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, 

Revised1

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 Progress emissions inventory for 2018 (PRP18). 

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

pollution within each state, and on the specific source categories whose 2018 emissions were 

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

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

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

providing comments, as well as for the Contractor 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 PRP emissions inventory, and present summary 

results for the WRAP region and detailed results for each jurisdiction.3

 The summary results are 

contained in Attachment 1 (for point sources, by state) and Attachment 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 recognized the authority of tribes to implement 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 submit 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 requirements 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, Washington, 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 sources, etc.). Updates to the oil and gas (O&G) 

area source emissions, and O&G point source SO2 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 made 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 codes [SCCs], changing facility names 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 projected 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 include, in addition to a draft and final technical 

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

under ERG’s previous project). ERG also provided 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 PRP18 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 database 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 changes were necessary to make the 2018 version 1 

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

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

● Added SO2 emissions for 4 facilities in WY; and 

● Added NOx, 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 database, 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 & Feedback Request” itemized other potential changes 

that might need to be made to each jurisdiction’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 SO2 emissions from major sources located in §309 states (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-fueled sources were accounted for in the emissions inventory. 

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

calls to explain the spreadsheets and receive initial comments from the agencies. 

Collected Comments from S/L Agencies 

Conference calls were held with each S/L agency 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 comments received during these calls were 

summarized. After the calls, and until April 18, ERG 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 PRP18 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 transition the WRAP 2018b base case emissions 

inventory into the WRAP PRP18 emissions inventory are described below. 

Addressed S/L Agency Comments

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

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

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

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

removed inactive sources). 

 

7

 “2018 SO2 Emissions Evaluation for Non-Utility Sources”, Pechan, October 2006.

http://www.wrapair.org/forums/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 inventory, and thus the WRAP 2018 version 1 

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

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

contractor) was requested to use NOx and SO2 emissions data for subject EGUs from the U.S. 

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

S/L agencies for those EGUs reporting to CAMD. When these NOx and SO2 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 NOx and SO2

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% difference 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 

NOx and SO2 emission records for non-CAMD units operating at facilities with CAMD units 

being deleted, causing non-CAMD EGU emissions to be underreported in the 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 originally submitted to the NEI, and (2) to replace the dropped NOx

and SO2 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 estimates out to 2025; the most current projections 

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

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

and revised generation projections are shown in Table 1. 

The revised analysis of future electricity generation 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

 “SOx and NOx Emissions Data from Electricity Generating Units (EGUs): Issues related to the substitution of 

state/local/tribal (S/L/T) data in the 2002 National Emissions 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) 

Californiaa 77.76 83.17 

Northwest Power Poolb 88.37 106.05 

Rocky Mountain Power Areac 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 Generation 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 Construction 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 estimated with the original analysis. The state-level 

allocation of the future coal-fired EGUs in the original analysis was 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 were assigned to ND; the ND and SD generation 

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

different electricity market module region and lignite coal is preferentially 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 analysis; the newly identified permitted facilities 

located in ND (i.e., Gascoyne #1 and #2, South Heart, 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. Therefore, 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 moratorium on the construction of coal-fired EGUs 

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

future coal-fired EGU assigned to Idaho should 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 “replace” 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 number of allocated future coal-fired EGUs were 

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

to two in the PRP18 analysis. 

The state-level allocations are presented in Table 4. WRAP staff 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 projections 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 facilities 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 are included in Table 3, but not in Table 5. 

Conversely, Otter Tail and Neil Simpson #2 are included 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), but their permitted emission 

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

emission rates were not obtained during the development 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 Allocation of Future Placeholder Coal-Fired EGUs 

Required to Match Total Electricity Demand 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 NOx SO2 VOC CO PM10

Springerville #3 AZ 0.090 0.090 0.055a

Springerville #4 AZ 0.054 0.077 0.055a

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 Montana 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 0.200a 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., 

PM10 at Springerville #3 and #4 and SO2 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 NOx SO2 VOC CO PM10

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 projections 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 SO2/MMBtu was 

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

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

WRAP’s latest WRAP BART Clearinghouse.12 The methodology used to estimate the annual 

SO2 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 

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

NOx (tpy) SO2 (tpy) NOx (tpy) SO2 (tpy) NOx (tpy) SO2 (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 Unit 1 3,090 1,858 2,317 1,856 -773 -2 

Public Service – Comanche Unit 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 Unit 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 Presumptive BART Limits for Subject and 

Eligible Coal-Fired EGUs 

Facility Name and Unit 

2018b Base 

Case 

(tons SO2)

a

Presumptive 

BART - Rate 

(lb/MMBtu) 

2018 Heat 

Input 

(MMBtu) 

Presumptive 

BARTAnnual (tons 

SO2) 

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

Change in AK Due to Presumptive BART -226 tons SO2

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 SO2

Montana 

Colstrip Steam Electric Station – Unit 1b 5,517 0.15 29,843,850 2,238 

Colstrip Steam Electric Station – Unit 2b 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 SO2

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 Presumptive BART -3,247 tons SO2

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 SO2

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 0.22c 19,819,756 2,180 

Pacificorp – Dave Johnston – Unit 4 4,250 0.15c 30,030,412 2,252 

Pacificorp – Jim Bridger – Unit 1 7,069 0.15c 45,621,694 3,422 

Pacificorp – Jim Bridger – Unit 2 6,906 0.15c 43,634,528 3,273 

Pacificorp – Jim Bridger – Unit 3 6,537 0.15c 46,238,491 3,468 

Pacificorp – Jim Bridger – Unit 4 4,107 0.15c 45,075,468 3,381 

Pacificorp – Naughton Power Plant – Unit 1 6,518 0.41c 12,813,313 2,627 

Pacificorp – Naughton Power Plant – Unit 2 8,694 0.41c 16,715,747 3,427 

Pacificorp – Naughton Power Plant – Unit 3 5,980 0.21c 28,425,577 2,985 

Pacificorp – Wyodak – Unit 1 8,281 0.32c 35,685,720 5,710 

Change in WY Due to Presumptive BART -35,522 tons SO2

U.S. EPA Sources on Navajo Tribal Land located in New Mexico 

Four Corners Power Plant – Unit 1 1,385 0.21d 14,846,431 1,559 

Four Corners Power Plant – Unit 2 1,687 0.21d 16,632,804 1,746 

Four Corners Power Plant – Unit 3 2,122 0.21d 19,873,582 2,087 

Four Corners Power Plant – Unit 4 8,509 0.21d 57,929,739 6,083 

Four Corners Power Plant – Unit 5 9,729 0.21d 56,778,871 5,962 

Change on Navajo Tribal Land Due to SO2

Control Levels Proposed by U.S. EPA -5,995 tons SO2
Technical Memorandum – Final, Revised June 18, 2007 

 Page 11 

Table 8. Continued 

Facility Name and Unit 

2018b Base 

Case 

(tons SO2)

a

Presumptive 

BART - Rate 

(lb/MMBtu) 

2018 Heat 

Input 

(MMBtu) 

Presumptive 

BARTAnnual (tons 

SO2) 

Overall Total Change Due to Presumptive 

BART -77,560 tons SO2

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 SO2/MMBtu was calculated using 2006 heat input 

[MMBtu] and 2006 mass emissions [tons of SO2]). Therefore no presumptive BART reductions 

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

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

baghouses and absorbers for SO2 control; therefore no additional reductions are expected as a 

result of BART implementation. PRP18 emissions 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 SO2/MMBtu. 2018b emissions were retained for PRP18. 

● Reid Gardner (NV) Units 1-3, operate below BART levels (i.e., 0.03 to 0.04 lb SO2/MMBtu). 

2018b emissions were retained for PRP18. 

● Mohave Power Plant (NV) Units 1-2, are permitted at 0.15 lb SO2/MMBtu. 2018b emissions 

were retained for PRP18. 

● TransAlta Centralia Units (WA) BW21 and BW22, operate below BART levels (i.e., 0.04 

and 0.05 lb SO2/MMBtu). PRP18 emissions were calculated based on projected 2018 heat 

input and current lb SO2/MMBtu emission rates. 

Incorporated ENVIRON Revisions for Oil and Gas Point and Area Sources

Under a separate contract, ENVIRON revised 2018 estimates of SO2 emissions from selected oil and 

gas (O&G) point sources and all pollutants (NOx, SO2, VOC, CO) for O&G area sources in the 

WRAP region.14 ERG incorporated these revised 2018 O&G emissions 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 SO2 from Sources in §309 States

A study was conducted for the WRAP SSJF in 2006 by Pechan to update the 2018 SO2 emission 

projections (originally estimated by ERG and ENVIRON) for purposes of establishing SO2

milestones for the 309 State Regional Haze State Implementation Plans.15 The focus of that project 

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

emitting more than 100 tons of SO2 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 project resulted in revised 2018 SO2 emissions from these industries: 

copper smelters, lime manufacturing, pulp and paper, oil and gas, chemical manufacturing, 

petroleum refining, and cement production. 

For the WRAP PRP18 inventory, ERG summarized the 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 report (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 Smelter and Mill (AZ): the 2018 SO2 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). The correct value of 23,000 tons was confirmed by Arizona DEQ. 

● Phelps Dodge-Miami Smelter (AZ): the 2018 SO2 emissions were changed to 10,368 tons 

(not 10,000 as in the Pechan report) based 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 resulting draft WRAP PRP18 

emissions inventory, at the state/tribal level. 

WRAP PRP18 Results (Final) – Detailed Tables 

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

2018b base case emissions, the net changes made during 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 WRAP 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 SO2 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 Paula Fields, ERG, February 27, 2007. 
Technical Memorandum – Final, Revised June 18, 2007 

 Page 13 

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

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

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

2002 Emission Inventory Changes 

Although the focus of this project was on the most significant sources 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 during a future emissions inventory update). The 2002 

changes that were made fell into these categories: 

● Added missing non-CAMD emissions (see “Corrected CAMD EGU Facility 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 status 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 PM10 and PM2.5 records for 6 facilities in Nevada. These were also projected to 

2018 and added to the PRP18 emissions inventory. 

● Added new SO2 and NOx records for 1 refinery in Wyoming. 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 outstanding issues that were identified during the project but have 

been deferred until the next inventory update.

Next Steps 

In conjunction with this memo, ERG prepared the final PRP18 emissions 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 (which 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 regional 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 conducted in conjunction with a final Reasonable Progress 2018 (FRP18) 

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

correcting inventory errors that affect the Reasonable Progress 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 identified). The associated FRP18 analysis will be 

completed when the 13 contiguous WRAP states and 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 those analyses. These final analyses for regional haze 

planning in the West will conducted simultaneously. 
Table 9. Summary of 2018b Base Case Emissions Inventory, Net Changes Made by State and 

PRP18 Emissions Inventory – Point Sources (Tons per Year) 

State NOx SO2 VOC CO PM10 PM2.5 

WRAP 2018b Base Case Emissions Inventory (TPY): 

AK 67,959.43 7,781.59 6,637.31 25,881.08 2,884.91 3

AZ 77,738.22 94,407.68 9,466.23 33,242.90 9,893.22 1,6

CA 109,514.89 49,631.75 54,631.70 123,795.15 33,191.68 19,4CO 112,239.70 69,213.14 98,629.89 58,211.27 28,697.25 3

ID 14,048.16 25,467.31 3,060.02 38,019.05 1,741.19 6

MT 62,583.10 45,321.07 10,445.96 62,353.62 11,266.02 6

ND 92,097.99 162,704.76 2,493.21 22,589.46 4,369.38 3,0

NM 74,874.05 41,392.29 26,187.38 57,506.25 3,391.82 1,7

NV 69,016.45 24,040.65 4,112.87 20,745.67 6,200.35 1,5

OR 31,760.79 21,686.48 41,168.92 53,654.91 13,517.81 16,6

SD 24,725.86 15,268.20 3,522.79 6,858.87 1,044.86 2

UT 96,974.44 52,952.88 13,599.53 98,373.32 18,381.76 5,8

WA 49,396.97 51,355.44 28,013.12 187,705.34 12,096.19 4,6WY 132,115.76 145,099.58 27,541.60 60,503.77 42,819.39 19,4

Tribal 92,580.06 32,894.77 2,864.32 12,987.96 7,748.84 3,2

Net Changes to 2018b Base Case Emissions Inventory (TPY): 

AK -226.34 -1,118.54 

AZ -4,666.91 -24,070.72 211.84 796.24 984.32 

CA CO 1,120.93 -12,234.64 -21,100.97 5,782.57 -401.45 -2

ID -1,675.35 -15,522.06 -41.37 -2,792.25 -335.07 

MT -217.91 -8,840.88 55.17 1,000.74 -131.79 -2

ND -21,041.97 -95,626.23 1.79 -1,593.89 1,020.96 -2

NM -273.61 -9,011.88 -0.04 -130.31 -74.46 

NV -1,391.45 4,126.30 -247.12 6,968.94 -164.13 1,0

OR -6,813.49 -13,734.49 -530.41 -3,502.51 -433.54 -15,3

SD 1.00 -9,433.88 0.00 

UT -17,213.16 -15,014.36 -406.18 -1,920.34 -2,903.88 -1,3

WA 59.34 -13,911.46 -1,801.03 -80,108.37 -2,370.47 -2WY 1,099.95 -49,955.64 728.59 4,278.61 19.80 -3

Tribal 7,922.92 -4,495.17 317.51 572.15 1,293.29 5
Table 9. Continued 

State NOx SO2 VOC CO PM10 PM2.5 

WRAP PRP18 Emissions Inventory (TPY): 

AK 67,959.43 7,555.25 6,637.31 25,881.08 1,766.37 3

AZ 73,071.31 70,336.96 9,678.07 34,039.14 10,877.54 1,6

CA 109,514.89 49,631.75 54,631.70 123,795.15 33,191.68 19,4CO 113,360.63 56,978.50 77,528.92 63,993.84 28,295.80 

ID 12,372.81 9,945.25 3,018.65 35,226.80 1,406.12 5

MT 62,365.19 36,480.19 10,501.13 63,354.36 11,134.23 4

ND 71,056.02 67,078.53 2,495.01 20,995.57 5,390.34 2,7

NM 74,600.43 32,380.40 26,187.34 57,375.95 3,317.36 1,6

NV 67,625.00 28,166.95 3,865.76 27,714.61 6,036.22 2,5

OR 24,947.30 7,951.99 40,638.51 50,152.40 13,084.26 1,2

SD 24,726.86 5,834.32 3,522.79 6,858.87 1,044.86 2

UT 79,761.28 37,938.52 13,193.35 96,452.98 15,477.88 4,5

WA 49,456.32 37,443.99 26,212.09 107,596.98 9,725.72 4,3WY 133,215.71 95,143.95 28,270.19 64,782.38 42,839.19 19,1

Tribal 100,502.99 28,399.61 3,181.83 13,560.10 9,042.14 3,7
Table 10. Summary of 2018b Base Case Emissions Inventory, Net Changes Made by State and 

PRP18 Emissions Inventory – Area Sources (Tons per Year) 

State NOx SO2 VOC CO PM10 PM2

WRAP 2018b Base Case Emissions Inventory 

AK 9,293.35 6,043.71 16,539.14 29,055.82 21,531.05 6

AZ 12,558.62 3,410.26 171,414.85 70,097.25 137,883.20 39

CA 117,716.62 9,772.22 357,745.55 384,966.70 190,987.09 84CO 44,040.52 7,498.70 173,092.43 94,594.76 185,238.34 48

ID 42,067.89 2,720.52 194,210.06 40,971.48 62,880.57 7

MT 36,052.99 3,432.14 67,476.71 41,415.20 173,892.25 40

ND 21,128.65 5,856.27 82,650.71 21,606.83 311,272.53 64

NM 172,318.92 15,753.24 399,205.01 47,997.02 144,289.23 34

NV 7,487.60 14,194.42 47,609.85 17,479.33 97,755.67 23

OR 17,027.19 8,421.88 334,872.12 380,523.74 225,924.68 81

SD 7,206.93 11,667.18 50,072.09 25,112.44 226,750.11 48

UT 21,635.69 3,586.90 173,344.04 45,962.17 34,279.28 5

WA 22,745.95 8,667.27 253,709.83 252,446.63 348,329.35 113WY 79,196.38 23,109.16 436,884.86 34,463.27 45,027.21 12

Tribal 6,639.04 2.08 18,240.28 563.99 2,062.46 

Net Changes to 2018b Base Case Emissions Inventory 

AK -115.65 -0.11 -79.74 -0.42 

AZ 240.28 -2.06 -457.15 7,867.05 -1,122.80 

CA CO 5,808.28 2.10 6,581.27 4,673.24 

ID 332.78 

MT -16,649.19 -1.64 6,553.79 -98.40 

ND 12,191.55 1.33 4,915.99 39.17 

NM -63,903.42 -4.84 -60,801.51 37,955.98 -2,689.03 

NV -9.20 0.08 5,570.15 -1.23 

OR -3.99 -5.32 0.06 

SD -2,203.33 -7,582.58 166.01 -1,025.64 -2,674.01 

UT -5,700.69 -4.10 -13,395.34 -6.57 

WA WY -25,390.88 -12.16 -99,885.56 4,553.73 

Tribal 
Table 10. Continued 

State NOx SO2 VOC CO PM10 PM2

WRAP PRP18 Emissions Inventory 

AK 9,177.70 6,043.60 16,459.40 29,055.40 21,531.10 6

AZ 12,798.90 3,408.20 170,957.70 77,964.30 136,760.40 39

CA 117,716.62 9,772.22 357,745.55 384,966.70 190,987.09 84CO 49,848.80 7,500.80 179,673.70 99,268.00 185,238.30 48

ID 42,067.90 3,053.30 194,210.10 40,971.50 62,880.60 7

MT 19,403.80 3,430.50 74,030.50 41,316.80 173,892.30 40

ND 33,320.20 5,857.60 87,566.70 21,646.00 311,272.50 64

NM 108,415.50 15,748.40 338,403.50 85,953.00 141,600.20 33

NV 7,478.40 14,194.50 53,180.00 17,478.10 97,755.70 23

OR 17,023.20 8,421.90 334,866.80 380,523.80 225,924.70 81

SD 5,003.60 4,084.60 50,238.10 24,086.80 224,076.10 48

UT 15,935.00 3,582.80 159,948.70 45,955.60 34,279.30 5

WA 22,745.95 8,667.27 253,709.83 252,446.63 348,329.35 113WY 53,805.50 23,097.00 336,999.30 39,017.00 45,027.20 12

Tribal 6,639.04 2.08 18,240.28 563.99 2,062.46 
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 agencies. 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 NOx and SO2 records for non-CAMD units operating 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 changes to the number and location of future 

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

Navajo Tribal Lands. Also, emission rates for NOx, SO2, 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 SO2 for coal-fired EGUs in Alaska, Arizona, 

Montana, New Mexico, South Dakota, Wyoming, 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 SO2 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 SO2 emitters (i.e., >100 TPY) as a result of an 

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

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

http://www.wrapair.org/forums/ssjf/documents/eictts/projections.html
A1-1 

Alaska – Point Sources 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release 

Point ID NOX SO2 VOC CO 

WRAP 2018-18b Emissions Inventory (TPY) All 67,959.4 7,781.6 6,637.3 25,881.1 Net Changes to 2018-18b Emissions Inventory (TPY) 

2068 229000003 US Air Force - Clear Air Force Station 1 1A 10100224 1 2068 229000003 US Air Force - Clear Air Force Station 2 2A 10100224 2 2068 229000003 US Air Force - Clear Air Force Station 3 3A 10100224 3 2090 209000001 Eielson Air Force Base 1 1A 10100224 1 2090 209000001 Eielson Air Force Base 2 2A 10100224 2 2090 209000001 Eielson Air Force Base 3 3A 10100224 3 2090 209000001 Eielson Air Force Base 4 4A 10100224 4 2090 209000001 Eielson Air Force Base 5 5A 10100224 5 2090 209000001 Eielson Air Force Base 6 6A 10100224 6 2090 20900004 US Army Fort Wainwright 3 3A 10100224 3 2090 20900004 US Army Fort Wainwright 4 4A 10100224 4 2090 20900004 US Army Fort Wainwright 5 5A 10100224 5 2090 20900004 US Army Fort Wainwright 6 6A 10100224 6 2090 20900002 Aurora Energy 3 3A 10100224 3 2090 20900002 Aurora Energy 4 4A 10100225 4 2090 20900002 Aurora Energy 5 5A 10100225 5 2090 20900002 Aurora Energy 6 6A 10100224 6 2090 0229000002 GVEA Healy Power Plant 1 1A 1 -226.3 

WRAP 2018 PRP Emissions Inventory (TPY) All 67,959.4 7,555.3 6,637.3 25,881.1 
A1-2 

Arizona – Point Sources 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release Point ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 77,738.2 94,407.7 9,466Net Changes to 2018-18b Emissions Inventory (TPY): 04001 0400100059 SALT RIVER PROJECT 15.6 04001 040013222 TUCSON ELECTRIC POWER CO-SPRINGERVILLE -2,322.1 -2,405.6 304001 040014477 CORONADO GENERATING STATION -9,010.5 04001 PRJEGU03 Future Coal EGU (A) -335.1 -223.4 004003 0400300037 AZ ELECTRIC POWER COOPERATIVE INC 145.5 0.4 04003 040032148 DOUGLAS LIME PLANT 979.8 04003 040033532 AZ ELECTRIC POWER COOPERATIVE INC -433.0 04003 PRJEGU04 Future Coal EGU (B) -335.1 -223.4 004007 0400701391 PHELPS DODGE - MIAMI SMELTER 2,356.8 04013 3316 SRP AGUA FRIA GENERATING STATION 138.7 0.4 04013 3317 KYRENE GENERATING STATION 2.0 0.3 04017 040171807 SNOWFLAKE PULP MILL -62.5 04017 0401734839 Snowflake White Mountain Power 240.0 225.0 2204017 04017447 CHOLLA POWER PLANT -2,570.8 -11,492.5 04019 040192869 ARIZONA PORTLAND CEMENT COMPANY 128.0 04019 EGU0047 IRVINGTON GENERATING STATION -4,369.4 04021 V20621 000 Cactus Waste Systems (landfill) 1204025 040252393 PHOENIX CEMENT -83.6 04025 040255992 NELSON LIME PLANT 291.1 04027 Arizona Clean Fuels Refinery 395.5 250.7 175Deleted Records -25.6 -15.0 -1WRAP 2018 PRP Emissions Inventory (TPY): All 73,071.3 70,337.0 9,678
A1-3 

California – Point Sources 

State County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC

Emission 

Release 

Point ID NOX SO2 VOC CO PM

WRAP 2018b Base Case Emissions Inventory (TPY) All 109,514.9 49,631.8 54,631.7 123,795.2 33,1Net Changes to 2018b Base Case Emissions Inventory (TPY) No Changes WRAP PRP18 Emissions Inventory (TPY) All 109,514.9 49,631.8 54,631.7 123,795.2 33,1
A1-4 

Colorado – Point Sources 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release 

Point ID NOX SO2 V

WRAP 2018-18b Emissions Inventory (TPY): All 112,239.7 69,213.1 98Net Changes to 2018-18b Emissions Inventory (TPY): All 40400311 -2108041 0030 COLORADO SPRINGS UTILITIES - NIXON PLT 1 222 10100222 222 -84.6 -700.8 08041 0030 COLORADO SPRINGS UTILITIES - NIXON PLT 002 01 10100501 002 5.5 1.8 08041 0004 COLORADO SPRINGS UTILITIES-DRAKE PLT 6 222 10100222 222 -148.9 -2,433.4 08041 0004 COLORADO SPRINGS UTILITIES-DRAKE PLT 5 222 10100222 222 -85.9 -116.9 08041 0004 COLORADO SPRINGS UTILITIES-DRAKE PLT 7 222 10100222 222 493.8 -3,050.3 08099 PRJEGU07 Future Coal EGU (A) #1 01 10100201 01 -335.1 -223.4 08121 Future Coal EGU (Akron/ AES Power) #1 01 10100201 01 1,667.9 2,382.7 08087 PRJEGU06 Future Coal EGU (B) #1 01 10100201 01 -335.1 -223.4 08087 Future Coal EGU (Ft. Morgan/ LS Power) #1 01 10100201 01 1,563.7 1,742.4 08031 0008 PUBLIC SERVICE CO - ARAPAHOE 019 01 20100101 019 12.4 0.6 08031 0008 PUBLIC SERVICE CO - ARAPAHOE 018 01 20100102 018 6.3 0.1 08031 0008 PUBLIC SERVICE CO - ARAPAHOE 012 01 20100102 012 3.4 0.2 08031 0008 PUBLIC SERVICE CO - ARAPAHOE 014 01 20100201 014 39.0 0.6 08013 0001 PUBLIC SERVICE CO - VALMONT 5 226 10100226 226 88.7 170.3 08013 0001 PUBLIC SERVICE CO - VALMONT 003 01 10200602 003 3.5 0.0 08013 0001 PUBLIC SERVICE CO - VALMONT 013 01 20100201 013 39.0 0.3 08013 0001 PUBLIC SERVICE CO - VALMONT 002 01 20100201 002 12.1 0.4 08077 0002 PUBLIC SERVICE CO CAMEO PLT 001 01 10100222 001 657.4 964.1 08001 0001 PUBLIC SERVICE CO CHEROKEE PLT 4 226 10100226 226 482.7 293.4 08001 0001 PUBLIC SERVICE CO CHEROKEE PLT 006 01 20100102 006 4.1 0.6 08001 0001 PUBLIC SERVICE CO CHEROKEE PLT 017 01 20100102 017 3.6 0.6 08101 0003 PUBLIC SERVICE CO COMANCHE PLT #3 Fut 1 10100201 01 -366.2 -457.8 08101 0003 PUBLIC SERVICE CO COMANCHE PLT 2 222 10100222 222 -466.1 2.0 08101 0003 PUBLIC SERVICE CO COMANCHE PLT 1 226 10100226 226 -772.9 -1.7 08123 0023 PUBLIC SERVICE CO FORT SAINT VRAIN PLT 001 02 10100602 001 16.0 0.1 08107 0001 PUBLIC SERVICE CO HAYDEN PLT H1 222 10100222 222 -263.7 31.2 08107 0001 PUBLIC SERVICE CO HAYDEN PLT H2 226 10100226 226 -530.4 102.8 08087 0011 PUBLIC SERVICE CO PAWNEE PLT 1 222 10100222 222 -957.7 -11,475.5 08087 0011 PUBLIC SERVICE CO PAWNEE PLT 002 02 10200601 002 0.1 0.0 08081 0018 TRI STATE GENERATION CRAIG C2 222 10100222 222 -317.9 -839.9 08081 0018 TRI STATE GENERATION CRAIG C1 222 10100222 222 741.4 408.8 08085 0001 TRI STATE GENERATION NUCLA 009 01 10101002 009 0.0 
A1-5 

Colorado – Point Sources Continued 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release 

Point ID NOX SO2 V

08059 0820 

TRIGEN - COLORADO ENERGY CORPORATION 4 2 10200222 4 43.9 281.1 

08059 0820 

TRIGEN - COLORADO ENERGY CORPORATION 5 2 10200222 6 -98.9 904.3 

08049 0006 

CLIMAX MOLYBDENUM AMAX HENDERSON MILL ALL 

Deleted Records WRAP 2018 PRP Emissions Inventory (TPY): All 113,360.6 56,978.5 77
A1-6 

Idaho – Point Sources 

State County 

FIPS 

Facility 

ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release Point 

ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 14,048.2 25,467.3 3,060.0 3Net Changes to 2018-18b Emissions Inventory (TPY): 16029 02900001 P4 Production LLC 10 1 30111299 10 -14,169.9 16051 05100017 Idaho Fresh Pak, Lewisville 10 2 10200501 10 119.9 16011 01100013 Idaho Supreme Potatoes 10 2 10200401 10 203.3 Deleted Records -1,675.4 -1,675.4 -41.4 WRAP 2018 PRP Emissions Inventory (TPY): All 12,372.8 9,945.2 3,018.7 3
A1-7 

Montana – Point Sources 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release 

Point ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 62,583.1 45,321.1 10,446.0 6Net Changes to 2018-18b Emissions Inventory (TPY): 30087 087-0008 COLSTRIP STEAM ELECTRIC STATION 1 226 10100226 226 -2,557.0 30087 087-0008 COLSTRIP STEAM ELECTRIC STATION 1 801 10100801 801 -721.2 30087 087-0008 COLSTRIP STEAM ELECTRIC STATION 2 226 10100226 226 -2,804.0 30087 087-0008 COLSTRIP STEAM ELECTRIC STATION 2 801 10100801 801 -640.2 30087 087-0008 COLSTRIP STEAM ELECTRIC STATION 8 1 20100107 1.0 30111 111-0015 PPL MONTANA - JE CORETTE PLANT 2 226 10100226 226 -2,596.5 30013 PRJEGU10 Future Coal EGU (A) #1 1 10100201 1 -335.1 -223.4 0.0 30065 PRJEGU11 

Future Coal EGU (Bull Mountain - Roundup Plant) #1 1 10100201 1 -1,496.6 -1,061.1 -18.5 -

30065 PRJEGU11 

Future Coal EGU (Bull Mountain - Roundup Plant) #2 1 10100201 1 1,016.4 1,452.0 43.6 

30003 PRJEGU09 

Future Coal EGU (Rocky Mountain Power - Hardin Generating Station) #1 1 10100201 1 -107.2 -71.5 0.0 

30013 

Future Coal EGU (Highwood/ Southern Montana Electric) #1 1 10100201 1 703.6 382.0 30.2 

WRAP 2018 PRP Emissions Inventory (TPY): All 62,365.2 36,480.2 10,501.1 6
A1-8 

Nevada – Point Sources 

State County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release 

Point ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 69,016.5 24,040.6 4,112Net Changes to 2018-18b Emissions Inventory (TPY): 32001 AP49110197 

AMOR IV CORP & STILLWATER GEOTHERMAL 1071 1135 20101001 1135 -165

32001 AP49110464 AMOR IX CORPORATION 1844 1997 20101001 1997 -8132001 AP49110464 AMOR IX CORPORATION 1847 2000 20101001 2000 -9732003 AP49110399 Nevada Power Sunrise Station 103006 32003 AP49110400 

NEVADA POWER COMPANY- Reid Gardner Generating Station 101002 

32003 AP49110466 So Cal Edison - Mohave 1848 2001 10100212 2001 1032003 AP49110466 So Cal Edison - Mohave 1849 2002 10100212 2002 1232003 AP49110466 So Cal Edison - Mohave 1850 2003 10100212 2003 0.6 0.0 032003 AP49110466 So Cal Edison - Mohave 1851 2004 10100212 2004 1.1 0.0 032003 AP49110466 So Cal Edison - Mohave 10100212 32011 PRJEGU15 

Future Coal EGU (Newmont - Northern Nevada Energy) #1 01 10100201 01 -171.3 0

32019 AP32410387 NEVADA CEMENT COMPANY 1534 1629 30501109 1629 -5.5 32019 AP32410387 NEVADA CEMENT COMPANY 1537 1632 30501109 1632 -1,791.6 32019 AP32410387 NEVADA CEMENT COMPANY 1540 1635 30501109 1635 -3.7 32019 AP32410387 NEVADA CEMENT COMPANY 1543 1638 30501109 1638 -891.5 32033 

Future Coal EGU (White Pine Energy Association/ LS Power) #1 01 10100201 01 3,909.2 4,355.9 124

32033 PRJEGU16 Future Coal EGU (A) #1 01 10100201 01 -335.1 -223.4 032003 423 Nevada Sun Peak Partnerships* 78.8 0.1 132019 AP49110091 

Sierra Pacific Company - Ft Churchill Power Station* 

32019 AP32410387 Nevada Cement Company* 32029 AP49110194 

Sierra Pacific Company - Tracy Generating Station* 

Deleted Records -2,182.5 -6.4 -51WRAP 2018 PRP Emissions Inventory (TPY): All 67,625.0 28,166.9 3,865* These records (complete facilities or certain units only) earlier had missing FIPS codes and so were not included in the state totals in 2018
A1-9 

New Mexico – Point Sources 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC

Emission 

Release 

Point ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 74,874.0 41,392.3 26,187.4 57Net Changes to 2018-18b Emissions Inventory (TPY): 35001 00008 Rio Grande Portland Cement 409.2 35001 00011 

Public Service Company of New Mexico Reeves Generating Station 0.1 0.0 

35015 350150008 Indian Basin Gas Plant -1,662.4 35015 350150010 Artesia Refinery 11.2 35015 350150011 Artesia Gas Plant -1,115.7 35015 350150285 Dagger Draw Gas Plant 18.0 35025 350250004 Maljamar Gas Plant 200.1 35025 350250007 Denton Plant -104.4 35025 350250008 Jal No. 3 -401.5 35025 350250034 Maddox Station 51.3 0.0 35025 350250035 Linam Ranch Gas Plant -1,230.2 35025 350250044 Eunice Gas Plant -1,745.4 35025 350250054 Cunningham Station 0.4 0.0 35025 350250060 Eunice Gas Plant 25.0 35025 350250061 Monument Plant 298.4 35025 350250063 Saunders Plant 38.3 35031 350310008 Ciniza Refinery -292.8 35031 350310032 Escalante Station 7.1 0.0 35031 PRJEGU18 Future Coal EGU (A) -335.1 -223.4 0.0 35045 350450023 San Juan Refinery (Bloomfield) 34.8 35045 350450247 San Juan River Gas Plant -24.9 35045 350450902 San Juan Generating Station 2.6 -3,246.5 WRAP 2018 PRP Emissions Inventory (TPY): All 74,600.4 32,380.4 26,187.3 57
A1-10 

North Dakota – Point Sources 

State County 

FIPS 

Facility 

ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release 

Point ID NOX SO2 VO

WRAP 2018-18b Emissions Inventory (TPY): All 92,098.0 162,704.8 2,49Net Changes to 2018-18b Emissions Inventory (TPY): 38053 16 Grasslands Plant 300.0 38055 126 Coal Creek Station -2,738.2 -19,941.5 38057 13 Antelope Valley Station 38057 289 Coyote 38057 65 Great Plains Synfuel Plant 38057 12 Leland Olds Station -4,796.6 -44,070.4 38057 125 Stanton Station -381.0 -5,117.2 38059 226 Mandan Refinery 38059 172 RM Heskett Station - Mandan -86.7 -1,094.0 38065 165 M R Young Station -13,153.4 -21,925.3 38105 270 Tioga Gas Plant 981.7 -981.7 38093 Future Coal EGU (Great River Energy) 221.1 147.4 38011 Future Coal EGU (Gascoyne/Montana Dakota Utility) 2,261.7 1,364.5 738089 Future Coal EGU (South Heart/Great Northern Power) 1,675.4 726.0 4Deleted Records -5,026.1 -5,034.0 -12WRAP 2018 PRP Emissions Inventory (TPY): All 71,056.0 67,078.5 2,49
A1-11 

Oregon – Point Sources 

State County 

FIPS 

Facility 

ID Facility Name 

Emission Unit 

ID 

Process 

ID SCC

Emission Release 

Point ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 31,760.8 21,686.5 41,168.9 Net Changes to 2018-18b Emissions Inventory (TPY): 41001 00038 Northwest Pipeline Corporation 41003 02298 Oregon State University 41005 01850 Blue Heron Paper Company 41005 02145 West Linn Paper Company 319.6 41007 00004 Fort James Operating Company -559.3 41009 01849 Boise Cascade Corporation -574.9 41029 00025 Timber Products Co. 41033 00030 U.S. Forest Industries, Inc. 41035 00093 Aqua Glass West, Inc. 41041 00005 Georgia-Pacific West, Inc. -162.8 41043 06024 Entek International LLC 41043 03501 Pope & Talbot, Inc. -46.8 41043 00547 Wah Chang 41043 00471 Weyerhaeuser Company -136.9 41049 00016 Portland General Electric Company -4,456.4 -11,678.4 41049 00031 Portland General Electric Company 2.8 2.8 41051 02025 Chevron Products Company 41051 03009 Dynea Overlays, Inc. 41051 02050 Oregon Health Sciences University 41051 01876 Owens-Brockway Glass Container Inc. 0.0 41059 30-0118 Hermiston Power Plant 79.9 23.7 19.6 41071 06142 Smurfit Newsprint Corporation -314.7 Deleted Records -2,439.8 -606.9 -550.0 WRAP 2018 PRP Emissions Inventory (TPY): All 24,947.3 7,952.0 40,638.5 
A1-12 

South Dakota – Point Sources 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release Point 

ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 24,725.9 15,268.2 3,522.8 Net Changes to 2018-18b Emissions Inventory (TPY): 46051 28.0801-29 Otter Tail Power Company 1 223 10100223 223 -9,436.8 46051 28.0801-29 Otter Tail Power Company 4 1 20100101 4 0.1 0.0 46051 28.0801-29 Otter Tail Power Company 3 1 10100501 3 0.0 0.1 0.1 46051 28.0801-29 Otter Tail Power Company 2 1 10100501 2 0.9 2.7 WRAP 2018 PRP Emissions Inventory (TPY): All 24,726.9 5,834.3 3,522.8 
A1-13 

Utah – Point Sources 

State County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC

Emission 

Release Point ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 96,974.4 52,952.9 13,599.5 98Net Changes to 2018-18b Emissions Inventory (TPY): 49007 10081 Carbon Power Plant 1.5 0.5 49011 10119 Salt Lake Refinery 35.5 49011 10122 Flying J Refinery (Big West Oil Co.) -82.5 49011 10123 Phillips Refinery 17.6 49015 10237 Hunter Power Plant -3,936.4 71.0 49015 10238 Huntington Power Plant -2,815.2 -12,403.5 49015 PRJEGU22 Future Coal EGU (A) -335.1 -223.4 -0.0 49027 10313 Cricket Mountain Plant 0.00 49027 10327 Intermountain Generation Station -705.1 16.9 49029 10007 Devil's Slide Plant -13.9 49035 10335 Salt Lake City Refinery -128.2 49035 10355 Gadsby Power Plant 0.5 0.0 49041 PRJEGU24 Future Coal EGU (NEVCO Energy Co.) 100.5 -683.5 -0.0 49047 PRJEGU25 Future Coal EGU (B) -335.1 -223.4 -0.0 Deleted Records -9,188.9 -1,380.6 -423.0 -1WRAP 2018 PRP Emissions Inventory (TPY): All 79,761.3 37,938.5 13,193.4 96
A1-14 

Washington – Point Sources 

State 

County 

FIPS 

Facility 

ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC

Emission 

Release 

Point ID NOX SO2 VOC C

WRAP 2018-18b Emissions Inventory (TPY): All 49,397.0 51,355.4 28,013.1 187,Net Changes to 2018-18b Emissions Inventory (TPY): 53007 0001 

ALUMINUM CO OF AMERICA WENATCHEE WORKS -40.8 -2,134.7 -7.3 -11,

53015 0015 LONGVIEW ALUMINUM, L.L.C. 1.0 53015 0144 Mint Farm Energy Center LLC 97.3 82.6 44.0 53039 0001 GOLDENDALE ALUMINUM -44.4 -305.5 -28.9 -12,53041 New Plant Cardinal FG 831.2 72.5 56.1 53041 0010 TransAlta Centralia Generation 8.6 -3,884.2 53073 0001 INTALCO ALUMINUM CORP FERNDALE -55.9 -3,339.9 -16.8 -24,Deleted Records -737.7 -4,402.3 -1,848.2 -32,WRAP 2018 PRP Emissions Inventory (TPY): All 49,456.3 37,444.0 26,212.1 107,
A1-15 

Wyoming - Point Sources 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC

Emission 

Release 

Point ID NOX SO2 VOC 

WRAP 2018-18b Emissions Inventory (TPY): All 132,115.8 145,099.6 27,541.6 6Net Changes to 2018-18b Emissions Inventory (TPY): 56001 5600100002 MOUNTAIN CEMENT CO -2.1 56003 5600300003 AMERICAN COLLOID CO_LOVELL 179.7 14.8 56005 5600500046 PACIFICORP_WYODAK -2,571.0 56005 5600500063 

BLACK HILLS CORPORATION_SIMPSON 2 1.9 

56005 Future Coal EGU (Dry Fork/ Basin Electric) 785.6 1,256.9 61.3 56005 PRJEGU28 Future Coal EGU (Wygen Station) 111.7 372.3 37.2 56005 PRJEGU29 Future Coal EGU (Two Elk) 1,928.5 2,752.0 214.0 56005 PRJEGU30 Future Coal EGU (A) -335.1 -223.4 -0.0 56007 5600700001 

SINCLAIR OIL CORP-SINCLAIR REFINERY -993.8 

56009 5600900001 PACIFICORP_DAVE JOHNSTON 4.7 -8,370.8 56013 5601300008 

DEVON SFS OPERATING_BEAVER CREEK -16.0 

56013 5601300028 

BURLINGTON RESOURCES_LOST CABIN -791.6 

56021 5602100001 FRONTIER REFINING, INC. -672.4 56023 5602300004 

PACIFICORP_NAUGHTON POWER PLANT -12,132.7 

56023 5602300013 EXXON SHUTE CREEK I -2,669.7 56025 5602500005 SINCLAIR REFINERY - CASPER -223.3 56029 5602900007 

MARATHON OIL CO _ OREGON BASIN GAS PLANT 200.4 

56029 5602900012 

HOWELL PET CORP_ELK BASIN GAS PLANT -324.7 

56031 5603100001 

BASIN ELECTRIC_LARAMIE RIVER STATION -1,350.7 

56035 00001 

EXXON -LABARGE DEHYDRATION FACILITY -696.5 

56037 5603700002 GENERAL CHEMICAL 209.3 56037 5603700008 UNION PAC_BRADY -41.2 56037 5603700022 Simplot Phosphates -758.8 56037 5603700048 

FMC CORP_GREEN RIVER PLANT_SODIUM PROD -57.0 

56037 5603701002 PACIFICORP_JIM BRIDGER 11.4 -11,069.7 
A1-16 

Wyoming - Point Sources Continued) 

State 

County 

FIPS Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC

Emission 

Release 

Point ID NOX SO2 VOC 

56037 PRJEGU32 Future Coal EGU (B) -335.1 -223.4 0.0 56041 5604100009 CHEVRON CARTER CREEK -715.9 56041 5604100012 BP AMERICA - WHITNEY CANYON -9,171.5 56043 5604300003 

HILAND PARTNERS, LLC_HILAND GAS PLANT -66.8 

56045 5604500001 

WYOMING REFINING CO_NEWCASTLE REFINERY 313.1 

56005 0083 

Western Gas Resources - Horse Creek/Gas Draw Compressor Stn.* 19.7 9.2 

56005 0120 

Western Gas Resources - Baker Springs/Butcher Compressor Stn.* 33.2 8.0 

56005 0134 

Western Gas Resources - Pronghorn/Oryn Compressor Stn.* 38.5 49.3 

56005 0137 

Western Gas Resources - Sioux/Jr. Reno Compressor Stn.* 29.7 1.3 

56035 0018 

Jonah Gas Gathering - Falcon Compressor Stn.* 126.6 143.5 

56035 0020 

Jonah Gas Gathering - Bird Canyon/Co. Line Compressor Stn.* 132.7 156.3 

56035 0034 

Jonah Gas Gathering - Luman Compressor Stn.* 95.2 178.2 

Deleted Records -1,727.0 -1,933.1 -129.5 -WRAP 2018 PRP Emissions Inventory (TPY): All 133,215.7 95,143.9 28,270.2 6* These records (complete facilities or certain units only) earlier had missing FIPS codes and so were not included in the state totals for the 
A1-17 

Tribal – Point Sources 

State 

County 

FIPS 

Tribal 

Code Facility ID Facility Name 

Emission 

Unit ID 

Process 

ID SCC 

Emission 

Release 

Point ID NOX SO2 

WRAP 2018-18b Emissions Inventory (TPY): All 92,580.1 32,894.8 2Net Changes to 2018-18b Emissions Inventory (TPY): 00000 687 10747 BONANZA POWER PLANT 7,850.7 1,265.1 00000 687 10766 Riverbend Field 55.6 0.3 00000 780 350450002 Four Corners Power Plant -5,994.6 00000 780 

Future Coal EGU (Desert Rock/Sithe Global Power) 3,315.6 3,315.6 

00000 281 00011 Devon Energy Riverton Dome Plant 51.7 269.1 Deleted Records -3,350.7 -3,350.7 WRAP 2018 PRP Emissions Inventory (TPY): All 100,503.0 28,399.6 3
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 agencies. 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 Mexico, Nevada, Oregon, South Dakota, Utah and 

Wyoming. See page 11 of this memo for more information. 
A2-1 

Alaska – Area Sources 

State SCC NOX SO2 VOC CO PM

WRAP 2018b Base Case Emissions Inventory (TPY): Alaska All 9,293.4 6,043.7 16,539.1 29,055.8 21,5Net Changes to 2018b Base Case Emissions Inventory (TPY): Alaska 2310000220- Oil and Gas Production: Drill rigs -114.1 -0.1 Alaska 2310021500- Oil and Gas Production: Natural Gas well completion – flaring and venting -1.6 -79.7 -0.4 WRAP PRP18 Emissions Inventory (TPY): Alaska 9,177.7 6,043.6 16,459.4 29,055.4 21,5
A2-2 

Arizona – Area Sources 

State SCC NOX SO2 VOC C

WRAP 2018b Base Case Emissions Inventory (TPY): Arizona All 12,558.6 3,410.3 171,414.9 70,0Net Changes to 2018b Base Case Emissions Inventory (TPY): Arizona 2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 0.2 0.0 Arizona 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing 16.0 

Arizona 2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices 3.6 Arizona 2310020600- Oil and Gas Production: Natural Gas Compressor engines 7.8 0.0 Arizona 2310021100- Oil and Gas Production: Natural Gas well heaters 7.4 0.0 Arizona 2310021300- Oil and Gas Production: Natural Gas well pneumatic devices 1.7 Arizona 2310021400- Oil and Gas Production: Natural Gas well dehydrators 10.6 Arizona 

2310030210- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing 16.9 

Arizona 2311000000- Construction: All Processes Arizona 2311000100- Construction: All Processes, Wind Erosion Arizona 2460100000- Consumer and Commercial- All Personal Care Products Total -229.5 Arizona 2460200000- Consumer and Commercial- All Household Products Total -102.0 Arizona 2460400000- Consumer and Commercial- All Automotive Aftermarket Products Total -35.3 Arizona 2460500000- Consumer and Commercial- All Coatings and Related Products Total -97.2 Arizona 2460600000- Consumer and Commercial- All Adhesives and Sealants Total: All Solvents -57.0 Arizona 2460800000- Consumer and Commercial- All FIFRA Related Products Total -179.6 Arizona 

2460900000- Consumer and Commercial Miscellaneous Products (Not Otherwise Covered) Total -7.2 

Arizona 2461800000- Commercial Pesticide Application: All Processes Total 602.1 Arizona 2465000000- Consumer Solvents- All Products/Processes Total -2.0 Arizona 2465100000- Consumer Solvents- Personal Care Products Total -125.7 Arizona 2465200000- Consumer Solvents- Household Products Total -137.1 Arizona 2465400000- Consumer Solvents- Automotive Aftermarket Products Total -315.7 Arizona 2465600000- Consumer Solvents- Adhesives and Sealants Total -302.6 Arizona 2465800000- Consumer Solvents- Pesticide Application Total 13.5 Arizona 2601000000- On-site Incineration All Categories Total -1.2 0.0 -0.0 Arizona 2610000100- Open Burning All Categories Yard Waste - Leaf Species Unspecified -3.4 Arizona 2610000400- Open Burning All Categories Yard Waste - Brush Species Unspecified -2.3 Arizona 2610000500- Open Burning All Categories Land Clearing Debris 241.8 561.1 8,1Arizona 2610030000- Open Burning Residential Household Waste -15.6 -2.1 -85.2 -2Arizona 2810050000- Other Combustion- Motor Vehicle Fires Total -0.1 -0.9 WRAP PRP18 Emissions Inventory (TPY): Arizona All 12,798.9 3,408.2 170,957.7 77,9
A2-3 

California – Area Sources 

State SCC NOX SO2 VOC CO PM10 

WRAP 2018b Base Case Emissions Inventory (TPY): California All 117,716.6 9,772.2 357,745.6 384,966.7 190,987Net Changes to 2018b Base Case Emissions Inventory (TPY):No Changes WRAP PRP18 Emissions Inventory (TPY): California All 117,716.6 9,772.2 357,745.6 384,966.7 190,987
A2-4 

Colorado – Area Sources 

State SCC NOX SO2 VOC CO PM10 

WRAP 2018b Base Case Emissions Inventory (TPY): Colorado All 44,040.5 7,498.7 173,092.4 94,594.8 185,238.3 Net Changes to 2018b Base Case Emissions Inventory (TPY): Colorado 2310000220- Oil and Gas Production: Drill rigs 361.6 2.1 154.8 996.0 Colorado 

2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 0.7 0.2 

Colorado 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing 63.5 

Colorado 

2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices 32.0 

Colorado 

2310020600- Oil and Gas Production: Natural Gas Compressor engines 4,005.8 1,485.4 3,412.2 

Colorado 

2310021100- Oil and Gas Production: Natural Gas well heaters 1,014.9 213.2 

Colorado 

2310021300- Oil and Gas Production: Natural Gas well pneumatic devices 231.7 

Colorado 

2310021400- Oil and Gas Production: Natural Gas well dehydrators 97.3 

Colorado 

2310021500- Oil and Gas Production: Natural Gas well completion - flaring and venting 208.7 4,233.1 51.6 

Colorado 

2310023000- Oil and Gas Production: Natural Gas CBM gas well - Dewatering pump engines 216.6 

Colorado 

2310030210- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing 283.5 

WRAP PRP18 Emissions Inventory (TPY): Colorado All 49,848.8 7,500.8 179,673.7 99,268.0 185,238.3 
A2-5 

Idaho – Area Sources 

State SCC NOX SO2 VOC CO PM

WRAP 2018b Base Case Emissions Inventory (TPY): Idaho All 42,067.9 2,720.5 194,210.1 40,971.5 62Net Changes to 2018b Base Case Emissions Inventory (TPY): Idaho 

2104004000- Residential Distillate Oil Combustion Total 332.8 

WRAP PRP18 Emissions Inventory (TPY): Idaho All 42,067.9 3,053.3 194,210.1 40,971.5 62
A2-6 

Montana – Area Sources 

State SCC NOX SO2 VOC CO 

WRAP 2018b Base Case Emissions Inventory (TPY): Montana All 36,053.0 3,432.1 67,476.7 41,415.2 Net Changes to 2018b Base Case Emissions Inventory (TPY): Montana 2310000220- Oil and Gas Production: Drill rigs -801.7 -1.6 10.3 5.9 Montana 

2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 69.30 13.9 

Montana 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks -flashing & standing/working/breathing 6,073.7 

Montana 

2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices 129.5 

Montana 

2310020600- Oil and Gas Production: Natural Gas Compressor engines -15,083.0 420.7 

Montana 2310021100- Oil and Gas Production: Natural Gas well heaters -684.3 -143.7 Montana 

2310021300- Oil and Gas Production: Natural Gas well pneumatic devices -156.2 

Montana 

2310021500- Oil and Gas Production: Natural Gas well completion - flaring and venting 131.9 86.5 33.0 

Montana 

2310030220- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing -0.6 

Deleted Records All -281.4 -0.0 -10.1 -7.5 WRAP PRP18 Emissions Inventory (TPY): Montana All 19,403.8 3,430.5 74,030.5 41,316.8 
A2-7 

Nevada – Area Sources 

State SCC NOX SO2 VOC CO 

WRAP 2018b Base Case Emissions Inventory (TPY): Nevada All 7,487.6 14,194.4 47,609.9 17,47Net Changes to 2018b Base Case Emissions Inventory (TPY): Nevada 2310000220- Oil and Gas Production: Drill rigs 4.3 0.1 Nevada 2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters -0.1 Nevada 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing -9.9 

Nevada 2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices 1.5 Nevada 2310020600- Oil and Gas Production: Natural Gas Compressor engines -8.3 Nevada 2310021100- Oil and Gas Production: Natural Gas well heaters -5.1 Nevada 2310021300- Oil and Gas Production: Natural Gas well pneumatic devices -1.2 Nevada 2310021400- Oil and Gas Production: Natural Gas well dehydrators -0.2 Nevada 2401002000- Surface Coating- Architectural Coatings - Solvent-based Total 1,949.1 Nevada 2401003000- Surface Coating- Architectural Coatings - Water-based Total 1,720.5 Nevada 2401015000- Surface Coating- Factory Finished Wood 530.0 Nevada 2401020000- Surface Coating- Wood Furniture 582.7 Nevada 2401040000- Surface Coating- Metal Cans -0.5 Nevada 2401050000- Surface Coating- Miscellaneous Finished Metals 195.5 Nevada 2401055000- Surface Coating- Machinery and Equipment 71.9 Nevada 2401060000- Surface Coating- Large Appliances 898.1 Nevada 2401065000- Surface Coating- Electronic and Other Electrical 76.4 Nevada 2401070000- Surface Coating- Motor Vehicles 11.4 Nevada 2401080000- Surface Coating- Marine 48.5 Nevada 2401085000- Surface Coating- Railroad 77.1 Nevada 2401090000- Surface Coating- Miscellaneous Manufacturing Total 870.7 Nevada 2401100000- Surface Coating- Industrial Maintenance Coatings Total 1,231.3 Nevada 2401200000- Surface Coating- Other Special Purpose Coatings Total 1,116.3 Nevada 2415005000- Degreasing- Furniture and Fixtures 251.2 Nevada 2415025000- Degreasing- Industrial Machinery and Equipment 0.2 Nevada 2415030000- Degreasing- Electronic and Other Elec. 26.9 Nevada 2415035000- Degreasing- Transportation Equipment 26.1 Nevada 2415040000- Degreasing- Instruments and Related Products 0.7 Nevada 2415045000- Degreasing- Miscellaneous Manufacturing 0.4 Nevada 2415230000- Degreasing- Electronic and Other Elec. 66.4 Nevada 2415245000- Degreasing- Miscellaneous Manufacturing 268.4 Nevada 2415345000- Degreasing- Miscellaneous Manufacturing 218.5 
A2-8 

Nevada – Area Sources Continued 

State SCC NOX SO2 VOC CO 

Nevada 2415360000- Degreasing- Auto Repair Services 3,457.6 Nevada 

2460110000- Consumer and Commercial Personal Care Products: Hair Care Products Total 772.3 

Nevada 

2460130000- Consumer and Commercial Personal Care Products: Fragrance Products Total 311.7 

Nevada 

2460150000- Consumer and Commercial Personal Care Products: Nail Care Products Total 24.5 

Nevada 

2460190000- Consumer and Commercial Personal Care Products: Miscellaneous Personal Care Products Total 96.5 

Nevada 

2460230000- Consumer and Commercial Household Products: Fabric and Carpet Care Products Total 34.4 

Nevada 

2460250000- Consumer and Commercial Household Products: Waxes and Polishes Total 127.4 

Nevada 

2460270000- Consumer and Commercial Household Products: Shoe and Leather Care Products Total 19.6 

Nevada 

2460290000- Consumer and Commercial Household Products: Miscellaneous Household Products Total 92.4 

Nevada 

2460410000- Consumer and Commercial Automotive Aftermarket Products: Detailing Products Total 151.6 

Nevada 

2460420000- Consumer and Commercial Automotive Aftermarket Products: Maintenance and Repair Products Total 506.9 

Nevada 

2460510000- Consumer and Commercial Coatings and Related Products: Aerosol Spray Paints Total 504.2 

Nevada 

2460520000- Consumer and Commercial Coatings and Related Products: Coating Related Products Total 31.5 

Nevada 2460610000- Consumer and Commercial Adhesives and Sealants: Adhesives Total 4.3 Nevada 2460810000- Consumer and Commercial FIFRA Related Products: Insecticides Total 524.2 Nevada 

2460820000- Consumer and Commercial FIFRA Related Products: Fungicides and Nematicides Total 2.0 

Nevada 

2460900000- Consumer and Commercial Miscellaneous Products (Not Otherwise Covered) Total 1,268.5 

Deleted Records All -12,587.5 WRAP PRP18 Emissions Inventory (TPY): Nevada All 7,478.4 14,194.5 53,180.0 17,4
A2-9 

New Mexico – Area Sources 

State SCC NOX SO2 VOC CO 

WRAP 2018b Base Case Emissions Inventory (TPY): New Mexico All 172,318.9 15,753.2 399,205.0 47,9Net Changes to 2018b Base Case Emissions Inventory (TPY): New Mexico 2310000220- Oil and Gas Production: Drill rigs -2,483.7 -13.9 67.7 4New Mexico 2310000330- Oil and Gas Production: Artificial lift 763.3 0.1 7.9 1New Mexico 2310000440- Oil and Gas Production: Saltwater disposal engines 170.4 9.5 New Mexico 2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 416.0 0.3 1New Mexico 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing 1,194.3 

New Mexico 

2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices 122.1 

New Mexico 2310010700- Oil and Gas Production: Crude Petroleum Oil well fugitives 622.1 New Mexico 2310010800- Oil and Gas Production: Crude Petroleum Oil well truck loading 154.5 New Mexico 2310020600- Oil and Gas Production: Natural Gas Compressor engines -54,605.9 1.4 4,879.0 38,6New Mexico 2310020700- Oil and Gas Production: Natural Gas well fugitives 52,087.1 New Mexico 2310020800- Oil and Gas Production: Natural Gas well truck loading 501.3 New Mexico 2310021100- Oil and Gas Production: Natural Gas well heaters -6,296.4 7.3 -9New Mexico 2310021300- Oil and Gas Production: Natural Gas well pneumatic devices -3,693.7 New Mexico 2310021400- Oil and Gas Production: Natural Gas well dehydrators -7,020.7 New Mexico 

2310021500- Oil and Gas Production: Natural Gas well completion - flaring and venting -1,809.8 0.1 -70,522.1 -4

New Mexico 2310021600- Oil and Gas Production: Natural Gas well venting 63,212.9 New Mexico 

2310023000- Oil and Gas Production: Natural Gas CBM gas well - Dewatering pump engines 66.9 

New Mexico 

2310030210- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing, Uncontrolled -31,670.1 

New Mexico 2311000100- Construction: All Processes Wind Erosion New Mexico 2311010000- Construction: Residential Total New Mexico 2311020000- Construction: Industrial/Commercial/Institutional Total New Mexico 2311030000- Construction: Road Construction Total Deleted Records All -124.2 -0.1 -70,753.3 WRAP PRP18 Emissions Inventory (TPY): New Mexico All 108,415.5 15,748.4 338,403.5 85,9
A2-10 

North Dakota – Area Sources 

State SCC NOX SO2 VOC CO PM10 

WRAP 2018b Base Case Emissions Inventory (TPY): North Dakota All 21,128.7 5,856.3 82,650.7 21,606.8 311,27Net Changes to 2018b Base Case Emissions Inventory (TPY): North Dakota 2310000220- Oil and Gas Production: Drill rigs 362.1 1.3 North Dakota 

2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 32.1 6.4 

North Dakota 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing 2,814.4 

North Dakota 

2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices 40.3 

North Dakota 

2310020600- Oil and Gas Production: Natural Gas Compressor engines 11,648.5 

North Dakota 

2310021100- Oil and Gas Production: Natural Gas well heaters 115.7 24.3 

North Dakota 

2310021300- Oil and Gas Production: Natural Gas well pneumatic devices 26.4 

North Dakota 

2310021400- Oil and Gas Production: Natural Gas well dehydrators 362.0 

North Dakota 

2310021500- Oil and Gas Production: Natural Gas well completion - flaring and venting 33.7 1,657.2 8.5 

North Dakota 

2310030220- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing 15.7 

Deleted Records All -0.6 WRAP PRP18 Emissions Inventory (TPY): North Dakota All 33,320.2 5,857.6 87,566.7 21,646.0 311,27
A2-11 

Oregon – Area Sources 

State SCC NOX SO2 VOC CO PM10 

WRAP 2018b Base Case Emissions Inventory (TPY): Oregon All 17,027.2 8,421.9 334,872.1 380,523.7 225,924Net Changes to 2018b Base Case Emissions Inventory (TPY): Oregon 

2310020600- Oil and Gas Production: Natural Gas Compressor engines -4.8 

Oregon 2310021100- Oil and Gas Production: Natural Gas well heaters 0.8 0.1 Oregon 

2310021300- Oil and Gas Production: Natural Gas well pneumatic devices 0.2 

Oregon 

2310021400- Oil and Gas Production: Natural Gas well dehydrators -5.5 

WRAP PRP18 Emissions Inventory (TPY): Oregon All 17,023.2 8,421.9 334,866.8 380,523.8 225,924
A2-12 

South Dakota – Area Sources 

State SCC NOX SO2 VOC CO PM

WRAP 2018b Base Case Emissions Inventory (TPY): South Dakota All 7,206.9 11,667.2 50,072.1 25,112.4 22Net Changes to 2018b Base Case Emissions Inventory (TPY): South Dakota 

2103002000- Commercial/Institutional Bituminous/Subbituminous Coal Combustion 20.6 36.1 0.2 11.7 

South Dakota 2199003000- Total Area Source Lignite Coal Combustion 10.0 34.7 1.8 3.5 South Dakota 2310000220- Oil and Gas Production: Drill rigs 92.9 0.2 0.2 1.2 South Dakota 

2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 2.0 0.3 

South Dakota 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing 171.1 

South Dakota 

2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices 6.0 

South Dakota 

2310020600- Oil and Gas Production: Natural Gas Compressor engines -46.1 

South Dakota 

2310021100- Oil and Gas Production: Natural Gas well heaters 1.3 0.2 

South Dakota 

2310021300- Oil and Gas Production: Natural Gas well pneumatic devices 0.3 

South Dakota 

2310021400- Oil and Gas Production: Natural Gas well dehydrators -3.1 

Deleted Records -2,284.0 -7,653.6 -10.5 -1,042.5 -WRAP PRP18 Emissions Inventory (TPY): South Dakota All 5,003.6 4,084.6 50,238.1 24,086.8 22
A2-13 

Utah – Area Sources 

State SCC NOX SO2 VOC CO 

WRAP 2018b Base Case Emissions Inventory (TPY): Utah All 21,635.7 3,586.9 173,344.0 45,962.2 Net Changes to 2018b Base Case Emissions Inventory (TPY): Utah 2310000220- Oil and Gas Production: Drill rigs -1,267.3 -4.1 31.4 213.2 Utah 

2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 77.1 15.5 

Utah 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing 6,760.1 

Utah 

2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices -154.0 

Utah 

2310020600- Oil and Gas Production: Natural Gas Compressor engines -3,395.2 91.1 

Utah 2310021100- Oil and Gas Production: Natural Gas well heaters -1,082.5 -227.4 Utah 

2310021300- Oil and Gas Production: Natural Gas well pneumatic devices -247.1 

Utah 2310021400- Oil and Gas Production: Natural Gas well dehydrators -2,301.9 Utah 

2310021500- Oil and Gas Production: Natural Gas well completion - flaring and venting -31.4 -1,541.2 -7.9 

Utah 

2310030210- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing -16,021.4 

Deleted Records All -1.4 -12.3 -0.0 WRAP PRP18 Emissions Inventory (TPY): Utah All 15,935.0 3,582.8 159,948.7 45,955.6 
A2-14 

Washington – Area Sources 

State SCC NOX SO2 VOC CO PM10 

WRAP 2018b Base Case Emissions Inventory (TPY): Washington All 22,746.0 8,667.3 253,709.8 252,446.6 348,329.4 Net Changes to 2018b Base Case Emissions Inventory (TPY):No changes WRAP PRP18 Emissions Inventory (TPY): Washington All 22,746.0 8,667.3 253,709.8 252,446.6 348,329.4 
A2-15 

Wyoming – Area Sources 

State SCC NOX SO2 VOC CO PM10 

WRAP 2018b Base Case Emissions Inventory (TPY): Wyoming All 79,196.4 23,109.2 436,884.9 34,463.3 45,027.2 Net Changes to 2018b Base Case Emissions Inventory (TPY): Wyoming 2310000220- Oil and Gas Production: Drill rigs 2,446.5 -12.2 406.8 3,688.4 Wyoming 

2310010100- Oil and Gas Production: Crude Petroleum Oil well heaters 17.4 3.4 

Wyoming 

2310010200- Oil and Gas Production: Crude Petroleum Oil well tanks - flashing & standing/working/breathing 1,523.4 

Wyoming 

2310010300- Oil and Gas Production: Crude Petroleum Oil well pneumatic devices -658.5 

Wyoming 

2310020600- Oil and Gas Production: Natural Gas Compressor engines -32,073.3 464.2 

Wyoming 

2310021100- Oil and Gas Production: Natural Gas well heaters 4,150.7 871.6 

Wyoming 

2310021300- Oil and Gas Production: Natural Gas well pneumatic devices 947.6 

Wyoming 

2310021400- Oil and Gas Production: Natural Gas well dehydrators -75,093.8 

Wyoming 

2310021500- Oil and Gas Production: Natural Gas well completion - flaring and venting -38.5 -1,891.3 -9.7 

Wyoming 

2310023000- Oil and Gas Production: Natural Gas CBM gas well - Dewatering pump engines 106.3 

Wyoming 

2310030210- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing -24,857.2 

Wyoming 

2310030220- Oil and Gas Production: Natural Gas Liquids Gas well tanks - Flashing & Standing/Working/Breathing -726.8 

WRAP PRP18 Emissions Inventory (TPY): Wyoming All 53,805.5 23,097.0 336,999.3 39,017.0 45,027.2 
A2-16 

Tribal – Area Sources 

State SCC NOX SO2 VOC CO PM10 

WRAP 2018b Base Case Emissions Inventory (TPY): Tribal All 6,639.0 2.1 18,240.3 564.0 2,06Net Changes to 2018b Base Case Emissions Inventory (TPY):No Changes WRAP PRP18 Emissions Inventory (TPY): Tribal All 6,639.0 2.1 18,240.3 564.0 2,06
ATTACHMENT 3: 

OUTSTANDING ISSUES 

 
A3-1 

Outstanding Issues Related to PRP18 Emissions Inventory 

State Commenter Comment Summary Response for PRP 2018 Analysis Data Source 

Reprojectio

Required

AK A.Edwards 

Responded to questions about 2 missing coal-fired boilers in 2002 and 2018 at USArmy Ft. Wainwright 

Need to add 2 records for PM10 (at min.) for these missing boilers in both 2002 and 2018 E-mail from Alice, 4/20/07

Yes - but not at this time 

AZ L. Toopal 

Per Pechan Report, add new plant, Arizona Clean Fuels Refinery, to be built 40 mi. east of Yuma. Permitted emissions. - 251 tpy of SO2 

We will add this new facility to 2018. Growth in the AZ refining sector will be adjusted for this new facility. 

AZ_Proposed Changes & Feedback Request.xls Yes 

AZ S. DiBiase 

Desert Basin (facility ID V20620/EGU0049) CO emissions appear to be off...should be 105 tons not 1,051 for SCC 20100201. 

4-16: E-mail to Scott asking if we should change 2002 and 2018 to 105 tons. E-mail 3-15-07 TBD 

AZ P. DeNee 

Point Sources It was difficult to track the various point sources used in the NOx pivot tables and the 2018-18b spreadsheet because the source names are not in alphabetical order. They are fortunately in order in the PM10 and PM2.5 Pivot Tables. 

Agreed - we will fix the pivot tables to order plants alphabetically. 

WRAP 2018 EI Review - Phil DeNee.doc No 

CO Curtis Taipale 

Colorado was the first state in the country to have voters approve a Renewable Energy Standard (RES) that requires utilities with over 40,000 customers to generate or purchase a minimum amount of electricity from renewable sources. By 2018, the benefit of this program might reduce our coal-fired generating needs by at more 7-10%. Similarly, I understand that California has a similar program with benefits approaching 13% by 2007. It seems that we should take credit in the 2018 modeling for these types of programs. It would take some technical analysis to nail down the exact estimates that I am unable to quickly quantify by today's deadline. We will provide some technical analysis in our SIP to address this issue but having it quantified in the regional modeling would be the best option. Thoughts? 

Response from Lee Gribovicz: "...add the renewable credit to the list..." of outstanding issues. 

E-mail from Curt and response from Lee on 5/10/07 No 
Outstanding Issues Related to PRP18 Emissions Inventory (Continued)

A3-2 

State Commenter Comment Summary Response for PRP 2018 Analysis Data Source 

Reprojectio

Required

ID C. Ramsdell 

Sent 2005 SO2 emissions for four (4) facilities with 4 different SCCs (120 to 215 

tons) not shown in 80% summary table; suggest to add to inventory (Facilities: BAF Blackfoot/ID 1100012; Idaho Supreme Potatoes/ID 1100013; Larsen Farms/ID 3300002; Idaho Fresh Pak/ID 5100017) 

BAF Blackfoot/SCC 10200402 and Larsen Farms/SCC 10300401 are not in 2018-18b or 2002 inventories; we will not add them at this time (have requested 2002 emissions from IDEQ so that these can be added to 2002 first, then projected to 2018). Idaho Supreme Potatoes/SCC 10200401 has 11.27 ton SO2 in 2018-18b, and Idaho Fresh Pak/SCC 10200501 has 0.01 ton SO2 in 2018; we will set their 2018 emissions to 2005 levels as provided by IDEQ. We defer adding the BAF Blackfoot and Larsen Farms emissions until the 2002 and 2018 inventories are updated next year. (We provided this explanation to Chris on 4-16-07.) 

point_summary_ID_cut.xls No 

ID C.Ramsdell 

Provided spreadsheet with dual-fueled source emissions 

The data provided do not include SCCs, and are for 2005, so they cannot be directly compared to the existing 2018-18b database. We will assume that these are accounted for in the 2002 and 2018 inventory, otherwise IDEQ would need to provide these by Facility ID, and SCC. We requested this information from Chris on 4-16-07.) V-mail from Chris indicates that data cannot be provided until later this week, which will be too late for this project. This comment will be deferred until next inventory update. Dual Emissions.xls TBD 

ID 

C.Ramsdell Provided spreadsheet with the top 10 area source SCCs for NOx and SO2 by county

NOx: all top 10 SCCs have 2005 emissions that are <2018, except for 2102006000 (Industrial natural gas boilers) where ID 2005 = 1619 tons (for 44 counties) and 2018-18b = 1325 tons (for 6 counties only). Will make no changes to the 2018 inventory at this time as reconciliation will be required for the 2002 inventory and reproject to 2018. 

Top 10 SCC SO2 NOX by County.xls 

Yes - but deferred 
Outstanding Issues Related to PRP18 Emissions Inventory (Continued)

A3-3 

State Commenter Comment Summary Response for PRP 2018 Analysis Data Source 

Reprojectio

Required

ID 

C.Ramsdell Provided spreadsheet with the top 10 area source SCCs for NOx and SO2 by county

NOx: For SCC 2010008000 (Industrial wood boilers), the 2018-18b NOx emissions seem excessive as compared to 2005, where ID 2005 = 1840 tons and 2018-18b = 31803 tons. The large 2018-18b estimate is driven by an equally large 2002 estimate, which appears to be incorrect (i.e., based on EPA gapfilling of NEI, which was used for WRAP 2002). We have requested 2002 emissions from Chris for this SCC on 4-16-07; v-mail from Chris said that data cannot be provided until later this week, which will be too late for this project. This change to 2002 and 2018 for NOx and SO2 will be deferred until the next inventory update.

Top 10 SCC SO2 NOX by County.xls 

Yes - but deferred 

ID C.Ramsdell 

ENVIRON has raised an issue that stage I and II refueling SCCs (250xxxxxxx) are missing from the area source inventory. Chris Ramsdell with the state has confirmed that they did include these sccs in their 2002 area source inventory. 

These sources did not appear in WRAP 2002 inventory (taken from 2002 NEI). Adding to 2018 now would require reprojection from 2005, and would create an inconsistency with 2002. Will be included in revision to 2002 and next revision to 2018. Email 

No - not athis time. 

ID M. Edwards 

Meeting scheduled with TASCO/Amalgamated Sugar on March 27, after which BART level will be known. 

4-6-07: sent e-mail to Mike Edwards requesting BART limit for TASCO. 

E-mail_MikeEdwards_3-23-07_RE Idaho EI information from 31907 conference call.doc No 

NV L. Campbell 

Add 2002 CO emissions for 2 new facilities (NP Clark and Sunrise Stations) and 1 existing facility (SPPC Valmy) and project to 2018 (Facility IDs, AP49110398, AP49110399, and AP49110457.) 

SPPC Valmy is in 2018, but CO amount was below 80% cut-off; no change is needed. Will need to add CO boiler emissions (SCC 10300601) for NP Clark and Sunrise Stations later. 

NV_2018-18b_point_summary_80% review by NDEP.xls (CO worksheet) 

Yes - but not at this time 

NV 

M. Doyle - Clark Co. 

Request to add PM2.5 emissions (assume PM2.5=PM10) for all natural gas fired power plants (excluding Copper Mtn, and Chuck Lenzie which already have PM2.5 estimates). 

Would need to add PM2.5 emissions for 2002 and project to 2018. This may be done during next RP inventory revision, but not at this time,. Email 4-3-07 

Yes - but not at this time 
Outstanding Issues Related to PRP18 Emissions Inventory (Continued)

A3-4 

State Commenter Comment Summary Response for PRP 2018 Analysis Data Source 

Reprojectio

Required

NV 

Rodney Langston – Clark Co. 

WRAP projections should include PM10 controls on fugitive dust sources from our PM10 SIP 

ERG researched this issue, with assistance from Clark Co. staff (Doyle and Lendis). Appendix L of the SIP provides control reductions for unstable vacant land, construction, unpaved road dust, paved road dust, unpaved parking, and race tracks. The only relevant category to the PRP18 point and area source inventory is a subset of construction:construction activities. The Appendix L documentation provides an emission reduction of 87% (due to watering), a rule penetration of 98% (only sites 1/4 acre or larger), and varying rule effectiveness values - 40% in 2001, 64% in 2002, and 80% in 2003 and beyond. This results in an overall control reduction of 34% in 2001 and 68% in 2006. The Appendix L documentation provides 2001 annual uncontrolled emissions (23,109 tpy) and controlled emissions (15,252 tpy) for the Valley-Wide Inventory; the only 2006 inventories in the documentation are 24-hour inventories. For the WRAP inventories, there are three construction source categories: residential, industrial/commercial/institutional, and road. The 2002 emissions for Clark County are 30,802 tpy; the 2018 emissions are 44,407 tpy. 

SD D. Healey 

Provided 2005 PM2.5, SO2, and NOx emissions for area source distillate fuel combustion. In follow-up call with ERG, it was noted that only 2005 fuel use is readily available (not 2002) 

We will not make these changes, since this will require a re-projection from 2005 to 2018. This change will be deferred until next year with 2002 and 2018 EIs are revised/finalized again. 

SD AREA NEI distillate.xls 

Yes - but not at this time 
Outstanding Issues Related to PRP18 Emissions Inventory (Continued)

A3-5 

State Commenter Comment Summary Response for PRP 2018 Analysis Data Source 

Reprojectio

Required

UT D. McMurtrie 

Confirmed changes to SO2 sources recommended in Pechan report for: Holcim - Devil's Slide, Kennecott Smelter & Refinery, Flying J Refinery, Tesoro - SLC Refinery, Chevron - Salt Lake Refinery, and Phillips Refinery. All facilities' emissions change for 2018, and all except Holcim and Kennecott change in 2002. 

4/10: P.Fields (ERG) talked to D.McMurtrie who said she would send an e-mail to confirm changes are okay. Confirmation e-mail was never received. 

UT_Proposed Changes & Feedback Request.xls No 

WA S. Otterson 

Provided updated 2005 woodstove/fireplace inventory to replace the 2002 inventory 

We compared the 2002 WRAP emissions to the 2005 WA emissions, and found (2002/2005 ratio): NOx 89%, SO2 84%, VOC 121%, CO 97%, PM10 96%, PM2.5 90%. We will defer these changes until WRAP does a final 2002 and 2018 inventory revision. WA_Updates.xls 

No - not athis tme 

WA 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 new records to replace old records; confirm only a 2018 change (and not 2002). May require re-projection if new SICs (different growth factors may now apply) WA_Updates.xls TBD 

WA S. Otterson 

Provided actual 2005 emissions data for 3 facilities listed with Plant IDs PRJ*** in NIF format (Goldendale Energy Center, Frederickson Power LP, Chehalis Power LP/Chehalis Generation Facility) 

We will replace the "PRJ" plant IDs with the state IDs, but cannot project from 2005 at this time. 

WA_Updates.xls and Adds_Replace_NIF.mdb 

2005 projection is deferred 

WA S. Otterson 

Provided actual 2005 oil refinery data (in NIF format) to replace their current 2002 WRAP data (Puget Sound Refining Co., Tesoro Northwest Co., Conoco Phillips, BP Cherry Point Refinery) 

We will keep in data on file, but cannot make changes at this time. 

WA_Updates.xls and Adds_Replace_NIF.mdb 

Yes, but not at this time 

WA S. Otterson 

Provided actual 2005 emissions data (in NIF format) to replace current 2002 WRAP data for several other facilities (Mutual Materials, Longview Fibre, Weyerhaeuser co.) 

We will keep in data on file, but cannot make changes at this time. 

WA_Updates.xls and Adds_Replace_NIF.mdb 

Yes, but not at this time 
Outstanding Issues Related to PRP18 Emissions Inventory (Continued)

A3-6 

State Commenter Comment Summary Response for PRP 2018 Analysis Data Source 

Reprojectio

Required

WY L. Bocchino 

Dyno Nobel received a permit last year which included the addition of a nitric acid plant, an ammonium nitrate plant, the replacement of two engines, and the *restoration* of 2 existing boilers. The net change in potential emissions is between 30 and 200 tpy depending on the pollutant. The permit is attached. What more do you need? 

The records in the existing 2018-18b database, by SCC and unit ID, do not match any of the unit IDs shown on the permit. Sent e-mail on 4-11 to Brian and Lori requesting them to match the existing records/units/SCCs with permit limits; we may decide to pull all current 2002 and 2018 Dyno Nobel records and replace them with new records to match the existing permit limits (based on the units in the permit); this could not be done until the next revision of the EI since there are 2002 implications. 

E-mail_Lori_More questions and info re WY 2018 projections.doc and DynoNobelMD-1502.doc TBD 

WY B. Bohlmann 

Dyno Nobel MTBE plant (operable in 2002) has been dismantled and air permits are being proposed for additional acid plants. Thus 2018 emissions may be significantly different from the 2002 emissions. 

We need specific SCC level emission changes for 2018 in order to put the impact of these changes in the to inventory. In the absence of additional information from the agency, no changes will be made E-mail 4-11-07 No 

WY B. Bohlmann 

For Plant ID 5602100002 (DYNO NOBEL INC. - CHEYENNE PLANT), change SCC from 30688801 to 30104199 

We will either change SCC as requested or pull all records and replace with new records in order to match to Unit IDs, permit limits (see previous comment and response). 

Wrap WY_2018-18b_point_summary_80%.xls (NOx, SO2, VOC, CO, PM10 worksheet) TBD 

WY B. Bohlmann 

Combustion SCC growth factors (soda ash production) for 2018 SO2 emissions for FMC Corp-Green River Plant-Sodium products (Plant ID 5603700048) per Pechan SO2 Report for 309 States (Oct 2006), Table III-5. 

Will change SO2 emissions for the applicable EU (EU ID#1014 and 1015) to 3555 tons from 3612 tons. Will obtain SCC level info from Pechan. 

WRAP WY_Proposed Changes & Feedback Request.xls No 

WY B. Bohlmann 

Per Pechan Report, Table III-5, made FCCU emission adjustments for 2002 and 2018 (i.e., growth factor adjustment for fuel combustion sources for 2018 SO2 emissions for Frontier Refining Inc. (Plant ID 5602100001)). 

For 2018, we will change the 2018 total SO2 emissions for the facility to 1292 tons from 1964 tons. Per WRAP, no changes to 2002 should be made at this time. 

WRAP WY_Proposed Changes & Feedback Request.xls No 

WY B. Bohlmann 

Per Pechan Report, Table III-5, possible FCCU adjustments (2002 and 2018); growth factor adjustment for fuel combustion sources for 2018 SO2 emissions for Sinclair Oil Corp-Sinclair Refinery (Plant ID 5600700001). 

Will change the 2018 total SO2 emissions for the facility to 3709 tons from 4703 tons. Will not change 2002 emissions at this time. 

WRAP WY_Proposed Changes & Feedback Request.xls No 
Outstanding Issues Related to PRP18 Emissions Inventory (Continued)

A3-7 

State Commenter Comment Summary Response for PRP 2018 Analysis Data Source 

Reprojectio

Required

WY B. Bohlmann 

Per Pechan Report, Table III-5, made FCCU adjustments (2002 and 2018); growth factor adjustment for fuel combustion sources for 2018 SO2 emissions for Sinclair Oil Corp-Casper Refinery (Plant ID 5602500005) 

Will change the 2018 total SO2 emissions for the facility to 1165 tons from 1389 tons. Will obtain SCC level info from Pechan. Will not change 2002 emissions at this time per WRAP. 

WRAP WY_Proposed Changes & Feedback Request.xls No 

WY B. Bohlmann 

The Santa Fe Snyder Riverton Plant, now called Devon Energy Production Company, L.P. Riverton Dome, is on the Wind River Indian Reservation and needs to be listed as such. It is currently listed as a Wyoming facility instead of a tribal facility. 

Facility name will be changed; facility will be moved from Wyoming to the Wind River Indian Reservation. 

E-mail from Brian Bohlmann on 5/3/07. No 

WY B. Bohlmann 

Celotex Corporation has a FIPS code of 56029:0:3 indicating that this is a Wyoming facility. Based on a file search, this facility is not in Wyoming. 

Facility was identified as BPB America, Cody Wallboard Plant. 

E-mail from Brian Bohlmann on 5/15/07. No