DEVELOPMENT OF EMISSION BUDGET INVENTORIES FOR REGIONAL TRANSPORT NOx SIP CALL TECHNICAL AMENDMENT VERSION A-96-56 : X-B-ll U.S. Environmental Protection Agency Office of Air Quality Planning and Standards December 1999 ------- This page intentionally left blank. ------- Chapter I Introduction Table of Contents l Chapter II Electric Generating Unit Point Source Emissions 3 A. Development of Base Year Emissions 3 B. 2007 Base Case 7 C. 2007 Budget Case 7 D. EGU Emission Summary 8 Chapter III Non-EGU Point Source Emissions 11 A. Development of Base Emissions 11 B. 2007 Base Case 11 C. 2007 Budget Case 12 D. Non-EGU Emission Summary 14 Chapter IV Stationary Area and Nonroad Source Emissions 25 A. Development of Base Year Emissions 25 B. 2007 Base Case 25 C. 2007 Budget Case 25 D. Stationary Area and Nonroad Emission Summary 26 Chapter V Highway Vehicle Source Emissions 29 A. Development of Base Year Emissions 29 B. 2007 Base Case 30 C. 2007 Budget Case 31 D. Highway Vehicle Emission Summary 31 Chapter VI Statewide NOx Budgets 37 APPENDIX A 2007 BASE CASE CONTROLS APPENDIX B NON-EGU POINT SOURCE CONTROL CATEGORY CODES APPENDIX C SOURCE SPECIFIC EGU BASE AND BUDGET EMISSIONS FILE APPENDIX D SOURCE SPECIFIC NON-EGU POINT SOURCE BASE AND BUDGET EMISSIONS FILE APPENDIX E COUNTY LEVEL STATIONARY AREA BASE AND BUDGET EMISSIONS FILE APPENDIX F COUNTY LEVEL NONROAD MOBILE BASE AND BUDGET EMISSIONS FILE APPENDIX G COUNTY LEVEL HIGHWAY VEHICLE BASE AND BUDGET EMISSIONS FILE APPENDIX H MOBILE MODEL HIGHWAY VEHICLE COUNTY CORRESPONDENCE FILE ------- This page intentionally left blank. ------- Chapter I Introduction The purpose of this document is to describe the development of the emissions and control data used in the United States (U.S.) Environmental Protection Agency's (EPA) Regional Transport NOx State Implementation Plan (SIP) Call Notice of Final Rulemaking (NFR) and to describe the process for calculation of the associated Statewide budgets. Chapter II of this document describes the development of the electric generating unit (EGU) point source data and budget, Chapter III describes the development of the non-EGU point source data and budget, Chapter IV describes the stationary area and nonroad mobile source data and budget, and Chapter V describes the highway vehicle data and budget. It should be noted that there were several comment periods during which EPA received comments on various aspects of the SIP Call emissions inventories. As a result of the Notice of Proposed Rulemaking (NPR) and Supplemental Notice of Proposed Rulemaking (SNPR) public comment periods, EPA revised the inventories with approved data addressing issues such as emission estimate revisions, missing sources, retired sources, incorrect source sizes, base year control levels, and facility name changes. Details of these comments and their affect on the base inventory can be found in the response to significant comments document for the NFR (EPA, 1998a). In addition to the NPR and SNPR public comment periods, in the NFR (63 FR 57427) EPA allowed commenters an additional opportunity to request revision to the source specific data used to establish each State's budget in the SIP Call. This opportunity for comments ended on November 23, 1998. When EPA published its correction and clarification notice to the NFR (63 FR 71220), EPA reopened the comment period for emissions inventory revisions. This comment period was restricted to comments related to the baseline sub-inventory information used to establish the State's budgets. This comment period ended on February 22, 1999. The EPA is proceeding to final action now on a second technical amendment based on further comments received from the public in response to the SIP call and the request for comments on inventory revisions as well as the May 14, 1999 technical amendment. The emissions inventories described in this document reflect the public comments accepted by EPA. The EPA's review and acceptance/rejection of specific comments is contained in EPA's "Responses to the 2007 Baseline Sub-Inventory Information and Significant Comments for the Final NOx SIP Call and Proposed Rulemakings for Section 126 Petitions and Federal Implementation Plans - Technical Amendment Version," (EPA, 1999b) and "Responses to the 2007 Baseline Sub-Inventory Information and Significant Comments for the Final NOx SIP Call," (EPA, 1999). ------- ------- This page intentionally left blank. ------- Chapter II Electric Generating Unit Point Source Emissions A. Development of Base Year Emissions The base year electric generating unit (EGU) emissions were developed to provide the EGU data necessary for determining the 2007 budget case and to supply data for use in air quality modeling of the budget case. A base year EGU inventory was developed using the higher of 1995 or 1996 heat input (determined at the State-level) for the purpose of calculating the 2007 budget case (as explained below). A 1996 base year EGU inventory was developed for the air quality modeling. For each base year inventory, both seasonal and daily emissions estimates were developed. The base year EGU inventories consist of both electric utility units and nonutility electricity generating units. The nonutility electricity generating units include independent power producers (IPPs) and nonutility generators (NUGs). Eight data sources were used to develop the base year EGU emissions data: 1. EPA's Acid Rain Data Base (ARDB) (Pechan, 1997c); 2. EPA's 2007 Integrated Planning Model Year 2007 (IPM); 3. EPA's Emission Tracking System/Continuous Emissions Monitoring System (ETS/CEM) (EPA, 1997b); 4. DOE's Form EIA-860 (DOE, 1995a); 5. DOE's Form EIA-767 (DOE, 1995b); 6. EPA's National Emissions Trends Data Base (NET) (EPA, 1997c); 7. DOE's Form EIA-867 (DOE, 1995c); and 8. The OTAG Emission Inventory (Pechan, 1997a). Each of these data sources is described below. EPA's Acid Rain Data Base (ARDB) was developed in response to the Acid Rain Program authorized under Title IV. The data base was originally an update to the boiler-based National Allowance Data Base Version 3.11 (NADBV311) which was used in the calculation of the S02 allowances as specified in Title IV. Over the last few years, the data base has been expanded to include ETS/CEM 1994-1996 S02, NOx, C02, and heat input; as well as 1985-1995 NET utility data, boiler identification, characteristics, and locational data. The existing boilers and planned turbines (as of 1990) in the ARDB are used as units for the EGU. EPA's 2007 Integrated Planning Model Year 2007 (IPM) data base represents a unit-level disaggregated IPM Clean Air Act (CAA) baseline simulation developed for OTAG air quality modeling. The IPM includes over 7,000 units (nationally) with data on existing electricity 4 ------- generating units. This information is maintained in EPA's National Electric Energy Data System (NEEDS). In general, the generator-level utility turbines and engines, as well as nonutility units that are not required to report to EPA under the Title IV program, are included in IPM. However for purposes of developing the EGU base year inventory, IC engines were included in the non- EGU inventory, rather than in the EGU inventory. This is because emissions and emission reductions for all IC engines (including both engines used for purposes of generating electricity and engines used for other purposes such as powering pumps on gas lines) were determined in the same way (see Chapter 3 for a more complete discussion of the treatment of IC engines). Supplemental data, provided by EPA, including the start year, the base year (1994) NOx rate, and type of ownership, were added to the IPM data base. This information was used to obtain NOx emissions and heat input data for these units. Where units could be matched to other inventories, actual locational data are included in the IPM; otherwise, county centroids are used. EPA's Emission Tracking System/Continuous Emissions Monitoring System (ETS/CEM) data contains hourly S02, C02, NOx rate, and heat input data at the monitoring stack level and boiler level for all boilers included in the Acid Rain Program that was mandated by Title IV of the Clean Air Act Amendments of 1990 (CAAA). In 1994, data were collected from the 263 Phase I boilers; beginning in 1995, data are collected from Phase II as well as Phase I affected boilers. These data were used to provide NOx emissions and heat input. DOE's Form EIA-860 is an annual utility survey, "Annual Electric Generator Report," that provides utility data on a generator level. Both existing and planned generators are reported. The data include generator identification, status, capacity, prime mover, and fuel type(s). Units reported on this form were generally only included in the EGU file if they also were included in the IPM file since NOx emissions and heat input are not derivable from Form EIA-860 alone. This form was useful, however, in providing other information, such as prime mover and unit status. DOE's Form EIA-767 is an annual utility survey, "Steam-Electric Plant Operation and Design Report," that contains data for fossil fuel steam boilers such as fuel quantity and quality; boiler identification, locational, status, and design information; and flue gas Desulfurization scrubber and particulate collector device information. Note that boilers in plants with less than 10 MW do not report all data elements. The relationship between boilers and generators is also provided, along with generator-level generation and nameplate capacity. Note that boilers and generators are not necessarily in a one-to-one correspondence. EPA's NET fossil fuel steam data base is developed annually by EPA. The data base was initially based on DOE's Form EIA-767 data, but the coal NOx emissions have been superseded by calculations using EPA NOx rates, and the NOx, S02 and heat input data from ETS/CEM, if available. Source Classification Codes (SCCs) are assigned to each boiler based on boiler and fuel characteristics; AP-42 emission factors are used to calculate VOC, CO, PM10, and PM2.5 emissions. The 1990 and 1995 NET data bases were used to obtain SCCs, stack parameters, NOx emissions and heat input. 5 ------- DOE's Form EIA-867 "Annual Nonutility Power Producer Report" is similar in content to, although more limited than, the utility Forms EIA-860 and EIA-767. The EIA-867, however, is a confidential form, and aside from the facility identification data (which includes State and capacity), EIA can only provide most data from this form on an aggregated basis. Only a few of the units in this file were ultimately used since it was difficult to obtain NOx emissions, heat input, or locational data unless they could be matched to another source. The OTAG data base was developed by collecting and compiling electric utility emission inventory data from States in the OTAG domain. This 1990 inventory contains summer day emission estimates, as well as variables required for air quality modeling. This data base was used to obtain NOx emissions and locational data. In general, the operating units in the ARDB identified the steam boilers, while the IPM data base identified the generator-level utility turbines and engines, as well as the nonutility units. While some units were obtained from the other data bases, the primary purpose of the other data bases was to add variables required for modeling to the units identified by the ARDB or IPM data. In order for a unit to be used, it had to have enough data to estimate emissions. Data had to be available on either daily or seasonal heat input or daily or seasonal NOx emissions. The NOx emission rate was also required, but a default NOx emission rate from AP-42 was assigned to units that had data on heat input or emissions, but no NOx rate. The emissions from 421 units could not be estimated because there was no NOx emissions or heat input information available to EPA for these units. This suggests that these units may not have operated in the summer seasons of 1995 and 1996. The first step in developing the base year data was to develop a file containing all available heat input, NOx emissions and NOx rate information. The second step involved assigning SCCs. In the third step stack parameters needed for air quality modeling were added to the inventory. Step 1. Seasonal NOx Emissions and Heat Input The hierarchy for obtaining seasonal NOx emissions and heat input for a particular unit identified from the above sources of information is provided below. For the 1995/1996 base year: a Determine what year of data to use for a given boiler, based on the State that the boiler is in and whether 1996 or 1995 heat input was higher for that State. b. Based on that boiler year information, use ETS/CEM data to obtain 1995 seasonal NOx rate and 1995 seasonal heat input, or 1996 seasonal NOx rate and 1996 seasonal heat input to calculate seasonal NOx emissions. 6 ------- c. Based on that boiler year information, use the 1995 NET data base (or 1996 data projected from the 1995 NET) for annual NOx emissions and heat input, then convert to seasonal emissions. d. Use 1990 OTAG file for ozone season day (OSD) NOx emissions and OSD heat input (or July month heat input and divide by 31), then convert to seasonal emissions and forecast to the base year. e. Use IPM NOx rate and 2007 July heat input, calculate NOx emissions, convert to seasonal emissions, and backcast to the base year. f. If there is a heat input and no NOx emissions or rate, assign an AP-42 default NOx rate based on SCC and convert to seasonal emissions. For the 1996 base year: a. Use ETS/CEM 1996 file for seasonal NOx emissions and 1996 seasonal heat input. b. Use the 1996 projected from thel995 NET data base for annual NOx emissions and heat input, then convert to seasonal emissions. c. Use 1990 OTAG file for OSD NOx emissions and OSD heat input (or July month heat input and divide by 31), then convert to seasonal and forecast to the base year. d. Use IPM NOx rate and 2007 July heat input, calculate NOx emissions, convert to seasonal emissions, and backcast to the base year. f. If there is a heat input and no NOx emissions or rate, assign an AP-42 default NOx rate based on SCC and convert to seasonal emissions. Step 2. Source Classification Codes (SCCs) The methodology for assigning SCC is as follows: a. Match the unit to the NET 1995 or 1990 inventory and assign the major SCC (based on heat input) to the boiler. b. Match the unit to the OTAG data and assign the major SCC. c. Assign default SCCs based on prime mover, fuel type, and (in the case of steam units) boiler bottom and firing types. 7 ------- Step 3. Stack Parameters The methodology for obtaining stack parameters is as follows: a. Match the unit to the NET 1995 or 1990 inventory and use the NET stack data. b. Match the unit to the OTAG data base and use the OTAG stack data. c. Assign default stack parameters, based on prime mover and fuel type, that were originally developed for the Regional Oxidant Model (ROM). (Note that since stack parameters in IPM were originally developed by matching with the OTAG and NET inventories, followed by defaults, any stack parameters obtained from IPM are likely to be default parameters.) B. 2007 Base Case The 2007 base case summer season emissions were determined using the IPM. Note that no changes were made as a result of the extended emissions inventory comment period to the data or methods used for the IPM projection of the 2007 base case summer season emissions. The 2007 base case includes all applicable controls required by the CAAA. Applicable controls required for EGUs include Title IV Acid Rain controls and NOx RACT. Details regarding the IPM model and the method can be found in the Regulatory Impact Analysis (RIA) of the final SIP call (EPA, 1998c). Appendix A presents the EGU source controls included in the 2007 base case. The growth factors used in the 2007 base case were obtained from the IPM projections. The growth factors are at the State-level (i.e., there was a single growth factor for each State that was applied to all units in that State). The estimates were interpolated to 2007 using the average annual growth of each State as forecasted by EPA using the IPM and EPA's baseline electric generation forecast. In calculating the average annual growth, EPA relied on unit-specific summer energy use from 2000 to 2010 as forecasted by the IPM. The growth factors are shown in Table II-1. C. 2007 Budget Case The 2007 budget case was developed by unit by applying IPM growth factors and an emission rate to the 1995/1996 base year heat input. Units greater than 25 MWe in each of the SIP call States had a uniform emission rate of 0.15 lb NOx/MMBtu applied to them. Units 25MWe or smaller were left at their 2007 base case NOx emission rate. A description of the data file structure for EGU sources including emissions, growth, and control information used to estimate the 2007 EGU budget is provided in Appendix C of this document. The growth factors were applied to the 1995/1996 heat input to get 2007 projected heat input. Emissions of NOx were then calculated by multiplying the 2007 projected heat input by the 8 ------- 2007 budget-applicable NOx rate. D. EGU Emission Summary Table II-2 is a State-level summary of the EGU data. It contains seasonal NOx emissions for the 2007 base and budget cases. 9 ------- Table II-l IPM Growth Factors State 1996-2007 Growth Factor Alabama 1.10 Connecticut 0.60 District of Columbia 1.36 Delaware 1.27 Georgia 1.13 Illinois 1.08 Indiana 1.17 Kentucky 1.16 Massachusetts 1.59 Maryland 1.35 Michigan 1.13 Missouri 1.09 North Carolina 1.21 New Jersey 1.29 New York 1.05 Ohio 1.07 Pennsylvania 1.15 Rhode Island 0.47 South Carolina 1.43 Tennessee 1.21 Virginia 1.32 Wisconsin 1.12 West Virginia 1.03 10 ------- Table II-2 2007 Seasonal Base and Budget NOx Emissions for EGUs State 2007 Base 2007 Budget Alabama 76,926 29,022 Connecticut 5,636 2,652 Delaware 5,838 5,250 District of Columbia 3 207 Georgia 86,455 30,402 Illinois 119,311 32,372 Indiana 136,773 47,731 Kentucky 107,829 36,503 Maryland 32,603 14,656 Massachusetts 16,479 15,146 Michigan 86,600 32,228 Missouri 82,097 24,216 New Jersey 18,352 10,250 New York 39,199 31,036 North Carolina 84,815 31,821 Ohio 163,132 48,990 Pennsylvania 123,102 47,469 Rhode Island 1,082 997 South Carolina 36,299 16,772 Tennessee 70,908 25,814 Virginia 40,884 17,187 West Virginia 115,490 26,859 Wisconsin 51,962 17,381 Total * 1,501,775 544,961 * Totals may not sum due to rounding. ------- Chapter III Non-EGU Point Source Emissions A. Development of 1995 Base Year Emissions The non-EGU point source emissions were based on data sets originating with the OTAG 1990 base year inventory. The OTAG prepared these base year inventories with 1990 State ozone nonattainment SIP emission inventories. These data were supplemented with either other State inventory data, if available, or EPA's NET data, if State data were not available. The non-EGU point source emissions for 1990 were then grown to 1995 using Bureau of Economic Analysis (BEA) historical growth estimates of industrial earnings at the State 2-digit Standard Industrial Classification (SIC) applied to emissions at the Source Classification Code (SCC) level. These emissions were grown to 1995 for the purposes of modeling and to maintain a consistent base year inventory with the EGU data. NOx RACT controls were applied to major sources in ozone nonattainment areas (NAA) and the Ozone Transport Region (OTR) unless the area received a NOx waiver. Information on the application of NOx RACT came from the OTAG data base which was developed by surveying applicable States on their implementation of NOx RACT (Pechan, 1997b). These data include unit specific NOx RACT control efficiencies for many units. For units without specific control information either ozone nonattainment area/SCC NOx RACT efficiencies collected from the States or national/SCC NOx RACT default efficiencies were applied. Table III-l presents the national/SCC NOx RACT default efficiencies used in the base calculation. B. 2007 Base Case To obtain the 2007 Base Case emissions, the 1995 data were projected to 2007 using BEA projections of Gross State Product (GSP) at the 2-digit SIC level and supplemented with State, local, and industry provided growth factors. Where SICs were not provided, an SIC-SCC cross-reference file was used to apply these factors. In addition to NOx RACT, Maximum Achievable Control Technology (MACT) control assumptions were applied to large municipal waste combustors (MWC) in the base case. A 30 percent NOx reduction was assumed for sources identified by the MACT rule (EPA, 1998b). Appendix A presents the non-EGU point source controls included in the 2007 base case. Seasonal 2007 base case emissions were calculated by multiplying the seasonal 1995 base year emissions by the applicable growth rate and emission controls applicable for 2007. 12 ------- C. 2007 Budget Case Budget controls were applied to large sources in the following non-EGU categories: boilers, turbines, cement manufacturing plants, and internal combustion engines. To determine control efficiencies for these sources for purposes of calculating the budget, emissions were first totaled at each source to a primary fuel (SCC). For sources using more than one fuel, a primary fuel was assigned based on the emission segment with the largest heat input or NOx emissions from the base year inventory. This was done to prevent the application of multiple control strategies to units firing multiple fuels. A control category was then assigned to this primary fuel from which NOx controls were selected for application to the source. Appendix B presents a list of these control categories. For each of the categories to which budget level controls were applied, an additional distinction was needed between large and small units for non-EGU point sources. For the following affected categories, the characteristics shown below were used to determine if the sources were considered large. Category Large Size Determinant Boilers > 250 MMBtu/hr Turbines > 250 MMBtu/hr Cement Manufacturing Plants > 1 ton NOx / typical ozone season day Internal Combustion Engines > 1 ton NOx / typical ozone season day 1. Boilers and Turbines If heat input capacity data were available for a unit, these data were used in determining the source's size. However, a majority of the non-EGU point source units in the inventory did not include boiler capacity data. For these cases, data from the NET inventory were used to determine whether a non-EGU boiler or turbine was assumed as a large or small source. Using data from the NET data base, a default boiler capacity file that contained the mean and median boiler capacities by the first 6-digits of SCCs was developed. For each 6-digit SCC, the file also contained the average daily NOx emissions for units with boiler capacities closest to 250 MMBtu/hr. These data are listed in Table III-2. As an example, for the 6-digit SCC "202001", the boiler capacity closest to 250 MMBtu/hr is listed in Table III-2 as 276 MMBtu/hr. If there was only one unit with a boiler capacity of 276 MMBtu/hr, the daily NOx emissions from that unit were used. If more than one unit had a boiler capacity of 276 MMBtu/hr, the mean daily emissions of those units was used. Each non-EGU unit in the inventory was matched to the default file described above based on the 13 ------- first 6-digits of its SCC. The following rules were then used to determine if a unit's boiler capacity was considered greater than, equal to, or less than 250 MMBtu/hr. For each unit: a. If boiler capacity data were provided for the unit, size determination was made based on those data. b. If both the mean and median boiler capacity in the file were greater than 300 MMBtu/hr, it was assumed that the unit's boiler capacity was greater than 250 MMBtu/hr. c. If either the mean or median boiler capacity was between 200 and 300 MMBtu/hr, then the daily NOx emissions were used to determine the boiler size. If the daily NOx emissions were greater than the average daily NOx emissions in the default boiler capacity file, it was assumed that the boiler capacity was greater than 250 MMBtu/hr. If the daily NOx emissions were less than the average daily NOx emissions in the default boiler capacity file, it was assumed that the boiler capacity was less than 250 MMBtu/hr. d. If both the mean and median boiler capacity in the file were less than 200 MMBtu/hr, it was assumed that the boiler capacity was less than 250 MMBtu/hr. e. If the boiler could not be matched to the default boiler capacity file, it was assumed that the boiler capacity was less than 250 MMBtu/hr. Units for which the boiler capacity was estimated to be greater than 250 MMBtu/hr were categorized as large sources. 2. Cement Manufacturing Plants and Internal Combustion Engines For cement manufacturing plants and internal combustion engines, boiler capacity was not used to determine source size. Instead 1995 typical ozone season daily emissions were used as a determinant. If the 1995 point-level emissions were more than 1 ton/day, the unit was categorized as a large source. Otherwise the unit was categorized as a small source. 3. Calculation of Reductions Emissions reductions for the budgets were calculated only for large sources in the specific source categories listed in Table III-3. Sources not meeting the large source requirements from these affected categories were considered small and not subject to additional budget control. Emissions from sources smaller than the heat input capacity cutoff level, and that emit less than 1 ton of NOx per typical ozone season day are included in the budget inventory at their 2007 base 14 ------- case level. Additionally, those sources without adequate information to determine potentially applicable control techniques are included in the budget at 2007 base case levels. Emissions reductions for the budget case were estimated from first calculating 2007 uncontrolled emission levels by removing base case control efficiency and rule effectiveness values. The new budget control efficiency and 2007 base rule effectiveness were then applied to the 2007 uncontrolled emissions as in the 2007 base case. As noted above, no additional reductions (beyond those in the base case) were applied to small sources. It should be noted that the budget reductions were applied to all applicable sources even if these reductions were less stringent than the existing 2007 base case controls. Although uncommon, this resulted in an increase in emissions from the 2007 base case to the 2007 budget case for some sources. This method is consistent with the EGU budget calculation. The description of the data file structure for non-EGU sources including NOx emissions, growth, and control information is provided in Appendix D of this document. D. Non-EGU Emissions Summary Table III-4 is a State-level summary of the seasonal non-EGU emissions data. It contains five month ozone season NOx emissions for the 2007 base case and the 2007 budget case. 15 ------- Table III-l Default NOx RACT Control Assumptions Default NOx RACT Control Efficiency SCC NOy RACT Control Group (Percent) 10200101 Industrial Boiler - PC 50 10200104 Industrial Boiler - Stoker - Overfeed 55 10200201 Industrial Boiler - PC - Wet 50 10200202 Industrial Boiler - PC - Dry 50 10200203 Industrial Boiler - Cyclone 53 10200204 Industrial Boiler - Stoker - Spreader 55 10200205 Industrial Boiler - Stoker - Overfeed 55 10200206 Industrial Boiler - Stoker 55 10200210 Industrial Boiler - Stoker - Overfeed 55 10200212 Industrial Boiler - PC - Dry 50 10200213 Industrial Boiler - PC - Wet 50 10200217 Industrial Boiler - PC 50 10200219 Cogeneration - Coal 50 10200222 Industrial Boiler - PC - Dry 50 10200223 Industrial Boiler - Cyclone 53 10200224 Industrial Boiler - Stoker - Spreader 55 10200225 Industrial Boiler - Stoker - Overfeed 55 10200229 Cogeneration - Coal 50 10200301 Industrial Boiler - PC 50 10200306 Industrial Boiler - Stoker - Spreader 55 10200401 Industrial Boiler - Residual Oil 50 10200402 Industrial Boiler - Residual Oil 50 10200403 Industrial Boiler - Residual Oil 50 10200404 Industrial Boiler - Residual Oil 50 10200405 Cogeneration - Oil Turbines 68 10200501 Industrial Boiler - Distillate Oil 50 10200502 Industrial Boiler - Distillate Oil 50 10200503 Industrial Boiler - Distillate Oil 50 10200504 Industrial Boiler - Distillate Oil 50 10200505 Cogeneration - Oil Turbines 68 10200601 Industrial Boiler - Natural Gas 50 16 ------- Table III-l Default NOx RACT Control Assumptions Default NOx RACT Control Efficiency see NOy RACT Control Group (Percent) 10200602 Industrial Boiler - Natural Gas 50 10200603 Industrial Boiler - Natural Gas 50 10200604 Cogeneration - Natural Gas Turbines 84 10200699 Industrial Boiler - Natural Gas 50 10200701 Industrial Boiler - Natural Gas 50 10200704 Industrial Boiler - Natural Gas 50 10200707 Industrial Boiler - Natural Gas 50 10200710 Cogeneration - Natural Gas Turbines 84 10200799 Industrial Boiler - Natural Gas 50 10200802 Industrial Boiler - PC 50 10200804 Cogeneration - Coal 50 10201001 Industrial Boiler - Natural Gas 50 10201002 Industrial Boiler - Natural Gas 50 10201402 Cogeneration - Coal 50 10300101 Industrial Boiler - PC 50 10300102 Industrial Boiler - Stoker - Overfeed 55 10300103 Industrial Boiler - PC 50 10300205 Industrial Boiler - PC - Wet 50 10300206 Industrial Boiler - PC - Dry 50 10300207 Industrial Boiler - Stoker - Overfeed 55 10300208 Industrial Boiler - Stoker 55 10300209 Industrial Boiler - Stoker - Spreader 55 10300211 Industrial Boiler - Stoker - Overfeed 55 10300217 Industrial Boiler - PC 50 10300221 Industrial Boiler - PC - Wet 50 10300222 Industrial Boiler - PC - Dry 50 10300224 Industrial Boiler - Stoker - Spreader 55 10300225 Industrial Boiler - Stoker - Overfeed 55 10300309 Industrial Boiler - Stoker - Spreader 55 10300401 Industrial Boiler - Residual Oil 50 10300402 Industrial Boiler - Residual Oil 50 17 ------- Table III-l Default NOx RACT Control Assumptions Default NOx RACT Control Efficiency see NOy RACT Control Group (Percent) 10300404 Industrial Boiler - Residual Oil 50 10300501 Industrial Boiler - Distillate Oil 50 10300502 Industrial Boiler - Distillate Oil 50 10300503 Industrial Boiler - Distillate Oil 50 10300504 Industrial Boiler - Distillate Oil 50 10300601 Industrial Boiler - Natural Gas 50 10300602 Industrial Boiler - Natural Gas 50 10300603 Industrial Boiler - Natural Gas 50 10300701 Industrial Boiler - Natural Gas 50 10300799 Industrial Boiler - Natural Gas 50 10301001 Industrial Boiler - Natural Gas 50 10301002 Industrial Boiler - Natural Gas 50 10500205 Process Heaters - Distillate Oil 74 10500206 Process Heaters - Natural Gas 75 10500210 Process Heaters - Other 74 20100101 Gas Turbines - Oil 68 20100102 IC Engines - Oil - Reciprocating 25 20100201 Gas Turbines - Natural Gas 84 20100202 IC Engines - Natural Gas - Reciprocating 30 20100702 Industrial Boiler - Other 50 20100801 Industrial Boiler - Other 50 20100802 Industrial Boiler - Other 50 20100901 Industrial Boiler - Other 50 20200101 Gas Turbines - Oil 68 20200102 IC Engines - Oil - Reciprocating 25 20200103 Cogeneration - Oil Turbines 68 20200104 Cogeneration - Oil Turbines 68 20200201 Gas Turbines - Natural Gas 84 20200202 IC Engines - Natural Gas - Reciprocating 30 20200203 Cogeneration - Natural Gas Turbines 84 20200204 Industrial Cogeneration - Nat. Gas 50 18 ------- Table III-l Default NOx RACT Control Assumptions Default NOx RACT Control Efficiency see NOy RACT Control Group (Percent) 20200301 Industrial Boiler - Other 50 20200401 Industrial Boiler - Other 50 20200402 Industrial Boiler - Other 50 20200403 Cogeneration - Oil Turbines 68 20200501 IC Engines - Oil - Reciprocating 25 20200901 Industrial Boiler - Other 50 20200902 Industrial Boiler - Other 50 20201001 IC Engines - Natural Gas - Reciprocating 30 20201002 IC Engines - Natural Gas - Reciprocating 30 20300101 IC Engines - Oil - Reciprocating 25 20300102 Gas Turbines - Oil 68 20300201 IC Engines - Natural Gas - Reciprocating 30 20300202 Gas Turbines - Natural Gas 84 20300203 Cogeneration - Natural Gas Turbines 84 20300204 Cogeneration - Natural Gas Turbines 84 20300301 Industrial Boiler - Other 50 20301001 IC Engines - Natural Gas - Reciprocating 30 20400301 Gas Turbines - Natural Gas 84 20400302 Gas Turbines - Oil 68 20400401 IC Engines - Oil - Reciprocating 25 20400402 IC Engines - Oil - Reciprocating 25 30100101 Adipic Acid Manufacturing Plant 81 30101301 Nitric Acid Manufacturing Plant 95 30101302 Nitric Acid Manufacturing Plant 95 30190003 Process Heaters - Natural Gas 75 30190004 Process Heaters - Natural Gas 75 30390001 Process Heaters - Distillate Oil 74 30390003 Process Heaters - Natural Gas 75 30390004 Process Heaters - Other 74 30490001 Process Heaters - Distillate Oil 74 30490003 Process Heaters - Natural Gas 75 19 ------- Table III-l Default NOx RACT Control Assumptions Default NOx RACT Control Efficiency see NOy RACT Control Group (Percent) 30490004 Process Heaters - Other 74 30590001 Process Heaters - Distillate Oil 74 30590002 Process Heaters - Residual Oil 73 30590003 Process Heaters - Natural Gas 75 30600101 Process Heaters - Distillate Oil 74 30600102 Process Heaters - Natural Gas 75 30600103 Process Heaters - Distillate Oil 74 30600104 Process Heaters - Natural Gas 75 30600105 Process Heaters - Natural Gas 75 30600106 Process Heaters - Natural Gas 75 30600107 Process Heaters - Natural Gas 75 30600111 Process Heaters - Residual Oil 73 30600199 Process Heaters - Other 74 30790001 Process Heaters - Distillate Oil 74 30790002 Process Heaters - Residual Oil 73 30790003 Process Heaters - Natural Gas 75 30890003 Process Heaters - Natural Gas 75 30990001 Process Heaters - Distillate Oil 74 30990002 Process Heaters - Residual Oil 73 30990003 Process Heaters - Natural Gas 75 31000401 Process Heaters - Distillate Oil 74 31000403 Process Heaters - Residual Oil 73 31000404 Process Heaters - Natural Gas 75 31000405 Process Heaters - Natural Gas 75 31390003 Process Heaters - Natural Gas 75 39990001 Process Heaters - Distillate Oil 74 39990002 Process Heaters - Residual Oil 73 39990003 Process Heaters - Natural Gas 75 39990004 Process Heaters - Natural Gas 75 40201001 Process Heaters - Natural Gas 75 40201002 Process Heaters - Distillate Oil 74 20 ------- Table III-l Default NOx RACT Control Assumptions Default NOx RACT see NOy RACT Control Group Control Efficiency (Percent) 40201003 Process Heaters - Residual Oil 73 40201004 Process Heaters - Natural Gas 75 21 ------- Table III-2 Default Boiler Capacity Data From the NET Boiler Daily NOx (tpd) Mean Median Capacity of Boiler with Boiler Boiler Closest to Capacity 6-Digit Capacity Capacity 250 Closest to 250 see (MMBtu/hr) (MMBtu/hr) MMBtu/hr MMBtu/hr 102001 75.97 55 264 2.6597 102002 236.65 150 250 0.7282 102003 150.44 58 87 0.4796 102004 393.35 73 250 0.3292 102005 299.63 80 250 0.1365 102006 251.96 86 250 0.2127 102007 268.49 198 250 0.1313 102008 515.30 420 241 1.0534 102009 348.64 132 250 0.2103 102010 123.57 45 224 0.0848 102011 193.00 193 193 0.1606 102012 252.00 180 246 0.4668 102013 194.81 172 250 0.0351 102014 287.62 297 267 0.1636 103001 49.45 43 137 0.2052 103002 90.28 74 248 1.1403 103003 85.00 93 101 0.1194 103004 113.01 59 245 0.0417 103005 89.05 71 249 0.0468 103006 152.38 97 249 0.0468 103007 211.00 197 197 0.7150 103009 65.18 66 166 0.0132 103010 138.00 138 138 0.0179 103012 240.33 75 200 0.5335 103013 93.45 59 250 0.5194 202001 228.87 62 276 1.2046 202002 294.62 9 271 0.5596 202005 62.00 62 62 0.1882 202009 70.00 70 70 0.3557 203001 75.00 35 256 8.0303 203002 29.47 8 197 0.7150 22 ------- Table III-3 Budget Reduction Levels From Uncontrolled Emissions Budget Reduction Source Category Percentage ICI Boilers* - Coal/Wall 60 ICI Boilers - Coal/FBC 60 ICI Boilers - Coal/Stoker 60 ICI Boilers - Coal/Cyclone 60 ICI Boilers - Residual Oil 60 ICI Boilers - Distillate Oil 60 ICI Boilers - Natural Gas 60 ICI Boilers - Process Gas 60 ICI Boilers - LPG 60 ICI Boilers - Coke 60 Gas Turbines - Oil 60 Gas Turbines - Natural Gas 60 Gas Turbines - Jet Fuel 60 Internal Combustion Engines - Oil 90 Internal Combustion Engines - Gas 90 Internal Combustion Engines - Gas, Diesel, LPG 90 Cement Manufacturing - Dry 30 Cement Manufacturing - Wet 30 In-Process; Bituminous Coal; Cement Kiln 30 * Industrial/Commercial/Institutional Boilers 23 ------- Table III-4 Base and Budget Ozone Season NOx Emissions Non-EGU Point Sources State 1995 Base 2007 Base 2007 Budget Reduction Alabama 49,515 60,465 43,415 28% Connecticut 5,221 5,397 5,216 3% Delaware 2,313 2,821 2,473 12% District of Columbia 398 300 282 6% Georgia 28,926 37,245 29,716 20% Illinois 71,316 70,948 59,577 16% Indiana 57,837 69,011 47,363 31% Kentucky 23,843 29,486 25,669 13% Maryland 15,988 16,216 12,585 22% Massachusetts 11,801 11,210 10,298 8% Michigan 58,938 68,801 60,055 13% Missouri 24,297 25,964 21,602 17% New Jersey 15,733 15,975 15,464 3% New York 29,997 32,678 25,477 22% North Carolina 27,397 33,114 26,434 20% Ohio 42,250 50,001 40,194 20% Pennsylvania 75,827 82,107 70,132 15% Rhode Island 1,611 1,635 1,635 0% South Carolina 27,228 37,960 27,787 27% Tennessee 41,286 53,262 39,636 26% Virginia 37,955 42,108 35,216 16% West Virginia 27,169 24,473 20,238 17% Wisconsin 18,431 23,734 19,853 16% Total * 695,277 794,911 640,317 19% * Totals may not sum due to rounding. 24 ------- This page intentionally left blank 25 ------- Chapter IV Stationary Area and Nonroad Source Emissions A. Development of 1995 Base Year Emissions The stationary area and nonroad mobile source emissions were derived from data sets originating with the OTAG 1990 base year inventory. These base year inventories were prepared with 1990 State ozone nonattainment SIP emission inventories supplemented with either other State inventory data, if available, or the NET data, if State data were not available. The OTAG 1990 nonroad emission inventories were based primarily on estimates of 1990 nonroad emissions found in the 1995 NET. The area and nonroad mobile source inventory data for 1990 were then grown to 1995 using BEA historical growth estimates of industrial earnings at the State 2-digit SIC level. The initial starting set of 1995 base year emission estimates were in the form of typical ozone season daily emission estimates. Base year seasonal emissions were developed by multiplying these typical ozone season daily emissions by the 153 days in the season. B. 2007 Base Case The 1995 area and nonroad emissions were projected to 2007 using BEA projections of GSP at the 2-digit SIC level and supplemented with growth rates provided by State and local agencies. Because these source categories do not generally report SICs, an SIC-SCC cross- reference file was used to apply these factors. Emissions reductions from certain nonroad mobile controls were included in the 2007 base case. These control programs include the Federal Small Engine Standards, Phase II; Federal Marine Engine Standards (for diesel engines of greater than 50 horsepower); Federal Locomotive Standards; and the Nonroad Diesel Engine Standards. Appendix A presents the stationary area and nonroad mobile control measures included in the 2007 base case. Seasonal 2007 base case emissions were calculated by multiplying the 1995 seasonal base year emissions by the applicable growth rate and emission reductions for 2007. A description of the file structure for the county-level stationary area and nonroad mobile source emissions and growth is provided in Appendices E and F of this document. C. 2007 Budget Case For stationary area and nonroad mobile sources, 2007 base case emissions were used for the budget case. No additional emissions reductions (beyond those in the 2007 base case) were applied to these sources. 26 ------- D. Stationary Area and Nonroad Emission Summary Table IV-1 is a State-level summary of the seasonal stationary area and nonroad mobile data. It contains five month ozone season NOx emissions for the 1995 base year and 2007 base and budget cases (which are the same for these sources). 27 ------- Table IV-1 Base and Budget Ozone Season NOx Emissions (Tons) Stationary Area and Nonroad Mobile 1995 1995 2007 2007 Stationary Nonroad Stationary Nonroad State Area Mobile Area Mobile Alabama 24,247 29,497 28,762 20,146 Connecticut 4,258 13,101 4,821 10,736 Delaware 1,728 5,334 1,129 5,651 District of Columbia 838 1,924 830 3,135 Georgia 10,694 37,007 13,212 26,467 Illinois 9,845 78,783 9,369 56,724 Indiana 18,009 44,942 29,070 26,494 Kentucky 25,711 20,001 31,807 15,025 Maryland 4,055 20,463 4,448 20,026 Massachusetts 9,984 25,662 11,048 20,166 Michigan 22,289 35,899 31,721 26,935 Missouri 6,540 36,256 7,341 20,829 New Jersey 10,602 30,629 12,431 23,565 New York 17,294 48,675 17,423 42,091 North Carolina 9,330 30,744 11,067 22,005 Ohio 16,899 62,715 21,860 43,380 Pennsylvania 15,002 50,303 17,842 30,571 Rhode Island 373 3,076 448 2,455 South Carolina 6,748 18,829 9,415 14,637 Tennessee 9,881 66,783 13,333 52,920 Virginia 21,301 35,786 27,738 27,859 West Virginia 5,358 15,471 5,459 10,433 Wisconsin 9,111 25,772 11,253 17,965 Total 260,097 737,652 321,827 540,215 28 ------- This page intentionally left blank. 29 ------- Chapter V Highway Vehicle Source Emissions A. Development of 1995 Base Year Emissions The 1995 base year highway vehicle emissions inventory was developed from data sets originating with annual 1995 VMT levels from the Federal Highway Administrations (FHWA) Highway Performance Monitoring System (HPMS). These data are specified by State, HPMS vehicle type, and roadway type. The VMT data were then supplemented with data provided by the States. These data were distributed from a statewide level to a county level using population data from the 1990 census. The data were then apportioned from the HPMS vehicle categories to EPA vehicle types using data provided by EPA's Office of Mobile Sources. The 1995 emissions inventories reflect the type and extent of inspection and maintenance programs (I/M) in effect as of that year and the extent of the Federal reformulated gasoline program. The 1995 highway vehicle emission factors were based on EPA's MOBILE5b emission factor model with corrected default inputs. The 1995 highway vehicle emissions were calculated at the county level using the 1995 VMT and applicable emissions factors. Highway vehicle emission factors were modeled for each month in the ozone season (May-September) for each unique type of mobile source control area within a State. The file XREFV5, listed in Appendix H, provides the MOBILE5b file used for each county. This file also indicates the files used to determine vehicle speed input to MOBILE5b for each county. A blank in the column SPEEDSCC denotes the use of the EPA default speeds. These default speeds can be found in Table V-l. Additional columns in XREFV5 show the RVP modeled, I/M flags and files, REG (2=yes, l=no), and other relevant data input to MOBILE5b for each county. State-specific monthly average minimum and maximum daily temperatures were used in calculating highway vehicle emissions factors. Temperature data over the period from 1970 to 1997 were used in calculating the average temperatures. These temperature data were obtained from the National Climatic Data Center. Table V-2 presents the monthly temperatures by State. The 1995 base year emissions include the effects of so-called "defeat devices" on highway heavy-duty diesel engines. These devices cause engines to function differently when in actual use than they do when being tested for emissions according to the Federal Test Procedure. Under certain operating conditions typical of actual use, the computer software in these engines cause them to function in a way that reduces the effectiveness of the engines' emission control systems compared to how the engines operate when being tested for emissions according to the Federal Test Procedure. In essence, the computer software alters the fuel injection timing when the engine operates in certain modes (such as highway driving), causing the engine to emit higher levels of NOx than suggested by their certification standards or by EPA's existing emission models. At the time of proposal of the NOx SIP Call, EPA had not yet completed its evaluation of 30 ------- the impact of these defeat devices on NOx emissions. As a result, EPA did not include the excess emissions from their use in the SIP Call emissions inventories. Since that time, EPA has completed its evaluation and entered into proposed consent decrees with the manufacturers of diesel engines equipped with these devices. The effects of the heavy duty excess are included in the emissions inventories by applying correction factors to the MOBILE5b highway vehicle emissions factors. Additional information regarding the defeat device consent decrees can be found at 63 FR 59330-59334 (November 3, 1998, Notices of Filing of Consent Decree under the Clean Air Act). B. 2007 Base Case The EPA used the growth methods developed by OTAG for the purpose of projecting VMT growth from 1995 and 2007. VMT growth factors were developed using data from the MOBILE4.1 Fuel Consumption Model. This model estimates national VMT by vehicle type through the year 2020. To calculate the VMT growth factors, the 1995 and 2007 Fuel Consumption Model VMT were first allocated to MS As and "rest-of-state" areas using 1995 population and projected 2007 population estimates, respectively. The VMT growth factors were calculated by vehicle type as the ratio of the 2007 VMT to the 1995 VMT for each MSA and rest-of-state area. The 1995 county annual VMT were projected to 2007 using the VMT growth factors. These annual projections were allocated to each for the four seasons using seasonal temporal factors. Monthly VMT data were then obtained using a ratio between the number of days in a month and the number of days in the corresponding season. The VMT for the months of May, June, July, August, and September were then summed to determine the ozone season total VMT. The 2007 highway vehicle emissions were calculated by multiplying the county-specific 2007 monthly VMT by MOBILE5b emissions factors calculated for 2007. Highway vehicle controls included county-specific I/M programs, reformulated gasoline in mandated and opt-in areas, Phase 2 RVP elsewhere, the new heavy duty engine standard, and National Low Emission Vehicle (NLEV)program. The NLEV implementation schedule modeled for each county is found in XREFV5. Areas with NOx waivers that have a high enhanced I/M programs were modeled without a NOx cutpoint in their I/M program (i.e., the NOx cutpoint was modeled as 999). Appendix A presents the highway vehicle control measures included in the 2007 base case. The effects on emissions of the heavy-duty vehicle defeat devices peaks in the late 1990s and then declines rapidly as newer engines that would not be equipped with defeat devices replace defeat device-equipped engines and as manufacturers undertake the mitigation commitments required under the proposed consent decrees. The 2007 base case emissions include the effects of defeat devices and the commitments made by diesel engine manufacturers in the settlement to introduce diesel engines meeting the 2004 standards prior to 2004. Table V-3 presents the defeat device correction factors used in the 2007 base case calculation. A description of the file structure for monthly 2007 base county-level highway vehicle 31 ------- VMT and emissions is provided in Appendix G of this document. C. 2007 Budget Case Highway vehicle emissions from the 2007 base case were used in the budget case inventory. No additional reductions (beyond those in the 2007 base case) were applied to the budget highway vehicle emissions. D. Highway Vehicle Emission Summary Table V-4 is a State-level summary of the seasonal highway vehicle data. It contains five month ozone season VMT and NOx emissions for the 2007 base and the budget case with the heavy duty diesel excess emissions. 32 ------- Table V-l Average Speeds by Road Type and Vehicle Type Rural Road Speeds (MPH) Vehicle Type" Interstate Principal Arterial Minor Arterial Major Collector Minor Collector Local LDV 60 45 40 35 30 30 LDT 55 45 40 25 30 30 HDV 40 35 30 25 25 25 Urban Road Speeds (MPH) Vehicle Type" Interstate Principle Arterial Minor Arterial Major Collector Minor Collector Local LDV 45 45 20 20 20 20 LDT 45 45 20 20 20 20 HDV 35 35 15 15 15 15 ^Vehicle Type: LDV - light duty vehicles; LDT - light duty trucks; HDV - heavy duty vehicles. ------- Table V-2 Historical Statewide Average Monthly Minimum and Maximum Temperatures (Degrees Fahrenheit) May May June June July July August August September September State Max Min Max Min Max Min Max Min Max Min Alabama 80.8 57.9 87.4 65.7 90.5 70.0 89.8 69.2 84.5 63.3 Connecticut 71.9 49.0 80.0 57.0 85.0 62.6 82.7 60.8 74.3 52.1 Delaware 74.9 53.3 83.0 61.9 87.5 67.5 85.9 66.1 79.7 59.2 DC 75.9 56.4 84.5 65.9 88.7 71.1 86.7 69.4 80.0 62.7 Georgia 79.9 59.3 86.4 66.9 89.3 70.6 87.7 69.9 82.4 64.5 Illinois 74.6 52.5 83.8 61.9 87.0 66.0 84.7 64.0 78.3 55.6 Indiana 73.4 51.9 82.2 61.4 85.6 65.5 83.8 63.6 77.3 55.6 Kentucky 76.0 55.3 84.1 64.3 87.8 68.6 86.4 67.2 79.8 60.0 Maryland 74.2 52.8 83.1 62.1 87.5 67.5 85.6 65.9 78.7 59.0 Massachusetts 66.8 50.2 76.7 59.4 82.3 65.5 80.3 64.6 72.5 56.8 Michigan 69.8 50.1 78.8 59.8 83.3 65.2 81.0 63.5 73.3 56.1 Missouri 75.3 53.5 84.3 62.3 89.4 66.9 88.7 65.7 80.0 57.9 New Jersey 72.6 54.1 81.4 63.6 86.3 69.4 84.6 68.0 76.9 60.1 New York 70.4 54.1 79.2 63.6 84.5 69.4 82.9 68.6 75.1 61.4 North Carolina 76.8 54.6 83.8 63.3 87.7 67.9 85.6 66.5 79.6 60.2 Ohio 72.4 50.5 80.8 59.5 84.5 64.0 83.0 62.5 76.1 55.3 Pennsylvania 72.4 51.6 80.9 60.9 85.7 66.2 83.8 64.7 75.9 56.9 Rhode Island 68.4 48.7 77.2 57.8 82.5 64.3 81.0 62.8 73.3 54.4 South Carolina 83.5 58.4 89.2 66.4 92.5 70.7 90.2 69.7 85.5 64.0 Tennessee 78.4 56.6 86.0 65.0 89.6 69.4 88.5 68.2 82.3 61.5 Virginia 77.7 54.6 85.4 63.2 89.2 68.4 87.2 66.8 81.3 60.0 West Virginia 75.0 51.8 81.8 60.0 85.9 65.5 84.3 63.6 77.9 56.8 Wisconsin 65.1 45.8 75.5 56.3 80.5 62.8 78.5 62.0 70.9 54.0 ------- Table V-3 Adjustment Factor for 2007 MOBILE5 Emission Factors to Account for Defeat Devices and the Pull-Ahead of the 2 g/bhp-hr Standard Speed Facility Description 5 10 15 20 25 30 35 40 45 50 55 60 65 Interstate Rural Interstate 0.9953 1.0872 1.1754 1.2525 1.3114 1.3463 1.3538 1.3329 1.2858 1.2174 1.1341 1.0432 0.9518 Interstate Rural Other Prin Arterial 0.9953 1.0873 1.1754 1.2525 1.3114 1.3464 1.3538 1.3329 1.2859 1.2174 1.1341 1.0433 0.9518 Interstate Urban Interstate 0.9955 1.0878 1.1764 1.2538 1.3130 1.3481 1.3555 1.3346 1.2873 1.2186 1.1349 1.0436 0.9518 Interstate Urban Other Freeways 0.9953 1.0874 1.1757 1.2528 1.3118 1.3468 1.3543 1.3334 1.2863 1.2177 1.1343 1.0433 0.9518 Arterial Rural Minor Arterial 0.9713 1.0012 1.0299 1.0550 1.0741 1.0855 1.0879 1.0811 1.0658 1.0436 1.0165 0.9869 0.9572 Arterial Rural Major Collector 0.9713 1.0012 1.0299 1.0549 1.0741 1.0854 1.0878 1.0811 1.0658 1.0435 1.0164 0.9869 0.9572 Arterial Rural Minor Collector 0.9712 1.0008 1.0291 1.0539 1.0729 1.0841 1.0865 1.0798 1.0646 1.0426 1.0159 0.9866 0.9572 Arterial Rural Local 0.9715 1.0015 1.0303 1.0555 1.0747 1.0861 1.0885 1.0817 1.0664 1.0440 1.0168 0.9872 0.9573 Urban Urban Other Prin Arterial 0.9660 0.9678 0.9695 0.9710 0.9722 0.9729 0.9730 0.9726 0.9717 0.9704 0.9687 0.9670 0.9652 Urban Urban Minor Arterial 0.9659 0.9677 0.9694 0.9709 0.9721 0.9727 0.9729 0.9725 0.9716 0.9702 0.9686 0.9668 0.9651 Urban Urban Collector 0.9662 0.9680 0.9697 0.9712 0.9724 0.9731 0.9732 0.9728 0.9719 0.9705 0.9689 0.9671 0.9653 Urban Urban Local 0.9658 0.9676 0.9693 0.9708 0.9720 0.9727 0.9728 0.9724 0.9715 0.9701 0.9685 0.9667 0.9649 35 ------- Table V-4 VMT and 2007 Budget Ozone Season NOx Emissions Highway Vehicle Seasonal Final Budget With 2007 VMT HDD Excess State (thousands) (tons/season) Alabama 23,642 51,274 Connecticut 14,960 19,424 Delaware 4,207 8,358 District of Columbia 1,944 2,204 Georgia 49,822 88,775 Illinois 52,897 112,518 Indiana 33,843 79,307 Kentucky 24,590 53,268 Maryland 24,840 30,183 Massachusetts 23,207 28,190 Michigan 40,187 78,763 Missouri 31,772 51,615 New Jersey 32,442 35,166 New York 68,689 124,261 North Carolina 42,240 73,695 Ohio 52,640 94,850 Pennsylvania 47,953 91,578 Rhode Island 3,614 3,843 South Carolina 22,025 54,494 Tennessee 31,546 66,342 Virginia 38,787 72,195 West Virginia 9,161 20,844 Wisconsin 28,561 69,319 Total * 703,569 1,310,466 * Totals may not sum due to rounding. 36 ------- This page intentionally left blank 37 ------- Chapter VI Statewide NOx Budgets The Statewide base case and budget emissions were calculated by summing the individual base case and budget emissions components. Table VI-1 shows the seasonal Statewide base case and budget NOx emissions and the percent reduction between the base case and the budget. Table VI-2 presents the base and budget cases by major source category component. 38 ------- Table VI-1 Seasonal Statewide NOx Base and Budgets (Tons/Season) State Final Base Final Budget Reduction Alabama 237,573 172,619 27% Connecticut 46,015 42,849 7% Delaware 23,798 22,861 4% District of Columbia 6,471 6,658 -3% Georgia 252,154 188,572 25% Illinois 368,870 270,560 27% Indiana 340,654 229,965 32% Kentucky 237,415 162,272 32% Maryland 103,476 81,898 21% Massachusetts 87,092 84,848 3% Michigan 292,820 229,702 22% Missouri 187,845 125,603 33% New Jersey 105,489 96,876 8% New York 255,653 240,288 6% North Carolina 224,697 165,022 27% Ohio 373,223 249,274 33% Pennsylvania 345,201 257,592 25% Rhode Island 9,463 9,378 1% South Carolina 152,805 123,105 19% Tennessee 256,765 198,045 23% Virginia 210,784 180,195 15% West Virginia 176,699 83,833 53% Wisconsin 174,234 135,771 22% Total 4,469,196 3,357,786 25% 39 ------- Table VI-2 Seasonal Statewide NOx Base and Budgets by Major Source Category (Tons/Season) 2007 Base NOx Emissions (tons/season) 2007 Budget NOx Emissions (tons/season) State EGU Non-EGU Area Nonroad Highway Total EGU Non-EGU Area Nonroad Highway Total Alabama 76,926 60,465 28,762 20,146 51,274 237,573 29,022 43,415 28,762 20,146 51,274 172,619 Connecticut 5,636 5,397 4,821 10,736 19,424 46,015 2,652 5,216 4,821 10,736 19,424 42,849 Delaware 5,838 2,821 1,129 5,651 8,358 23,798 5,250 2,473 1,129 5,651 8,358 22,861 District of Columbia 3 300 830 3,135 2,204 6,471 207 282 830 3,135 2,204 6,658 Georgia 86,455 37,245 13,212 26,467 88,775 252,154 30,402 29,716 13,212 26,467 88,775 188,572 Illinois 119,311 70,948 9,369 56,724 112,518 368,870 32,372 59,577 9,369 56,724 112,518 270,560 Indiana 136,773 69,011 29,070 26,494 79,307 340,654 47,731 47,363 29,070 26,494 79,307 229,965 Kentucky 107,829 29,486 31,807 15,025 53,268 237,415 36,503 25,669 31,807 15,025 53,268 162,272 Maryland 32,603 16,216 4,448 20,026 30,183 103,476 14,656 12,585 4,448 20,026 30,183 81,898 Massachusetts 16,479 11,210 11,048 20,166 28,190 87,092 15,146 10,298 11,048 20,166 28,190 84,848 Michigan 86,600 68,801 31,721 26,935 78,763 292,820 32,228 60,055 31,721 26,935 78,763 229,702 Missouri 82,097 25,964 7,341 20,829 51,615 187,845 24,216 21,602 7,341 20,829 51,615 125,603 New Jersey 18,352 15,975 12,431 23,565 35,166 105,489 10,250 15,464 12,431 23,565 35,166 96,876 New York 39,199 32,678 17,423 42,091 124,261 255,653 31,036 25,477 17,423 42,091 124,261 240,288 North Carolina 84,815 33,114 11,067 22,005 73,695 224,697 31,821 26,434 11,067 22,005 73,695 165,022 Ohio 163,132 50,001 21,860 43,380 94,850 373,223 48,990 40,194 21,860 43,380 94,850 249,274 Pennsylvania 123,102 82,107 17,842 30,571 91,578 345,201 47,469 70,132 17,842 30,571 91,578 257,592 Rhode Island 1,082 1,635 448 2,455 3,843 9,463 997 1,635 448 2,455 3,843 9,378 South Carolina 36,299 37,960 9,415 14,637 54,494 152,805 16,772 27,787 9,415 14,637 54,494 123,105 Tennessee 70,908 53,262 13,333 52,920 66,342 256,765 25,814 39,636 13,333 52,920 66,342 198,045 Virginia 40,884 42,108 27,738 27,859 72,195 210,784 17,187 35,216 27,738 27,859 72,195 180,195 West Virginia 115,490 24,473 5,459 10,433 20,844 176,699 26,859 20,238 5,459 10,433 20,844 83,833 Wisconsin 51,962 23,734 11,253 17,965 69,319 174,234 17,381 19,853 11,253 17,965 69,319 135,771 Total 1,501,775 794,911 321,827 540,215 1,310,466 4,469,196 544,961 640,317 321,827 540,215 1,310,466 3,357,786 ------- References DOE, 1995a: U.S. Department of Energy, Energy Information Administration, "Steam-Electric Plant Operation and Design Report, "Form EIA-767, 1995. DOE, 1995b: U.S. Department of Energy, Energy Information Administration, "Annual Electric Generator Report," Form EIA-860, 1995. DOE, 1995c: U.S. Department of Energy, Energy Information Administration, "Annual Nonutility Power Producers Report, "Form EIA-867, 1995. EPA, 1997b: U.S. Environmental Protection Agency, Data files received from EPA Acid Rain Division, Washington DC, December 1997. EPA, 1997c: U.S. Environmental Protection Agency, "National Air Pollutant Emission Trends, 1900- 1996, " EPA-454/R-97-011, Research Triangle Park, NC, December, 1997. EPA, 1998a: U.S. Environmental Protection Agency, "Responses to Significant Comments on the Proposed Finding of Significant Contribution and Rulemaking for Certain States in the Ozone Transport Assessment Group (OTAG) Region for Purposes of Reducing Regional Transport of Ozone (62 FR 60318, November 7,1997 and 63 FR 25902, May 11, 1998), " Docket A-96-56, VI- C-01, September, 1998. EPA, 1998b: U.S. Environmental Protection Agency, "Technical Support Document for Municipal Waste Combustors (MWCs), " Docket A-96-56, VI-B-12, September, 1998. EPA, 1998c: U.S. Environmental Protection Agency, "Regulatory Impact Analysis for the Regional N0X SIP Call," Docket A-96-56, VI-B-09, September, 1998. EPA, 1999: U.S. Environmental Protection Agency, "Responses to the 2007 Baseline Sub-Inventory Information and Significant Comments for the Final NOx SIP Call (63 FR 57356, October 27, 1998), " Docket A-96-56, X-C-01, May, 1999. EPA, 1999b: U.S. Environmental Protection Agency, "Responses to the 2007 Baseline Sub-Inventory Information and Significant Comments for the Final NOx SIP Call and Proposed Rulemakings for Section 126 Petitions and Federal Implementation Plans - Technical Amendment Version, " December, 1999. Pechan, 1997a: E.H. Pechan & Associates, Inc., "Ozone Transport Assessment Group (OTAG) Emissions Inventory Development Report - Volume I: 1990 Base Year Development, " (revised draft) prepared for U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards, Research Triangle Park, NC, February, 1997. Pechan, 1997b: E.H. Pechan & Associates, Inc., "Ozone Transport Assessment Group (OTAG) Emissions Inventory Development Report - Volume III: Projections and Controls, " (draft) prepared for U.S. Environmental Protection Agency, Office of Air Quality Planning and Standards, Research Triangle Park, NC, June, 1997. Pechan, 1997c: E.H. Pechan & Associates, Inc., "The Acid Rain Data Base for 1996 (ARDB96) Technical Support Document, " (draft) prepared for U.S. Environmental Protection Agency, Office of Atmospheric Programs, September 1997. ------- This page intentionally left blank ------- APPENDIX A 2007 BASE CASE CONTROLS ------- Table A-l 2007 Base Case Controls EGU - Title IV Controls [ phase 1 & 2 ] - 250 Ton PSD and NSPS - RACT & NSR in non-waived NAAs Non-EGU Point Stationary Area Nonroad Mobile Highway Vehicles - NOx RACT on major sources in non-waived NAAs - CTG & Non-CTG VOC RACT at major sources in NAAs & OTR - NOx MACT standards to municipal waste combustors (MWCs) - Two Phases of VOC Consumer and Commercial Products & One Phase of Architectural Coatings controls - VOC Stage 1 & 2 Petroleum Distribution Controls in NAAs - VOC Autobody, Degreasing & Dry Cleaning controls in NAAs - Fed Phase II Small Eng. Stds - Fed Marine Eng. Stds. - Fed Nonroad Heavy-Duty (>=50 hp) Engine Stds - Phase 1 - Fed RFGII (statutory and opt-in areas) - 9.0 RVP maximum elsewhere in OTAG domain - Fed Locomotive Stds (not including rebuilds) - Fed Nonroad Diesel Engine Stds - Phases 2 & 3 - On-board vapor recovery - National LEV - Fed RFG II (statutory and opt-in areas) - Phase II RVP limits elsewhere in OTAG domain - High Enhanced, Low Enhanced, or Basic I/M in areas specified by State - Clean Fuel Fleets (mandated NAAs) - HDV 2 gm std ------- APPENDIX B NON-EGU POINT SOURCE CONTROL CATEGORY CODES ------- Table B-l Non-EGU Point Source Category Codes and Descriptions POD' Source Category 0 No Match 11 ICI Boilers - Coal/Wall 12 ICI Boilers - Coal/FBC 13 ICI Boilers - Coal/Stoker 14 ICI Boilers - Coal/Cyclone 15 ICI Boilers - Residual Oil 16 ICI Boilers - Distillate Oil 17 ICI Boilers - Natural Gas 18 ICI Boilers - Wood/Bark/Stoker 19 ICI Boilers - Wood/Bark/FBC 20 ICI Boilers - MSW/Stoker 21 Internal Combustion Engines - Oil 22 Internal Combustion Engines - Gas 23 Gas Turbines - Oil 24 Gas Turbines - Natural Gas 25 Process Heaters - Distillate Oil 26 Process Heaters - Residual Oil 27 Process Heaters - Natural Gas 28 Adipic Acid Manufacturing 29 Nitric Acid Manufacturing 30 Glass Manufacturing - Container 31 Glass Manufacturing - Flat 32 Glass Manufacturing - Pressed 33 Cement Manufacturing - Dry 34 Cement Manufacturing - Wet 35 Iron & Steel Mills - Reheating 36 Iron & Steel Mills - Annealing 37 Iron & Steel Mills - Galvanizing 38 Municipal Waste Combustors 39 Medical Waste Incinerators 40 Open Burning 41 ICI Boilers - Process Gas 42 ICI Boilers - Coke 43 ICI Boilers - LPG 44 ICI Boilers - Bagasse 45 ICI Boilers - Liquid Waste 46 IC Engines - Gas, Diesel, LPG 47 Process Heaters - Process Gas 48 Process Heaters - LPG 49 Process Heaters - Other Fuel 50 Gas Turbines - Jet Fuel 51 Engine Testing - Natural Gas 52 Engine Testing - Diesel GT ------- Table B-l Non-EGU Point Source Category Codes and Descriptions POD" Source Category 53 Engine Testing - Oil IC 54 Space Heaters - Distillate Oil 55 Space Heaters - Natural Gas 56 Ammonia - NG-Fired Reformers 57 Ammonia - Oil-Fired Reformers 58 Lime Kilns 59 Comm./Inst. Incinerators 60 Indust. Incinerators 61 Sulfate Pulping - Recovery Furnaces 62 Ammonia Prod; Feedstock Desulfurization 63 Plastics Prod-Specific; (ABS) Resin 64 Starch Mfg; Combined Operations 65 By-Product Coke Mfg; Oven Underfiring 66 Pri Cop Smel; Reverb Smelt Furn 67 Iron Prod; Blast Furn; Blast Htg Stoves 68 Steel Prod; Soaking Pits 69 Fuel Fired Equip; Process Htrs; Pro Gas 70 Sec Alum Prod; Smelting Furn/Reverb 71 Steel Foundries; Heat Treating Furn 72 Fuel Fired Equip; Furnaces; Natural Gas 73 Asphaltic Cone; Rotary Dryer; Conv Plant 74 Ceramic Clay Mfg; Drying 75 Coal Cleaning-Thrml Dryer; Fluidized Bed 76 Fbrglass Mfg; Txtle-Type Fbr; Recup Furn 77 Sand/Gravel; Dryer 78 Fluid Cat Cracking Units; Cracking Unit 79 Conv Coating of Prod; Acid Cleaning Bath 80 Natural Gas Prod; Compressors 81 In-Process; Bituminous Coal; Cement Kiln 82 In-Process; Bituminous Coal; Lime Kiln 83 In-Process Fuel Use;Bituminous Coal; Gen 84 In-Process Fuel Use; Residual Oil; Gen 85 In-Process Fuel Use; Natural Gas; Gen 86 In-Proc;Process Gas; Coke Oven/Blast Furn 87 In-Process; Process Gas; Coke Oven Gas 88 Surf Coat Oper;Coating Oven Htr;Nat Gas 89 Solid Waste Disp;Gov;Other Incin;Sludge * A POD is an grouping of sources categories for which a common control technology is applicable. ------- This page intentionally left blank ------- APPENDIX C SOURCE SPECIFIC EGU BUDGET EMISSIONS FILE ------- Table C-l Source Specific EGU Budget Emissions File Filename: NFRUT3 Description: Regional NOx SIP Call Budget Determination EGU Point Source File Variable Type Length Decimal Description ST C 2 0 State Abbreviation FIPSST c 2 0 FIPS State Code FIPSCNTY c 3 0 FIPS County Code PLANT c 45 0 Plant Name PLANTID c 15 0 Plant ID Code POINTID c 15 0 Point ID Code NAMEPLCAP N 8 2 Capacity (MW) of Largest Generator the Unit Serves FSIPHEAT N 15 4 Final Heat Input (mmBtu) Used to Calculate Budget (Based on Year to Use) F95HEAT N 15 4 1995 Ozone Season Heat Input (mmBtu) F96HEAT N 15 4 1996 Ozone Season Heat Input (mmBtu) FSIPNOXRT N 8 5 NOx Rate Used to Calculate Budget FSIPHTYR C 4 0 Year to Use for Heat Input to Calculate Individual State Budget F95NOXRT N 8 5 1995 NOx Emission Rate (lbs/mmBtu) F96NOXRT N 8 5 1996 NOx Emission Rate (lbs/mmBtu) NOX MASS N 15 4 2007 Ozone Season Budget NOx Emissions (pounds) ------- APPENDIX D SOURCE SPECIFIC NON-EGU POINT SOURCE BASE AND BUDGET EMISSIONS FILE ------- Table D-l Source Specific Non-EGU Point Source Base and Budget Emissions File Filename: NFRPT3 Description: Regional NOx SIP Call Non-EGU Point Source File Variable Type Length Decimal Description FIPSST C 2 0 FIPS State Code FIPSCNTY c 3 0 FIPS County Code PLANTID c 15 0 Plant ID Code PLANT c 40 0 Plant Name SIC N 4 0 Standard Industrial Classification Code POINTID c 15 0 Point ID Code STACKID c 15 0 Stack ID Code SEGMENT c 15 0 Segment ID see c 10 0 Source Classification Code POD c 3 0 Source Category Association SIZE c 1 0 Budget Size BOILCAP N 8 0 Boiler Design Capacity (MMBtu/hr) STKHGT N 4 0 Stack Height (ft) STKDIAM N 6 2 Stack Diameter (ft) STKTEMP N 4 0 Stack Temperature (degrees F) STKFLOW N 10 2 Stack Flow (cu. ft./min) STKVEL N 9 2 Stack Velocity (ft/sec) WINTHRU N 3 0 Winter Throughput Percentage SPRIHRU N 3 0 Spring Throughput Percentage SUMTHRU N 3 0 Summer Throughput Percentage FALTHRU N 3 0 Fall Throughput Percentage HOURS N 2 0 Operating Hours/Day DAYS N 1 0 Operating Days/Weeks WEEKS N 2 0 Operating Wccks/Year LATC N 9 4 Latitude (degrees) LONC N 9 4 Longitiude (degrees) NOXCE95 N 5 2 1995 NOx Control Efficiency NOXRE95 N 5 2 1995 NOx Rule Effectiveness DNOX95 N 16 4 1995 Typical Ozone Season Daily NOx Emissions (tons) SNOX95 N 16 4 1995 Ozone Season NOx Emissions (tons) GF9507 N 7 2 1995 - 2007 Growth Factor NOXCE07 N 5 2 2007 Base NOx Control Efficiency NOXRE07 N 5 2 2007 NOx Rule Effectiveness DNOX07 N 16 4 2007 Typical Ozone Season Daily NOx Emissions (tons) SNOX07 N 16 4 2007 Ozone Season Base NOx Emissions (tons) NOXCE07B N 5 2 2007 Budget NOx Control Efficiency DBNOX N 16 4 2007 Typical Ozone Season Daily Budget NOx Emissions (tons) SBNOX N 16 4 2007 Ozone Season Budget NOx Emissions (tons) ------- APPENDIX E COUNTY LEVEL STATIONARY AREA BASE AND BUDGET EMISSIONS FILE ------- Table E-l County Level Stationary Area Base and Budget Emissions File Filename: NFRAR3 Description: Regional NOx SIP Call Stationary Area Source File Variable Type Length Decimal Description FIPSST C 2 0 FIPS State Code FIPSCNTY c 3 0 FIPS County Code see c 10 0 Source Classification Code DNOX95 N 10 4 1995 Typical Ozone Season Daily NOx Emissions (tons) SNOX95 N 10 4 1995 Ozone Season NOx Emissions (tons) GR9507 N 7 3 1995 - 2007 Growth Factor NOXCE07 N 5 2 2007 Base NOx Control Efficiency NOXCRE07 N 5 2 2007 NOx Rule Effectiveness NOXRP07 N 5 2 2007 NOx Rule Penetration PUGR N 7 3 2007 Process Units Growth Rate SCF N 7 3 2007 Source Conversion Factor DNOX07 N 10 4 2007 Typical Ozone Season Daily NOx Emissions (tons) SNOX07 N 10 4 2007 Ozone Season NOx Emissions (tons) ------- APPENDIX F COUNTY LEVEL NONROAD MOBILE BASE AND BUDGET EMISSIONS FILE ------- Table E-l County Level Nonroad Mobile Base and Budget Emissions File Filename: NFRNR3 Description: Regional NOx SIP Call Nonroad Mobile Source File Variable Type Length Decimal Description FIPSST C 2 0 FIPS State Code FIPSCNTY c 3 0 FIPS County Code see c 10 0 Source Classification Code DNOX95 N 10 4 1995 Typical Ozone Season Daily NOx Emissions (tons) SNOX95 N 10 4 1995 Ozone Season NOx Emissions (tons) GR9507 N 7 3 1995 - 2007 Growth Factor NOXCE07 N 5 2 2007 Base NOx Control Efficiency NOXCRE07 N 5 2 2007 NOx Rule Effectiveness NOXRP07 N 5 2 2007 NOx Rule Penetration PUGR N 7 3 2007 Process Units Growth Rate SCF N 7 3 2007 Source Conversion Factor DNOX07 N 10 4 2007 Typical Ozone Season Daily NOx Emissions (tons) SNOX07 N 10 4 2007 Ozone Season NOx Emissions (tons) ------- APPENDIX G COUNTY LEVEL HIGHWAY VEHICLE BASE AND BUDGET EMISSIONS FILE ------- Table G-l County Level Highway Vehicle Base and Budget Emissions File Filename: NFRMB3 Description: Regional NOx SIP Call Highway Vehicle File Variable Tvoe Length Decimal DescriDtion FIPSST C 2 0 FIPS State Code FIPSCNTY C 3 0 FIPS County Code see c 10 0 Source Classification Code VTYPE c 5 0 Vehicle Type VOC07SEAS N 13 6 2007 Ozone Season VOC Emissions (tons) NOX07SEAS N 13 6 2007 Ozone Season NOx Emissions (tons) CO07SEAS N 13 6 2007 Ozone Season CO Emissions (tons) VOC07MAY N 13 6 2007 May VOC Emissions (tons) VOC07JUN N 13 6 2007 June VOC Emissions (tons) VOC07JUL N 13 6 2007 July VOC Emissions (tons) VOC07AUG N 13 6 2007 August VOC Emissions (tons) VOC07SEP N 13 6 2007 September VOC Emissions (tons) NOX07MAY N 13 6 2007 May NOx Emissions (tons) NOX07JUN N 13 6 2007 June NOx Emissions (tons) NOX07JUL N 13 6 2007 July NOx Emissions (tons) NOX07AUG N 13 6 2007 August NOx Emissions (tons) NOX07SEP N 13 6 2007 September NOx Emissions (tons) CO07MAY N 13 6 2007 May CO Emissions (tons) CO07JUN N 13 6 2007 June CO Emissions (tons) CO07JUL N 13 6 2007 July CO Emissions (tons) CO07AUG N 13 6 2007 August CO Emissions (tons) CO07SEP N 13 6 2007 September CO Emissions (tons) VMT07MAY N 16 3 2007 May VMT VMT07JUN N 16 3 2007 June VMT VMT07JUL N 16 3 2007 July VMT VMT07AUG N 16 3 2007 August VMT VMT07SEP N 16 3 2007 September VMT VMT07 SEAS N 16 3 2007 Ozone Season VMT ------- APPENDIX H MOBILE MODEL HIGHWAY VEHICLE COUNTY CORRESPONDENCE FILE ------- Table H-l Regional NOx SIP Call MOBILE Model Highway Vehicle County Correspondence File Format Filename: XREFV5 Description: Regional NOx SIP Call Highway Mobile Source File Variable Type Length Decimal Description FIPSST C 2 FIPS State code FIPSCNTY C 3 FIPS county code STATECD c 2 State abbreviation COUNTYNAME c 30 County name M5BFILE c 12 Name of MOBILE5b input file used to model county emission factors ASTM c 1 Fuel ASTM class (only needed when reformulated gasoline is modeled) SPDFLG c 1 Flag indicating whether user-supplied trip length distributions were modeled (l=MOBILE5b defaults, 3 or 4=user-supplied trip length distributions) MYMRFG c 1 Flag indicating whether user-supplied registration distributions and/or mileage accumulation rates were modeled (l=MOBILE5b defaults, 3=user-supplied registration distributions, 4=user-supplied registration distributions and mileage accumulation rates) IMFLAG c 1 Flag indicating whether I/M program modeled in county (l=no I/M, all other flag values indicate I/M program modeled) ATPFLG c 1 Flag indicating whether ATP, pressure, or purge tests were modeled for this county (l=no ATP, pressure, or purge, 2=ATP modeled, 5=ATP and pressure test modeled, 8=ATP, pressure, and purge tests modeled) SPDFILE c 10 Name of file containing trip length distribution modeled for this county MYMRFILE c 10 Name of file containing registration distributions and/or mileage accumulation rates modeled for this county IMATPFILE c 8 Name of file with I/M, ATP,pressure, and purge program inputs modeled in this county (EPA high enhanced performance standard = HEIMPS and NHEIMPS, EPA low enhanced performance standard = LEIMPS and NLEIMPS, EPA basic I/M performance standard = BSIMPS, NBS OPMODE c 16 Operating mode fractions (default = " 20.6 27.3 20.6 ") RVPJUL N 4 1 Fuel RVP value modeled (psi) REFORMFLG c 1 Reformulated gasoline flag: l=no RFG, 2=RFG OXYDAT c 21 Oxygenated/alcohol fuel data for county: ether blend market share, alcohol blend market share, oxygen content of ether blends, oxygen content of alcohol blends, RVP waiver switch (l=no RVP waiver, 2=1 psi RVP waiver) LEV_MINMAX c 1 Flag indicating whether minimum (1) or maximum (2) LEV credits were applied in this county LEVSTART c 2 Start year of LEV program in this county LEVIMPFILE c 12 LEV implementation schedule file used to run MOBILE5b for this county SPEEDSCC c 12 Name of file containing vehicle speeds modeled in this county (default file is SCCSPD.DBF) ------- |