0003 PUBLIC SERVICE CO COMANCHE PLT 1 226 10100226 226 -772.9 -1.708123 0023 PUBLIC SERVICE CO FORT SAINT VRAIN PLT 001 02 10100602 001 16.0 0.108107 0001 PUBLIC SERVICE CO HAYDEN PLT H1 222 10100222 222 -263.7 31.208107 0001 PUBLIC SERVICE CO HAYDEN PLT H2 226 10100226 226 -530.4 102.808087 0011 PUBLIC SERVICE CO PAWNEE PLT 1 222 10100222 222 -957.7 -11,475.508087 0011 PUBLIC SERVICE CO PAWNEE PLT 002 02 10200601 002 0.1 0.008081 0018 TRI STATE GENERATION CRAIG C2 222 10100222 222 -317.9 -839.908081 0018 TRI STATE GENERATION CRAIG C1 222 10100222 222 741.4 408.808085 0001 TRI STATE GENERATION NUCLA 009 01 10101002 009 0.0

# A1-5Colorado – Point Sources ContinuedStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH308059 0820TRIGEN - COLORADO ENERGYCORPORATION4 2 10200222 4 43.9 281.108059 0820TRIGEN - COLORADO ENERGYCORPORATION 5 2 10200222 6 -98.9 904.308049 0006CLIMAX MOLYBDENUM AMAX HENDERSONMILLALL -666.9DeletedRecords -85.8WRAP 2018 PRP Emissions Inventory (TPY):All 113,360.6 56,978.5 77,528.9 63,993.8 28,295.8 95.5 537.2

# A1-6Idaho – Point SourcesState CountyFIPSFacilityIDFacility NameEmissionUnit IDProcessIDSCCEmissionRelease PointIDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 14,048.2 25,467.3 3,060.0 38,019.0 1,741.2 643.0 1,649.9Net Changes to 2018-18b Emissions Inventory (TPY):16029 02900001 P4 Production LLC 10 1 30111299 10 -14,169.916051 05100017 Idaho Fresh Pak, Lewisville 10 2 10200501 10 119.916011 01100013 Idaho Supreme Potatoes 10 2 10200401 10 203.3Deleted Records-1,675.4 -1,675.4 -41.4 -2,792.3 -335.1 -87.4 -31.0WRAP 2018 PRP Emissions Inventory (TPY):All 12,372.8 9,945.2 3,018.7 35,226.8 1,406.1 555.6 1,618.8

# A1-7Montana – Point SourcesStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 62,583.1 45,321.1 10,446.0 62,353.6 11,266.0 691.7 421.7Net Changes to 2018-18b Emissions Inventory (TPY):30087 087-0008 COLSTRIP STEAM ELECTRIC STATION 1 226 10100226 226 -2,557.030087 087-0008 COLSTRIP STEAM ELECTRIC STATION 1 801 10100801 801 -721.230087 087-0008 COLSTRIP STEAM ELECTRIC STATION 2 226 10100226 226 -2,804.030087 087-0008 COLSTRIP STEAM ELECTRIC STATION 2 801 10100801 801 -640.230087 087-0008 COLSTRIP STEAM ELECTRIC STATION 8 1 20100107 1.030111 111-0015 PPL MONTANA - JE CORETTE PLANT 2 226 10100226 226 -2,596.530013 PRJEGU10 Future Coal EGU (A) #1 110100201 1 -335.1 -223.4 0.0 -130.3 -74.5 -87.430065 PRJEGU11Future Coal EGU (Bull Mountain - RoundupPlant)#1 1 10100201 1 -1,496.6 -1,061.1 -18.5 -2,010.4 -328.4 -131.130065 PRJEGU11Future Coal EGU (Bull Mountain - RoundupPlant) #2 1 10100201 1 1,016.4 1,452.0 43.6 2,178.0 174.230003 PRJEGU09Future Coal EGU (Rocky Mountain Power -Hardin Generating Station)#1 1 10100201 1 -107.2 -71.5 0.0 -41.7 -23.8 -28.030013Future Coal EGU (Highwood/ SouthernMontana Electric) #1 1 10100201 1703.6 382.0 30.2 1,005.2 120.6WRAP 2018 PRP Emissions Inventory (TPY):All 62,365.2 36,480.2 10,501.1 63,354.4 11,134.2 445.2 421.7

# A1-8Nevada – Point SourcesState CountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 69,016.5 24,040.6 4,112.9 20,745.7 6,200.3 1,534.6 1,172.8Net Changes to 2018-18b Emissions Inventory (TPY):32001 AP49110197AMOR IV CORP & STILLWATERGEOTHERMAL1071 1135 20101001 1135 -165.132001 AP49110464 AMOR IX CORPORATION 1844 1997 20101001 1997 -81.332001 AP49110464 AMOR IX CORPORATION 1847 2000 20101001 2000 -97.932003 AP49110399 Nevada Power Sunrise Station 103006 12.632003 AP49110400NEVADA POWER COMPANY- ReidGardner Generating Station 101002 722.0 599.232003 AP49110466 So Cal Edison - Mohave 1848 2001 10100212 2001 10.9 83.4 -559.032003 AP49110466 So Cal Edison - Mohave 1849 2002 10100212 2002 12.3 93.4 -647.432003 AP49110466 So Cal Edison - Mohave 1850 2003 10100212 2003 0.6 0.0 0.0 0.1 0.032003 AP49110466 So Cal Edison - Mohave 1851 2004 10100212 2004 1.1 0.0 0.0 0.1 0.032003 AP49110466 So Cal Edison - Mohave 10100212 846.932011 PRJEGU15Future Coal EGU (Newmont - NorthernNevada Energy)#1 01 10100201 01 -171.30.0 -44.7 -35.032019 AP32410387 NEVADA CEMENT COMPANY 1534 1629 30501109 1629 -5.532019 AP32410387 NEVADA CEMENT COMPANY 1537 1632 30501109 1632 -1,791.632019 AP32410387 NEVADA CEMENT COMPANY 1540 1635 30501109 1635 -3.732019 AP32410387 NEVADA CEMENT COMPANY 1543 1638 30501109 1638 -891.532033Future Coal EGU (White Pine EnergyAssociation/ LS Power) #1 01 1010020101 3,909.2 4,355.9 124.0 7,985.8 670.132033 PRJEGU16 Future Coal EGU (A) #1 0110100201 01 -335.1 -223.4 0.0 -130.3 -74.5 -87.432003 423 Nevada Sun Peak Partnerships* 78.8 0.1 1.7 6.0 0.232019 AP49110091Sierra Pacific Company - Ft ChurchillPower Station*57.9 10.932019 AP32410387 Nevada Cement Company* 142.5 42.832029 AP49110194Sierra Pacific Company - TracyGenerating Station* 31.2 26.7Deleted Records-2,182.5 -6.4 -51.6 -1,069.5 -474.9 -345.7 -308.3WRAP 2018 PRP Emissions Inventory (TPY):All 67,625.0 28,166.9 3,865.8 27,714.6 6,036.2 2,592.9 864.5* These records (complete facilities or certain units only) earlier had missing FIPS codes and so were not included in the state totals in 2018b base case.

# A1-9New Mexico – Point SourcesStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 74,874.0 41,392.3 26,187.4 57,506.3 3,391.8 1,749.3 123.3Net Changes to 2018-18b Emissions Inventory (TPY):35001 00008 Rio Grande Portland Cement 409.235001 00011Public Service Company of New Mexico ReevesGenerating Station 0.1 0.0 -4.935015 350150008 Indian Basin Gas Plant -1,662.435015 350150010 Artesia Refinery 11.235015 350150011 Artesia Gas Plant -1,115.735015 350150285 Dagger Draw Gas Plant 18.035025 350250004 Maljamar Gas Plant 200.135025 350250007 Denton Plant -104.435025 350250008 Jal No. 3 -401.535025 350250034 Maddox Station 51.3 0.035025 350250035 Linam Ranch Gas Plant -1,230.235025 350250044 Eunice Gas Plant -1,745.435025 350250054 Cunningham Station 0.4 0.035025 350250060 Eunice Gas Plant 25.035025 350250061 Monument Plant 298.435025 350250063 Saunders Plant 38.335031 350310008 Ciniza Refinery -292.835031 350310032 Escalante Station 7.1 0.035031 PRJEGU18 Future Coal EGU (A)-335.1 -223.4 0.0 -130.3 -74.5 -87.435045 350450023 San Juan Refinery (Bloomfield) 34.835045 350450247 San Juan River Gas Plant -24.935045 350450902 San Juan Generating Station 2.6 -3,246.5WRAP 2018 PRP Emissions Inventory (TPY):All 74,600.4 32,380.4 26,187.3 57,375.9 3,317.4 1,661.9 118.3

# A1-10North Dakota – Point SourcesState CountyFIPSFacilityIDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 92,098.0 162,704.8 2,493.2 22,589.5 4,369.4 3,051.5 523.0Net Changes to 2018-18b Emissions Inventory (TPY):38053 16 Grasslands Plant 300.038055 126 Coal Creek Station -2,738.2 -19,941.538057 13 Antelope Valley Station 640.038057 289 Coyote 410.038057 65 Great Plains Synfuel Plant 280.038057 12 Leland Olds Station-4,796.6 -44,070.438057 125 Stanton Station-381.0 -5,117.238059 226 Mandan Refinery 110.038059 172 RM Heskett Station - Mandan-86.7 -1,094.0 60.038065 165 M R Young Station -13,153.4 -21,925.338105 270 Tioga Gas Plant 981.7 -981.738093 Future Coal EGU (Great River Energy) 221.1 147.4 5.5 351.4 31.938011 Future Coal EGU (Gascoyne/Montana Dakota Utility) 2,261.7 1,364.5 73.9 3,639.2 308.138089 Future Coal EGU (South Heart/Great Northern Power)1,675.4 726.0 46.5 2,792.3 186.2Deleted Records-5,026.1 -5,034.0 -124.1 -8,376.8 -1,005.2 -262.3 -61.1WRAP 2018 PRP Emissions Inventory (TPY):All 71,056.0 67,078.5 2,495.0 20,995.6 5,390.3 2,789.3 461.9

# A1-11Oregon – Point SourcesState CountyFIPSFacilityIDFacility NameEmission UnitIDProcessIDSCCEmission ReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 31,760.8 21,686.5 41,168.9 53,654.9 13,517.8 16,659.9 1,016.1Net Changes to 2018-18b Emissions Inventory (TPY):41001 00038 Northwest Pipeline Corporation -0.041003 02298 Oregon State University -0.241005 01850 Blue Heron Paper Company -0.0 -0.141005 02145 West Linn Paper Company 319.6 -0.141007 00004 Fort James Operating Company -559.3 -0.241009 01849 Boise Cascade Corporation -574.9 -0.541029 00025 Timber Products Co. -0.141033 00030 U.S. Forest Industries, Inc. -0.041035 00093 Aqua Glass West, Inc. -0.041041 00005 Georgia-Pacific West, Inc. -162.8 -0.341043 06024 Entek International LLC -0.141043 03501 Pope & Talbot, Inc. -46.8 -0.241043 00547 Wah Chang -0.141043 00471 Weyerhaeuser Company -136.9 -0.241049 00016 Portland General Electric Company -4,456.4 -11,678.441049 00031 Portland General Electric Company 2.8 2.841051 02025 Chevron Products Company -0.141051 03009 Dynea Overlays, Inc. -0.041051 02050 Oregon Health Sciences University -0.141051 01876 Owens-Brockway Glass Container Inc. 0.0 -72.441059 30-0118 Hermiston Power Plant 79.9 23.7 19.6 -351.9 115.841071 06142 Smurfit Newsprint Corporation -314.7 -0.1Deleted Records-2,439.8 -606.9 -550.0 -3,150.6 -549.3 -15,302.8 -184.3WRAP 2018 PRP Emissions Inventory (TPY):All 24,947.3 7,952.0 40,638.5 50,152.413,084.3 1,282.5 831.8

# A1-12South Dakota – Point SourcesStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionRelease PointIDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 24,725.915,268.2 3,522.8 6,858.9 1,044.9 256.9 101.6Net Changes to 2018-18b Emissions Inventory (TPY):46051 28.0801-29 Otter Tail PowerCompany 1 223 10100223 223 -9,436.846051 28.0801-29 Otter Tail Power Company 41 20100101 4 0.1 0.046051 28.0801-29 Otter Tail Power Company 31 10100501 3 0.0 0.1 0.146051 28.0801-29 Otter Tail Power Company 21 10100501 2 0.9 2.7WRAP 2018 PRP Emissions Inventory (TPY):All 24,726.9 5,834.3 3,522.8 6,858.9 1,044.9 256.9 101.6

# A1-13Utah – Point SourcesState CountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 96,974.4 52,952.9 13,599.5 98,373.318,381.8 5,812.3 2,081.9Net Changes to 2018-18b Emissions Inventory (TPY):49007 10081 Carbon Power Plant 1.5 0.549011 10119 Salt Lake Refinery 35.549011 10122 Flying J Refinery (Big West Oil Co.) -82.549011 10123 Phillips Refinery 17.649015 10237 Hunter Power Plant-3,936.4 71.0 -177.049015 10238 Huntington Power Plant-2,815.2 -12,403.5 -413.049015 PRJEGU22 Future Coal EGU (A)-335.1 -223.4 -0.0 -130.3 -74.5 -87.449027 10313 Cricket Mountain Plant 0.0049027 10327 Intermountain Generation Station-705.1 16.9 -212.2 -55.449029 10007 Devil's Slide Plant -13.949035 10335 Salt Lake City Refinery -128.249035 10355 Gadsby Power Plant 0.5 0.049041 PRJEGU24 Future Coal EGU (NEVCO EnergyCo.) 100.5 -683.5 -0.0 -351.8 -26.1 -47.249047 PRJEGU25 Future Coal EGU (B)-335.1 -223.4 -0.0 -130.3 -74.5 -87.4Deleted Records-9,188.9 -1,380.6 -423.0 -1,307.9 -1,926.6 -1,034.0 -31.4WRAP 2018 PRP Emissions Inventory (TPY):All 79,761.3 37,938.5 13,193.4 96,453.015,477.9 4,500.9 2,050.5

# A1-14Washington – Point SourcesStateCountyFIPSFacilityIDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 49,397.0 51,355.4 28,013.1 187,705.312,096.2 4,676.2 5,495.1Net Changes to 2018-18b Emissions Inventory (TPY):53007 0001ALUMINUM CO OF AMERICA WENATCHEEWORKS-40.8 -2,134.7 -7.3 -11,431.0 -121.453015 0015 LONGVIEW ALUMINUM, L.L.C. 1.0 1.0 3.0 3.0 0.753015 0144 Mint Farm Energy Center LLC97.3 82.6 44.0 68.8 97.9 96.953039 0001 GOLDENDALE ALUMINUM-44.4 -305.5 -28.9 -12,811.1 -170.7 -62.853041 New Plant Cardinal FG831.2 72.5 56.1 772.0 20.19 101.453041 0010 TransAlta Centralia Generation 8.6 -3,884.253073 0001 INTALCO ALUMINUM CORP FERNDALE-55.9 -3,339.9 -16.8 -24,644.9 -507.7 -72.6Deleted Records -737.7 -4,402.3 -1,848.2 -32,063.2 -1,691.7 -355.6 -29.9WRAP 2018 PRP Emissions Inventory (TPY):All 49,456.3 37,444.0 26,212.1 107,597.0 9,725.7 4,386.5 5,465.8

# A1-15Wyoming - Point SourcesStateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b Emissions Inventory (TPY):All 132,115.8 145,099.6 27,541.6 60,503.842,819.4 19,495.9 810.9Net Changes to 2018-18b Emissions Inventory (TPY):56001 5600100002 MOUNTAIN CEMENT CO -2.156003 5600300003 AMERICAN COLLOID CO_LOVELL179.7 14.8 -120.356005 5600500046 PACIFICORP_WYODAK -2,571.056005 5600500063BLACK HILLS CORPORATION_SIMPSON21.956005 Future Coal EGU (Dry Fork/ Basin Electric) 785.6 1,256.9 61.3 2,356.7 188.556005 PRJEGU28 Future Coal EGU (Wygen Station)111.7 372.3 37.2 558.5 22.356005 PRJEGU29 Future Coal EGU (Two Elk)1,928.5 2,752.0 214.0 3,976.2 413.356005 PRJEGU30 Future Coal EGU (A)-335.1 -223.4 -0.0 -130.3 -74.556007 5600700001SINCLAIR OIL CORP-SINCLAIRREFINERY -993.856009 5600900001 PACIFICORP_DAVE JOHNSTON 4.7 -8,370.856013 5601300008DEVON SFS OPERATING_BEAVERCREEK-16.056013 5601300028BURLINGTON RESOURCES_LOSTCABIN -791.656021 5602100001 FRONTIER REFINING, INC. -672.456023 5602300004PACIFICORP_NAUGHTON POWERPLANT-12,132.756023 5602300013 EXXON SHUTE CREEK I -2,669.756025 5602500005 SINCLAIR REFINERY - CASPER -223.356029 5602900007MARATHON OIL CO _ OREGON BASINGAS PLANT 200.456029 5602900012HOWELL PET CORP_ELK BASIN GASPLANT-324.756031 5603100001BASIN ELECTRIC_LARAMIE RIVERSTATION -1,350.756035 00001EXXON -LABARGE DEHYDRATIONFACILITY -696.556037 5603700002 GENERAL CHEMICAL 209.356037 5603700008 UNION PAC_BRADY -41.256037 5603700022 Simplot Phosphates -758.856037 5603700048FMC CORP_GREEN RIVERPLANT_SODIUM PROD-57.056037 5603701002 PACIFICORP_JIM BRIDGER 11.4 -11,069.7

# A1-16Wyoming - Point Sources Continued)StateCountyFIPSFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH356037 PRJEGU32 Future Coal EGU (B) -335.1 -223.4 0.0 -130.3 -74.556041 5604100009 CHEVRON CARTER CREEK -715.956041 5604100012 BP AMERICA - WHITNEY CANYON -9,171.556043 5604300003HILAND PARTNERS, LLC_HILAND GASPLANT-66.856045 5604500001WYOMING REFINING CO_NEWCASTLEREFINERY 313.156005 0083Western Gas Resources - Horse Creek/GasDraw Compressor Stn.*19.7 9.2 24.356005 0120Western Gas Resources - BakerSprings/Butcher Compressor Stn.* 33.2 8.0 87.356005 0134Western Gas Resources - Pronghorn/OrynCompressor Stn.*38.5 49.3 70.956005 0137Western Gas Resources - Sioux/Jr. RenoCompressor Stn.* 29.7 1.3 77.456035 0018Jonah Gas Gathering - Falcon CompressorStn.*126.6 143.5 97.856035 0020Jonah Gas Gathering - Bird Canyon/Co.Line Compressor Stn.* 132.7 156.3 65.556035 0034Jonah Gas Gathering - Luman CompressorStn.* 95.2 178.2 69.5Deleted Records-1,727.0 -1,933.1 -129.5 -2,844.9 -335.1 -328.7 0.0WRAP 2018 PRP Emissions Inventory (TPY):All 133,215.7 95,143.9 28,270.2 64,782.442,839.2 19,167.2 810.9* These records (complete facilities or certain units only) earlier had missing FIPS codes and so were not included in the state totals for the 2018b base case.

# A1-17Tribal – Point SourcesStateCountyFIPSTribalCodeFacility IDFacility NameEmissionUnit IDProcessIDSCCEmissionReleasePoint IDNOXSO2VOCCOPM10PM2.5NH3WRAP 2018-18b EmissionsInventory (TPY):All 92,580.132,894.8 2,864.3 12,988.0 7,748.8 3,206.3 125.4Net Changes to 2018-18b Emissions Inventory (TPY):00000 687 10747 BONANZA POWER PLANT7,850.7 1,265.1 62.8 523.4 680.9 562.8 31.400000 687 10766 Riverbend Field55.6 0.3 83.5 53.0 177.3 148.100000 780 350450002 Four Corners Power Plant -5,994.600000 780Future Coal EGU (Desert Rock/Sithe GlobalPower) 3,315.6 3,315.6 165.8 5,527.6 1,105.200000 281 00011 Devon Energy Riverton Dome Plant51.7 269.1 88.2 52.6Deleted Records-3,350.7 -3,350.7 -82.7 -5,584.5 -670.1 -174.8WRAP 2018 PRP EmissionsInventory (TPY):All 100,503.028,399.6 3,181.8 13,560.1 9,042.1 3,742.3 156.9

# ATTACHMENT 2:

WRAP PRP18 EMISSIONS INVENTORY - DRAFT

STATE SUMMARY TABLES

AREA SOURCES

These results incorporate changes made as a result of:

• Comments received from state/local agen cies. See page 3 of this memo and

comments/responses table for more

details: http://www.wrapair.org/forums/ssjf/ documents/eictts/projections.html )

• Changes by ENVIRON to the area source oil and gas emissions in Alaska, Arizona,

Colorado, Montana, North Dakota, New Mexic o, Nevada, Oregon, South Dakota, Utah and

Wyoming. See page 11 of this memo for more information.

# A2-1Alaska – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Alaska All9,293.4 6,043.7 16,539.1 29,055.8 21,531.1 6,877.7 639.2Net Changes to 2018b Base Case Emissions Inventory (TPY):Alaska 2310000220- Oil and Gas Production: Drill rigs -114.1 -0.1Alaska 2310021500- Oil and Gas Production: Natural Gas well completion – flaring and venting -1.6 -79.7 -0.4WRAP PRP18 Emissions Inventory (TPY):Alaska9,177.7 6,043.6 16,459.4 29,055.4 21,531.1 6,877.7 639.2

# A2-2Arizona – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Arizona All12,558.6 3,410.3 171,414.9 70,097.3 137,883.2 39,332.9 9,457.1Net Changes to 2018b Base Case Emissions Inventory (TPY):Arizona 2310010100- Oil and Gas Production:Crude Petroleum Oil well heaters 0.20.0 0.0Arizona2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing &standing/working/breathing16.0Arizona 2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices3.6Arizona 2310020600- Oil and Gas Production: Natural Gas Compressor engines 7.80.0Arizona 2310021100- Oil and Gas Production: Natural Gas well heaters 7.40.0 1.6Arizona 2310021300- Oil and Gas Production: Natural Gas well pneumatic devices1.7Arizona 2310021400- Oil and Gas Production: Natural Gas well dehydrators10.6Arizona2310030210- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing &Standing/Working/Breathing16.9Arizona 2311000000- Construction: All Processes -779.1 -155.8Arizona 2311000100- Construction: All Processes,Wind Erosion -1,121.3 -333.7Arizona 2460100000- Consumer and Commercial- All Personal Care Products Total -229.5Arizona 2460200000- Consumer and Commercial- All Household Products Total -102.0Arizona 2460400000- Consumer and Commercial- All AutomotiveAftermarket Products Total -35.3Arizona 2460500000- Consumer and Commercial- All Coatingsand Related Products Total -97.2Arizona 2460600000- Consumer and Commercial- All Adhesives andSealants Total: All Solvents -57.0Arizona 2460800000- Consumer and Commercial- All FIFRA Related Products Total -179.6Arizona2460900000- Consumer and Commercial Miscellaneous Products (Not OtherwiseCovered) Total-7.2Arizona 2461800000- Commercial Pesticide Application:All Processes Total 602.1Arizona 2465000000- Consumer Solvents- All Products/Processes Total -2.0Arizona 2465100000- Consumer Solvents- Personal Care Products Total -125.7Arizona 2465200000- Consumer Solvents- Household Products Total -137.1Arizona 2465400000- Consumer Solvents- Automotive Aftermarket Products Total -315.7Arizona 2465600000- Consumer Solvents- Adhesivesand Sealants Total -302.6Arizona 2465800000- Consumer Solvents- Pesticide Application Total 13.5Arizona 2601000000- On-site Incineration All Categories Total -1.2 0.0 -0.0 -0.0 -0.0 -0.0Arizona 2610000100- Open Burning All Categories Yard Waste- Leaf Species Unspecified -3.4 -13.5 -4.6 -4.6Arizona 2610000400- Open Burning All Categories Yard Waste- Brush Species Unspecified -2.3 -16.9 -2.1 -2.1Arizona 2610000500- Open Burning All Categories Land Clearing Debris 241.8561.1 8,187.4 821.7 821.7Arizona 2610030000- Open Burning Residential Household Waste -15.6 -2.1 -85.2 -288.1 -34.7 -31.1Arizona 2810050000- Other Combustion- Motor Vehicle Fires Total -0.1-0.9 -3.5 -2.8 -2.8WRAP PRP18 Emissions Inventory (TPY):Arizona All12,798.9 3,408.2 170,957.7 77,964.3 136,760.4 39,624.6 9,457.1

# A2-3California – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):California All 117,716.6 9,772.2 357,745.6 384,966.7 190,987.1 84,801.2Net Changes to 2018b Base Case Emissions Inventory (TPY):No ChangesWRAP PRP18 Emissions Inventory (TPY):California All 117,716.6 9,772.2 357,745.6 384,966.7 190,987.1 84,801.2

# A2-4Colorado – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Colorado All 44,040.5 7,498.7 173,092.4 94,594.8 185,238.3 48,422.5 96.8Net Changes to 2018b Base Case Emissions Inventory (TPY):Colorado 2310000220- Oil and Gas Production:Drill rigs 361.6 2.1 154.8 996.0Colorado2310010100- Oil and Gas Production: CrudePetroleum Oil well heaters0.7 0.2Colorado2310010200- Oil and Gas Production: CrudePetroleum Oil well tanks - flashing &standing/working/breathing63.5Colorado2310010300- Oil and Gas Production: CrudePetroleum Oil well pneumatic devices 32.0Colorado2310020600- Oil and Gas Production: Natural GasCompressor engines4,005.8 1,485.4 3,412.2Colorado2310021100- Oil and Gas Production: Natural Gaswell heaters 1,014.9 213.2Colorado2310021300- Oil and Gas Production: Natural Gaswell pneumatic devices231.7Colorado2310021400- Oil and Gas Production: Natural Gaswell dehydrators 97.3Colorado2310021500- Oil and Gas Production: Natural Gaswell completion - flaring and venting208.7 4,233.1 51.6Colorado2310023000- Oil and Gas Production: Natural GasCBM gas well - Dewatering pump engines 216.6Colorado2310030210- Oil and Gas Production: Natural GasLiquids Gas well tanks - Flashing &Standing/Working/Breathing283.5WRAP PRP18 Emissions Inventory (TPY):Colorado All 49,848.8 7,500.8 179,673.7 99,268.0 185,238.3 48,422.5 96.8

# A2-5Idaho – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Idaho All 42,067.9 2,720.5 194,210.1 40,971.5 62,880.6 7,702.7 2,288.4Net Changes to 2018b Base Case Emissions Inventory (TPY):Idaho2104004000- Residential Distillate Oil CombustionTotal332.8WRAP PRP18 Emissions Inventory (TPY):Idaho All 42,067.9 3,053.3 194,210.1 40,971.5 62,880.6 7,702.7 2,288.4

# A2-6Montana – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Montana All36,053.0 3,432.1 67,476.7 41,415.2 173,892.3 40,015.5 607.9Net Changes to 2018b Base Case Emissions Inventory (TPY):Montana 2310000220- Oil and Gas Production:Drill rigs -801.7 -1.6 10.3 5.9Montana2310010100- Oil and Gas Production: Crude Petroleum Oil wellheaters69.30 13.9Montana2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks -flashing & standing/working/breathing 6,073.7Montana2310010300- Oil and Gas Production: Crude Petroleum Oil wellpneumatic devices129.5Montana2310020600- Oil and Gas Production: Natural Gas Compressorengines -15,083.0 420.7Montana 2310021100- Oil and Gas Production: NaturalGas well heaters -684.3 -143.7Montana2310021300- Oil and Gas Production: Natural Gas well pneumaticdevices-156.2Montana2310021500- Oil and Gas Production: Natural Gas well completion -flaring and venting 131.9 86.5 33.0Montana2310030220- Oil and Gas Production: Natural Gas Liquids Gas welltanks - Flashing & Standing/Working/Breathing-0.6DeletedRecords All-281.4 -0.0 -10.1 -7.5WRAP PRP18 Emissions Inventory (TPY):Montana All19,403.8 3,430.5 74,030.5 41,316.8 173,892.3 40,015.5 607.9

# A2-7Nevada – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Nevada All7,487.6 14,194.4 47,609.9 17,479.3 97,755.7 23,312.9 1,645.7Net Changes to 2018b Base Case Emissions Inventory (TPY):Nevada 2310000220- Oil and Gas Production: Drill rigs 4.3 0.1Nevada 2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters -0.1 -0.1Nevada2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing &standing/working/breathing-9.9Nevada 2310010300- Oil and Gas Production: Crude PetroleumOil well pneumatic devices 1.5Nevada 2310020600- Oil and Gas Production: Natural Gas Compressor engines -8.3Nevada 2310021100- Oil and Gas Production: Natural Gas well heaters -5.1 -1.1Nevada 2310021300- Oil and Gas Production: Natural Gas well pneumatic devices -1.2Nevada 2310021400- Oil and Gas Production: Natural Gas well dehydrators -0.2Nevada 2401002000- Surface Coating- Architectural Coatings - Solvent-based Total 1,949.1Nevada 2401003000- Surface Coating- Architectural Coatings - Water-based Total 1,720.5Nevada 2401015000- Surface Coating- FactoryFinished Wood 530.0Nevada 2401020000- Surface Coating- Wood Furniture 582.7Nevada 2401040000- Surface Coating- Metal Cans -0.5Nevada 2401050000- Surface Coating- Miscellaneous Finished Metals 195.5Nevada 2401055000- Surface Coating- Machinery and Equipment 71.9Nevada 2401060000- Surface Coating- Large Appliances 898.1Nevada 2401065000- Surface Coating- Electronic and Other Electrical 76.4Nevada 2401070000- Surface Coating- Motor Vehicles 11.4Nevada 2401080000- Surface Coating- Marine 48.5Nevada 2401085000- Surface Coating- Railroad 77.1Nevada 2401090000- Surface Coating- MiscellaneousManufacturing Total 870.7Nevada 2401100000- Surface Coating- Industrial Maintenance Coatings Total 1,231.3Nevada 2401200000- Surface Coating- Other Special Purpose Coatings Total 1,116.3Nevada 2415005000- Degreasing- Furniture and Fixtures 251.2Nevada 2415025000- Degreasing- Industrial Machinery and Equipment 0.2Nevada 2415030000- Degreasing- Electronic and Other Elec. 26.9Nevada 2415035000- Degreasing- Transportation Equipment 26.1Nevada 2415040000- Degreasing- Instruments and Related Products 0.7Nevada 2415045000- Degreasing- Miscellaneous Manufacturing 0.4Nevada 2415230000- Degreasing- Electronic and Other Elec. 66.4Nevada 2415245000- Degreasing- Miscellaneous Manufacturing 268.4Nevada 2415345000- Degreasing- Miscellaneous Manufacturing 218.5

# A2-8Nevada – Area Sources ContinuedStateSCCNOXSO2VOCCOPM10PM2.5NH3Nevada 2415360000- Degreasing- Auto Repair Services 3,457.6Nevada2460110000- Consumer and Commercial Personal Care Products: Hair Care ProductsTotal772.3Nevada2460130000- Consumer and Commercial Personal Care Products: Fragrance ProductsTotal311.7Nevada2460150000- Consumer and Commercial Personal Care Products: Nail Care ProductsTotal24.5Nevada2460190000- Consumer and Commercial Personal Care Products: MiscellaneousPersonal Care Products Total96.5Nevada2460230000- Consumer and Commercial Household Products: Fabric and Carpet CareProducts Total34.4Nevada2460250000- Consumer and Commercial Household Products: Waxes and PolishesTotal127.4Nevada2460270000- Consumer and Commercial Household Products: Shoe and Leather CareProducts Total19.6Nevada2460290000- Consumer and Commercial Household Products: MiscellaneousHousehold Products Total92.4Nevada2460410000- Consumer and Commercial Automotive Aftermarket Products: DetailingProducts Total151.6Nevada2460420000- Consumer and Commercial Automotive Aftermarket Products:Maintenance and Repair Products Total506.9Nevada2460510000- Consumer and Commercial Coatings and Related Products: AerosolSpray Paints Total 504.2Nevada2460520000- Consumer and Commercial Coatings and Related Products: CoatingRelated Products Total31.5Nevada 2460610000- Consumer and Commercial Adhesives andSealants: Adhesives Total 4.3Nevada 2460810000- Consumer and Commercial FIFRA Related Products: Insecticides Total 524.2Nevada2460820000- Consumer and Commercial FIFRA Related Products: Fungicides andNematicides Total 2.0Nevada2460900000- Consumer and Commercial Miscellaneous Products (Not OtherwiseCovered) Total1,268.5DeletedRecords All-12,587.5WRAP PRP18 Emissions Inventory (TPY):Nevada All7,478.4 14,194.5 53,180.0 17,478.1 97,755.7 23,312.9 1,645.7

# A2-9New Mexico – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):New Mexico All172,318.9 15,753.2 399,205.0 47,997.0 144,289.2 34,664.4 909.6Net Changes to 2018b Base Case Emissions Inventory (TPY):New Mexico 2310000220- Oil and Gas Production:Drill rigs -2,483.7 -13.9 67.7 434.2New Mexico 2310000330- Oil and Gas Production: Artificial lift 763.3 0.1 7.9 160.9New Mexico 2310000440- Oil and Gas Production: Saltwater disposal engines 170.4 9.5 24.5New Mexico 2310010100- Oil and Gas Production: CrudePetroleum Oil well heaters 416.0 0.3 103.9New Mexico2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing& standing/working/breathing1,194.3New Mexico2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumaticdevices122.1New Mexico 2310010700- Oil and Gas Production: Crude Petroleum Oil well fugitives 622.1New Mexico 2310010800- Oil and Gas Production: CrudePetroleum Oil well truck loading 154.5New Mexico 2310020600- Oil and Gas Production: Natural Gas Compressor engines -54,605.9 1.4 4,879.0 38,614.0New Mexico 2310020700- Oil and Gas Production: Natural Gas well fugitives 52,087.1New Mexico 2310020800- Oil and Gas Production: Natural Gas well truck loading 501.3New Mexico 2310021100- Oil and Gas Production: Natural Gas well heaters -6,296.4 7.3 -921.0New Mexico 2310021300- Oil and Gas Production: NaturalGas well pneumatic devices -3,693.7New Mexico 2310021400- Oil and Gas Production: Natural Gas well dehydrators -7,020.7New Mexico2310021500- Oil and Gas Production: Natural Gas well completion - flaring andventing-1,809.8 0.1 -70,522.1 -455.2New Mexico 2310021600- Oil and Gas Production: Natural Gas well venting 63,212.9New Mexico2310023000- Oil and Gas Production: Natural Gas CBM gas well - Dewateringpump engines66.9New Mexico2310030210- Oil and Gas Production: Natural Gas Liquids Gas well tanks -Flashing & Standing/Working/Breathing, Uncontrolled-31,670.1New Mexico 2311000100- Construction: All Processes Wind Erosion -586.9 -312.5New Mexico 2311010000- Construction: Residential Total -90.3 -26.4New Mexico 2311020000- Construction: Industrial/Commercial/Institutional Total -307.1 -89.8New Mexico 2311030000- Construction: RoadConstruction Total -1,704.8 -498.4DeletedRecords All-124.2 -0.1 -70,753.3 -5.3WRAP PRP18 Emissions Inventory (TPY):New Mexico All108,415.5 15,748.4 338,403.5 85,953.0 141,600.2 33,737.5 909.6

# A2-10North Dakota – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):North Dakota All 21,128.7 5,856.3 82,650.7 21,606.8 311,272.5 64,978.4 463.0Net Changes to 2018b Base Case Emissions Inventory (TPY):North Dakota 2310000220- Oil and Gas Production: Drill rigs 362.1 1.3North Dakota2310010100- Oil and Gas Production: CrudePetroleum Oil well heaters32.1 6.4North Dakota2310010200- Oil and Gas Production: CrudePetroleum Oil well tanks - flashing &standing/working/breathing2,814.4North Dakota2310010300- Oil and Gas Production: CrudePetroleum Oil well pneumatic devices 40.3North Dakota2310020600- Oil and Gas Production: Natural GasCompressor engines11,648.5North Dakota2310021100- Oil and Gas Production: Natural Gaswell heaters 115.7 24.3North Dakota2310021300- Oil and Gas Production: Natural Gaswell pneumatic devices26.4North Dakota2310021400- Oil and Gas Production: Natural Gaswell dehydrators 362.0North Dakota2310021500- Oil and Gas Production: Natural Gaswell completion - flaring and venting33.7 1,657.2 8.5North Dakota2310030220- Oil and Gas Production: Natural GasLiquids Gas well tanks - Flashing &Standing/Working/Breathing15.7DeletedRecords All -0.6WRAP PRP18 Emissions Inventory (TPY):North Dakota All 33,320.2 5,857.6 87,566.7 21,646.0 311,272.5 64,978.4 463.0

# A2-11Oregon – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Oregon All 17,027.2 8,421.9 334,872.1 380,523.7 225,924.7 81,744.6 249.8Net Changes to 2018b Base Case Emissions Inventory (TPY):Oregon2310020600- Oil and Gas Production: Natural Gas Compressorengines-4.8Oregon 2310021100- Oil and Gas Production: NaturalGas well heaters 0.8 0.1Oregon2310021300- Oil and Gas Production: Natural Gas wellpneumatic devices 0.2Oregon2310021400- Oil and Gas Production: Natural Gas welldehydrators-5.5WRAP PRP18 Emissions Inventory (TPY):Oregon All 17,023.2 8,421.9 334,866.8 380,523.8 225,924.7 81,744.6 249.8

# A2-12South Dakota – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):South Dakota All 7,206.911,667.2 50,072.1 25,112.4 226,750.1 48,648.4 502.0Net Changes to 2018b Base Case Emissions Inventory (TPY):South Dakota2103002000- Commercial/InstitutionalBituminous/Subbituminous Coal Combustion20.6 36.1 0.2 11.7 17.1 15.1South Dakota 2199003000- Total Area Source Lignite Coal Combustion 10.0 34.7 1.8 3.5 16.5 0.4South Dakota 2310000220- Oil and Gas Production: Drill rigs 92.9 0.2 0.2 1.2South Dakota2310010100- Oil and Gas Production: Crude PetroleumOil well heaters 2.0 0.3South Dakota2310010200- Oil and Gas Production: Crude PetroleumOil well tanks - flashing & standing/working/breathing171.1South Dakota2310010300- Oil and Gas Production: Crude PetroleumOil well pneumatic devices 6.0South Dakota2310020600- Oil and Gas Production: Natural GasCompressor engines-46.1South Dakota2310021100- Oil and Gas Production: Natural Gas wellheaters 1.3 0.2South Dakota2310021300- Oil and Gas Production: Natural Gas wellpneumatic devices0.3South Dakota2310021400- Oil and Gas Production: Natural Gas welldehydrators -3.1DeletedRecords-2,284.0 -7,653.6 -10.5 -1,042.5 -2,707.5 -506.7 -6.2WRAP PRP18 Emissions Inventory (TPY):South Dakota All 5,003.6 4,084.6 50,238.1 24,086.8 224,076.1 48,157.2 495.8

# A2-13Utah – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Utah All 21,635.7 3,586.9 173,344.0 45,962.2 34,279.3 5,760.8 1,679.8Net Changes to 2018b Base Case Emissions Inventory (TPY):Utah 2310000220- Oil and Gas Production: Drillrigs -1,267.3 -4.1 31.4 213.2Utah2310010100- Oil and Gas Production: Crude Petroleum Oil wellheaters77.1 15.5Utah2310010200- Oil and Gas Production: Crude Petroleum Oil welltanks - flashing & standing/working/breathing 6,760.1Utah2310010300- Oil and Gas Production: Crude Petroleum Oil wellpneumatic devices-154.0Utah2310020600- Oil and Gas Production: Natural Gas Compressorengines -3,395.2 91.1Utah 2310021100- Oil and Gas Production: Natural Gaswell heaters -1,082.5 -227.4Utah2310021300- Oil and Gas Production: Natural Gas well pneumaticdevices-247.1Utah 2310021400- Oil and Gas Production: Natural Gas well dehydrators -2,301.9Utah2310021500- Oil and Gas Production: Natural Gas well completion -flaring and venting -31.4 -1,541.2 -7.9Utah2310030210- Oil and Gas Production: Natural Gas Liquids Gas welltanks - Flashing & Standing/Working/Breathing-16,021.4DeletedRecords All-1.4 -12.3 -0.0WRAP PRP18 Emissions Inventory (TPY):Utah All 15,935.0 3,582.8 159,948.7 45,955.6 34,279.3 5,760.8 1,679.8

# A2-14Washington – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Washington All 22,746.0 8,667.3 253,709.8 252,446.6 348,329.4113,984.7 7,021.7Net Changes to 2018b Base Case Emissions Inventory (TPY):No changesWRAP PRP18 Emissions Inventory (TPY):Washington All 22,746.0 8,667.3 253,709.8 252,446.6 348,329.4113,984.7 7,021.7

# A2-15Wyoming – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Wyoming All 79,196.4 23,109.2 436,884.9 34,463.345,027.2 12,435.8 514.1Net Changes to 2018b Base Case Emissions Inventory(TPY):Wyoming 2310000220- Oil and Gas Production: Drill rigs 2,446.5 -12.2406.8 3,688.4Wyoming2310010100- Oil and Gas Production: CrudePetroleum Oil well heaters 17.4 3.4Wyoming2310010200- Oil and Gas Production: CrudePetroleum Oil well tanks - flashing &standing/working/breathing1,523.4Wyoming2310010300- Oil and Gas Production: CrudePetroleum Oil well pneumatic devices-658.5Wyoming2310020600- Oil and Gas Production: NaturalGas Compressor engines -32,073.3 464.2Wyoming2310021100- Oil and Gas Production: NaturalGas well heaters4,150.7 871.6Wyoming2310021300- Oil and Gas Production: NaturalGas well pneumatic devices 947.6Wyoming2310021400- Oil and Gas Production: NaturalGas well dehydrators-75,093.8Wyoming2310021500- Oil and Gas Production: NaturalGas well completion - flaring and venting -38.5 -1,891.3 -9.7Wyoming2310023000- Oil and Gas Production: NaturalGas CBM gas well - Dewatering pump engines106.3Wyoming2310030210- Oil and Gas Production: NaturalGas Liquids Gas well tanks - Flashing &Standing/Working/Breathing-24,857.2Wyoming2310030220- Oil and Gas Production: NaturalGas Liquids Gas well tanks - Flashing &Standing/Working/Breathing-726.8WRAP PRP18 Emissions Inventory (TPY):Wyoming All 53,805.5 23,097.0 336,999.3 39,017.045,027.2 12,435.8 514.1

# A2-16Tribal – Area SourcesStateSCCNOXSO2VOCCOPM10PM2.5NH3WRAP 2018b Base Case Emissions Inventory (TPY):Tribal All 6,639.0 2.1 18,240.3 564.0 2,062.5 412.2 0.1Net Changes to 2018b Base Case Emissions Inventory (TPY):No ChangesWRAP PRP18 Emissions Inventory (TPY):Tribal All 6,639.0 2.1 18,240.3 564.0 2,062.5 412.2 0.1

# ATTACHMENT 3:

OUTSTANDING ISSUES

# A3-1Outstanding Issues Related toPRP18 Emissions InventoryStateCommenterComment SummaryResponse for PRP 2018 AnalysisData SourceReprojectionRequired?2002Changes?ERG StatusAK A.EdwardsResponded to questions about 2 missingcoal-fired boilers in 2002 and 2018 atUSArmy Ft. WainwrightNeed to add 2 records for PM10 (at min.)for these missing boilers in both 2002 and2018E-mail from Alice, 4/20/07Yes - butnot at thistimeYes - butnot at thistimeDefer 2002 and 2018changesAZ L. ToopalPer Pechan Report, add new plant,Arizona Clean Fuels Refinery, to be built40 mi. east of Yuma. Permitted emissions.- 251 tpy of SO2We will add this new facility to 2018.Growth in the AZ refining sector will beadjusted for this new facility.AZ_Proposed Changes &Feedback Request.xlsYesNoAdded 5 records forthe new facility(pollutant totals) to2018 database. ADEQshould provideprocess-level datausing SCC nos. andunit/process IDs for fileformatting purposes.AZ S. DiBiaseDesert Basin (facility IDV20620/EGU0049) CO emissions appearto be off...should be 105 tons not 1,051for SCC 20100201.4-16: E-mail to Scott asking if we shouldchange 2002 and 2018 to 105 tons. E-mail 3-15-07 TBD TBD TBDAZ P. DeNeePoint Sources It was difficult to track thevarious point sources used in the NOxpivot tables and the 2018-18bspreadsheet because the source namesare not in alphabetical order. They arefortunately in order in the PM10 andPM2.5 Pivot Tables.Agreed - we will fix the pivot tables toorder plants alphabetically.WRAP 2018 EI Review -Phil DeNee.doc No NoNo action required foremissions, but changewill be made in pivottablesCOCurtis TaipaleColorado was the first state in the countryto have voters approve a RenewableEnergy Standard (RES) that requiresutilities with over 40,000 customers togenerate or purchase a minimum amountof electricity from renewable sources. By2018, the benefit of this program mightreduce our coal-fired generating needs byat more 7-10%. Similarly, I understandthat California has a similar program withbenefits approaching 13% by 2007. Itseems that we should take credit in the2018 modeling for these types ofprograms. It would take some technicalanalysis to nail down the exact estimatesthat I am unable to quickly quantify bytoday's deadline. We will provide sometechnical analysis in our SIP to addressthis issue but having it quantified in theregional modeling would be the bestoption. Thoughts?Response from Lee Gribovicz: "...add therenewable credit to the list..." ofoutstanding issues.E-mail from Curt andresponse from Lee on5/10/07No No Defer issueOutstanding Issues Related to PRP18 Emissions Inventory (Continued)



# A3-2StateCommenterComment SummaryResponse for PRP 2018 AnalysisData SourceReprojectionRequired?2002Changes?ERG StatusID C. RamsdellSent 2005 SO2 emissions for four (4)facilities with 4 different SCCs (120 to 215tons) not shown in 80% summary table;suggest to add to inventory (Facilities:BAF Blackfoot/ID 1100012; IdahoSupreme Potatoes/ID 1100013; LarsenFarms/ID 3300002; Idaho Fresh Pak/ID5100017)BAF Blackfoot/SCC 10200402 and LarsenFarms/SCC 10300401 are not in 2018-18b or 2002 inventories; we will not addthem at this time (have requested 2002emissions from IDEQ so that these can beadded to 2002 first, then projected to2018). Idaho Supreme Potatoes/SCC10200401 has 11.27 ton SO2 in 2018-18b, and Idaho Fresh Pak/SCC 10200501has 0.01 ton SO2 in 2018; we will set their2018 emissions to 2005 levels asprovided by IDEQ. We defer adding theBAF Blackfoot and Larsen Farmsemissions until the 2002 and 2018inventories are updated next year. (Weprovided this explanation to Chris on 4-16-07.)point_summary_ID_cut.xlsNoYes - butdeferredChanged SO2emissions for 2facilities (2 records).Deferred changes toBAF Blackfoot andLarsen FarmsID C.RamsdellProvided spreadsheet with dual-fueledsource emissionsThe data provided do not include SCCs,and are for 2005, so they cannot bedirectly compared to the existing 2018-18b database. We will assume that theseare accounted for in the 2002 and 2018inventory, otherwise IDEQ would need toprovide these by Facility ID, and SCC. Werequested this information from Chris on4-16-07.) V-mail from Chris indicates thatdata cannot be provided until later thisweek, which will be too late for thisproject. This comment will be deferreduntil next inventory update. DualEmissions.xls TBD No DeferredIDC.RamsdellProvided spreadsheet with the top 10 areasource SCCs for NOx and SO2 by countyNOx:all top 10 SCCs have 2005emissions that are <2018, except for2102006000 (Industrial natural gasboilers) where ID 2005 = 1619 tons (for44 counties) and 2018-18b = 1325 tons(for 6 counties only). Will make nochanges to the 2018 inventory at this timeas reconciliation will be required for the2002 inventory and reproject to 2018.Top 10 SCC SO2 NOXby County.xlsYes - butdeferredYes - butdeferred DeferredOutstanding Issues Related to PRP18 Emissions Inventory (Continued)



# A3-3StateCommenterComment SummaryResponse for PRP 2018 AnalysisData SourceReprojectionRequired?2002Changes?ERG StatusIDC.RamsdellProvided spreadsheet with the top 10 areasource SCCs for NOx and SO2 by countyNOx:For SCC 2010008000 (Industrialwood boilers), the 2018-18b NOxemissions seem excessive as comparedto 2005, where ID 2005 = 1840 tons and2018-18b = 31803 tons. The large 2018-18b estimate is driven by an equally large2002 estimate, which appears to beincorrect (i.e., based on EPA gapfilling ofNEI, which was used for WRAP 2002).We have requested 2002 emissions fromChris for this SCC on 4-16-07; v-mail fromChris said that data cannot be provideduntil later this week, which will be too latefor this project. This change to 2002 and2018 for NOx and SO2 will be deferreduntil the next inventory update.Top 10 SCC SO2 NOXby County.xlsYes - butdeferredYes - butdeferredDeferredID C.RamsdellENVIRON has raised an issue that stage Iand II refueling SCCs (250xxxxxxx) aremissing from the area source inventory.Chris Ramsdell with the state hasconfirmed that they did include these sccsin their 2002 area source inventory.These sources did not appear in WRAP2002 inventory (taken from 2002 NEI).Adding to 2018 now would require reprojection from 2005, and would create aninconsistency with 2002. Will be includedin revision to 2002 and next revision to2018.EmailNo - not atthis time.Yes - butnot at thistime. DeferredID M. EdwardsMeeting scheduled withTASCO/Amalgamated Sugar on March27, after which BART level will be known.4-6-07: sent e-mail to Mike Edwardsrequesting BART limit for TASCO.E-mail_MikeEdwards_3-23-07_RE Idaho EIinformation from 31907conference call.docNo No DeferredNV L. CampbellAdd 2002 CO emissions for 2 newfacilities (NP Clarkand Sunrise Stations)and 1 existing facility (SPPC Valmy) andproject to 2018 (Facility IDs, AP49110398,AP49110399, and AP49110457.)SPPC Valmy is in 2018, but CO amountwas below 80% cut-off; no change isneeded. Will need to add CO boileremissions (SCC 10300601) for NP Clarkand Sunrise Stations later.NV_2018-18b_point_summary_80% review by NDEP.xls(CO worksheet)Yes - butnot at thistimeYes - butnot at thistime.No action requiredNVM. Doyle -Clark Co.Request to add PM2.5 emissions (assumePM2.5=PM10) for all natural gas firedpower plants (excluding Copper Mtn, andChuck Lenzie which already have PM2.5estimates).Would need to add PM2.5 emissions for2002 and project to 2018. This may bedone during next RP inventory revision,but not at this time,.Email 4-3-07Yes - butnot at thistimeYes - butnot at thistimeNo action requiredOutstanding Issues Related to PRP18 Emissions Inventory (Continued)



# A3-4StateCommenterComment SummaryResponse for PRP 2018 AnalysisData SourceReprojectionRequired?2002Changes?ERG StatusNVRodneyLangston –Clark Co.WRAP projections should include PM10controls on fugitive dust sources from ourPM10 SIPERG researched this issue, withassistance from Clark Co. staff (Doyle andLendis). Appendix L of the SIP providescontrol reductions for unstable vacantland, construction, unpaved road dust,paved road dust, unpaved parking, andrace tracks. The only relevant category tothe PRP18 point and area sourceinventory is a subset ofconstruction:construction activities. TheAppendix L documentation provides anemission reduction of 87% (due towatering), a rule penetration of 98% (onlysites 1/4 acre or larger), and varying ruleeffectiveness values - 40% in 2001, 64%in 2002, and 80% in 2003 and beyond.This results in an overall control reductionof 34% in 2001 and 68% in 2006. TheAppendix L documentation provides 2001annual uncontrolled emissions (23,109tpy) and controlled emissions (15,252 tpy)for the Valley-Wide Inventory; the only2006 inventories in the documentation are24-hour inventories. For the WRAPinventories, there are three constructionsource categories: residential,industrial/commercial/institutional, androad. The 2002 emissions for ClarkCounty are 30,802 tpy; the 2018emissions are 44,407 tpy.These reductions canbe incorporated intothe next version of the2018 inventory forClark County.SD D. HealeyProvided 2005 PM2.5, SO2, and NOxemissions for area source distillate fuelcombustion. In follow-up call with ERG, itwas noted that only 2005 fuel use isreadily available (not 2002)We will not make these changes, sincethis will require a re-projection from 2005to 2018. This change will be deferred untilnext year with 2002 and 2018 EIs arerevised/finalized again.SD AREA NEIdistillate.xlsYes - butnot at thistimeYes - butnot at thistimeNo Action RequiredOutstanding Issues Related to PRP18 Emissions Inventory (Continued)



# A3-5StateCommenterComment SummaryResponse for PRP 2018 AnalysisData SourceReprojectionRequired?2002Changes?ERG StatusUT D. McMurtrieConfirmed changes to SO2 sourcesrecommended in Pechan report for:Holcim - Devil's Slide, Kennecott Smelter& Refinery, Flying J Refinery, Tesoro -SLC Refinery, Chevron - Salt LakeRefinery, and Phillips Refinery. Allfacilities' emissions change for 2018, andall except Holcim and Kennecott changein 2002.4/10: P.Fields (ERG) talked toD.McMurtrie who said she would send ane-mail to confirm changes are okay.Confirmation e-mail was never received.UT_Proposed Changes &Feedback Request.xlsNoYes - forFlying J,TesoroSLC,ChevronSL, andPhillipsRefineries- but not atthis time. TBDWA S. OttersonProvided updated 2005woodstove/fireplace inventory to replacethe 2002 inventoryWe compared the 2002 WRAP emissionsto the 2005 WA emissions, and found(2002/2005 ratio): NOx 89%, SO2 84%,VOC 121%, CO 97%, PM10 96%, PM2.590%. We will defer these changes untilWRAP does a final 2002 and 2018inventory revision.WA_Updates.xlsNo - not atthis tmeYes - butnot at thistime No action requiredWA S. Otterson"LAKESIDE INDUSTRIES, INC. /CENTRALIA" (FIPS 53041, plant ID 15)has been split into two (2) different plants:asphalt (756) and rock crushing (1953)4-11-07: E-mail to Sally asking for newrecords to replace old records; confirmonly a 2018 change (and not 2002). Mayrequire re-projection if new SICs (differentgrowth factors may now apply) WA_Updates.xls TBD TBD TBDWA S. OttersonProvided actual 2005 emissions data for 3facilities listed with Plant IDs PRJ*** inNIF format (Goldendale Energy Center,Frederickson Power LP, Chehalis PowerLP/Chehalis Generation Facility)We will replace the "PRJ" plant IDs withthe state IDs, but cannot project from2005 at this time.WA_Updates.xls andAdds_Replace_NIF.mdb2005projectionis deferredYes -plant IDsonlyChanged Plant Ids for2018 (PRJFACxxx)WA S. OttersonProvided actual 2005 oil refinery data (inNIF format) to replace their current 2002WRAP data (Puget Sound Refining Co.,Tesoro Northwest Co., Conoco Phillips,BP Cherry Point Refinery)We will keep in data on file, but cannotmake changes at this time.WA_Updates.xls andAdds_Replace_NIF.mdbYes, butnot at thistimeYes, butnot at thistimeNo action requiredWA S. OttersonProvided actual 2005 emissions data (inNIF format) to replace current 2002WRAP data for several other facilities(Mutual Materials, Longview Fibre,Weyerhaeuser co.)We will keep in data on file, but cannotmake changes at this time.WA_Updates.xls andAdds_Replace_NIF.mdbYes, butnot at thistimeYes, butnot at thistime No action requiredOutstanding Issues Related to PRP18 Emissions Inventory (Continued)



# A3-6StateCommenterComment SummaryResponse for PRP 2018 AnalysisData SourceReprojectionRequired?2002Changes?ERG StatusWY L. BocchinoDyno Nobel received a permit last yearwhich included the addition of a nitric acidplant, an ammonium nitrate plant, thereplacement of two engines, and the*restoration* of 2 existing boilers. The netchange in potential emissions is between30 and 200 tpy depending on thepollutant. The permit is attached. Whatmore do you need?The records in the existing 2018-18bdatabase, by SCC and unit ID, do notmatch any of the unit IDs shown on thepermit. Sent e-mail on 4-11 to Brian andLori requesting them to match the existingrecords/units/SCCs with permit limits; wemay decide to pull all current 2002 and2018 Dyno Nobel records and replacethem with new records to match theexisting permit limits (based on the unitsin the permit); this could not be done untilthe next revision of the EI since there are2002 implications.E-mail_Lori_Morequestions and info re WY2018 projections.doc andDynoNobelMD-1502.docTBD TBD TBDWY B. BohlmannDyno Nobel MTBE plant (operable in2002) has been dismantled and airpermits are being proposed for additionalacid plants. Thus 2018 emissions may besignificantly different from the 2002emissions.We need specific SCC level emissionchanges for 2018 in order to put theimpact of these changes in the toinventory. In the absence of additionalinformation from the agency, no changeswill be madeE-mail 4-11-07 No No TBDWY B. BohlmannFor Plant ID 5602100002 (DYNO NOBELINC. - CHEYENNE PLANT), change SCCfrom 30688801 to 30104199We will either change SCC as requestedor pull all records and replace with newrecords in order to match to Unit IDs,permit limits (see previous comment andresponse).Wrap WY_2018-18b_point_summary_80%.xls (NOx, SO2, VOC,CO, PM10 worksheet)TBD TBD TBDWY B. BohlmannCombustion SCC growth factors (sodaash production) for 2018 SO2 emissionsfor FMC Corp-Green River Plant-Sodiumproducts (Plant ID 5603700048) perPechan SO2 Report for 309 States (Oct2006), Table III-5.Will change SO2 emissions for theapplicable EU (EU ID#1014 and 1015) to3555 tons from 3612 tons. Will obtainSCC level info from Pechan.WRAP WY_ProposedChanges & FeedbackRequest.xls No NoRevised SO2emissionsWY B. BohlmannPer Pechan Report, Table III-5, madeFCCU emission adjustments for 2002 and2018 (i.e., growth factor adjustment forfuel combustion sources for 2018 SO2emissions for Frontier Refining Inc. (PlantID 5602100001)).For 2018, we will change the 2018 totalSO2 emissions for the facility to 1292 tonsfrom 1964 tons. Per WRAP, no changesto 2002 should be made at this time.WRAP WY_ProposedChanges & FeedbackRequest.xlsNoYes - butnot at thistimeRevised 2018 SO2emissionsWY B. BohlmannPer Pechan Report, Table III-5, possibleFCCU adjustments (2002 and 2018);growth factor adjustment for fuelcombustion sources for 2018 SO2emissions for Sinclair Oil Corp-SinclairRefinery (Plant ID 5600700001).Will change the 2018 total SO2 emissionsfor the facility to 3709 tons from 4703tons. Will not change 2002 emissions atthis time.WRAP WY_ProposedChanges & FeedbackRequest.xlsNoYes - butnot at thistimeRevised 2018 SO2emissionsOutstanding Issues Related to PRP18 Emissions Inventory (Continued)



# A3-7StateCommenterComment SummaryResponse for PRP 2018 AnalysisData SourceReprojectionRequired?2002Changes?ERG StatusWY B. BohlmannPer Pechan Report, Table III-5, madeFCCU adjustments (2002 and 2018);growth factor adjustment for fuelcombustion sources for 2018 SO2emissions for Sinclair Oil Corp-CasperRefinery (Plant ID 5602500005)Will change the 2018 total SO2 emissionsfor the facility to 1165 tons from 1389tons. Will obtain SCC level info fromPechan. Will not change 2002 emissionsat this time per WRAP.WRAP WY_ProposedChanges & FeedbackRequest.xls NoYes - butnot at thistimeRevised 2018 SO2emissionsWY B. BohlmannThe Santa Fe Snyder Riverton Plant, nowcalled Devon Energy ProductionCompany, L.P. Riverton Dome, is on theWind River Indian Reservation and needsto be listed as such. It is currently listed asa Wyoming facility instead of a tribalfacility.Facility name will be changed; facility willbe moved from Wyoming to the WindRiver Indian Reservation.E-mail from BrianBohlmann on 5/3/07. No YesChanged facility nameand assigned to WindRiver IndianReservation.WY B. BohlmannCelotex Corporation has a FIPS code of56029:0:3 indicating that this is aWyoming facility. Based on a file search,this facility is not in Wyoming.Facility was identified as BPB America,Cody Wallboard Plant.E-mail from BrianBohlmann on 5/15/07. No YesInformation arrived toolate for revision. Will beadded to theoutstanding issues list.