oEPA United States Environmental Protection Agency THE EMISSIONS & GENERATION RESOURCE INTEGRATED DATABASE Technical Support Document for eGRID with Year 2018 Data eGR&> 2018 Office of Atmospheric Programs Clean Air Markets Division ------- eGRID2018 Technical Support Document Contract # EP- Task Order FINAL January 2020 ared for: Clean Air Markets Division Office of Atmospheric Programs ironmental Protection Agency Washington, DC 20460 Prepared by: Abt Associates 6130 Executive Blvd. Rockville, MD 20852 ------- NOTICES Notices This document has been reviewed by the Clean Air Markets Division (CAMD), Office of Atmospheric Programs (OAP), U.S. Environmental Protection Agency (EPA), and approved for distribution. Technical Support Document for eGR!D2018 ------- ACKNOWLEDGMENTS Acknowledgments This edition of eGRID was developed under the leadership of Mr. Travis Johnson and Dr. Jeremy Schreifels of EPA's Clean Air Markets Division (CAMD) and Dr. Jonathan Dorn, Ms. Marissa Hoer, Mr. David Cooley, and Ms. Kait Siegel of Abt Associates, Inc. The eGRID concept was originated by Mr. Rick Morgan, former EPA Senior Energy Analyst in EPA's Office of Atmospheric Programs, and historical development was led by Mr. Art Diem of EPA's Office of Air Quality Planning and Standards. Technical Support Document for eGR!D2018 ------- CONTENTS Contents Notices i Acknowledgments ii Contents iii Abbreviations and Acronyms vi 1. Introduction 10 2. Summary of eGRID2018 Data 11 2.1 eGRID Files 11 2.2 What's New in eGRID 12 2.3 Uses and Users of eGRID 13 2.4 eGRID Data Sources 16 3. eGRID Methodology 17 3.1 Estimation of Emissions 17 3.1.1 Unit Level and Plant Level Unadjusted Emission Estimates 18 3.1.1.1 Annual Emission Estimates for CO2, NOx, and SO2 18 3.1.1.2 Annual Emission Estimates for CH4, N2O, and CO2 equivalent 20 3.1.1.3 Annual Emission Estimates for Mercury 21 3.1.2 Plant Level Adjusted Emission Estimates 22 3.1.2.1 Adjustments for Biomass 22 3.1.2.2 Adjustments for CHP 23 3.1.2.3 Plant-level adjustment example calculation 25 3.1.3 Emission Rate Estimates 26 3.1.3.1 Generation 26 3.1.3.2 Heat Input 27 3.1.3.3 Emission Rates 27 3.2 Determination of Plant Primary Fuel 29 3.3 Estimation of Resource Mix 29 3.4 Aggregating Plant-Level Data 30 3.4.1 Balancing Authority 30 3.4.2 eGRID Subregion 31 3.4.3 NERC Region 33 3.5 Grid Gross Loss 33 4. Specific eGRID Identifier Codes, Name Changes, and Associations 36 4.1 Plant Level 36 4.1.1 Plant ID Changes 36 4.1.2 Longitude/Latitude Updates 36 4.1.3 EPA/CAMD Plants Not Connected to the Grid 36 5. Description of Data Elements 38 5.1 The UNIT (Unit) File 38 5.2 The GEN (Generator) File 44 5.3 The PLNT (Plant) File 48 Technical Support Document for eGRID2018 | pg iii ------- CONTENTS 5.4 The ST (State) File 63 5.5 The BA (Balancing Authority) File 70 5.6 The SRL (eGRID Subregion) File 70 5.7 The NRL (NERC Region) File 70 5.8 The US (U.S.) File 70 5.9 The Regional Grid Gross Loss File 70 6. References 73 Appendix A. eGRID File Structure - Variable Descriptions for eGRID2018 77 Appendix B. eGRID Subregion and NERC Region Representational Maps 104 Appendix C. Crosswalks and Additional Data Tables 106 Emission Factors - NOx, CO2, SO2, CH4, and N2O 106 Biomass fuels used in the Plant file biomass emission adjustments 121 Plant ORISPL ID Changes 122 Geothermal Geotype 123 English to Metric Conversion Factors 123 Appendix D. Information on Prior Editions of eGRID 124 Tables Table 3-1. Comparison of 100-Year GWPs 21 Table 3-2. Example Biomass and CHP CO2 Emissions Adjustment Calculation 25 Table 3-3. Fuel-based Emission Rates - Primary Fuel Category 28 Table 3-4. eGRID Subregion Acronym and Names for eGRID 32 Table 3-5. NERC Region Acronym and Names for eGRID 33 Table 3-6. eGRID2018 Grid Gross Loss (%) 35 Table 4-1. eGRID2018 Latitude/Longitude Updates 36 Table 4-2. eGRID2018 EPA/CAMD Plants Not Connected to the Grid 37 Table A-l. eGRID File Structure, eGRID2018 UNIT Unit File 77 Table A-2. eGRID File Structure, eGRID2018 GEN Generator File 78 Table A-3. eGRID File Structure, eGRID2018 PLNT Plant File 79 Table A-4. eGRID File Structure, eGRID2018 ST State File 83 Table A-5. eGRID File Structure, eGRID2018 BA File, Balancing Authority (BA) File 87 Table A-6. eGRID File Structure, eGRID2018 SRL File, eGRID Subregion File 91 Table A-7. eGRID File Structure, eGRID2018 NRL File, NERC Region File 95 Table A-8. eGRID File Structure, eGRID2018 U.S. File, United States File 99 Table A-9. eGRID File Structure, eGRID2018 GGL File, Grid Gross Loss (%) File 103 Table C-l. eGRID Emission Factors (CO2, CH4, and N2O) 106 Table C-2. Nitrogen oxides (NOx) emission factors 107 Table C-3. Sulfur dioxide (SO2) emission factors 114 Table C-4. Fuel types included in the Plant file biomass emission adjustments 122 Table C-5. Crosswalk of EIA ORISPL ID changes to EPA/CAMD ORISPL IDs 122 Table C-6. Geothermal Emission Factors by Geotype and Pollutant 123 Table C-7. Conversion Factors 123 Figures "cc 1 lical Support Document c<,>K D2018 j pg, iv ------- CONTENTS Figure B-l. eGRID Subregion Representational Map 104 Figure B-2. NERC Region Representational Map 105 Technical Support Document for eGR!D2018 j pg, v ------- ABBREVIATIONS AND ACRONYMS Abbreviations and Acronyms 40 CFR Part 75 AB 32 AR4 AR5 BA BBtu Btu CAMD CARMA CHP CH4 C02 C02e DOE DVRPC EF eGRID eGRID1996 eGRID 1997 eGRID 1998 eGRID2000 eGRID2004 eGRID2005 eGRID2007 Code of Federal Regulations Title 40 Part 75, which specifies air emissions monitoring and reporting requirements delineated in EPA regulations Assembly Bill 32 - California Global Warming Solutions Act Fourth Assessment Report of the Intergovernmental Panel on Climate Change Fifth Assessment Report of the Intergovernmental Panel on Climate Change Balancing authority Billion Btu British thermal unit Clean Air Markets Division Carbon Monitoring for Action Combined heat and power (cogeneration) Methane Carbon dioxide Carbon dioxide equivalent U.S. Department of Energy Delaware Valley Regional Planning Commission Emission factor Emissions & Generation Resource Integrated Database First edition of Emissions & Generation Resource Integrated Database with year 1996 data Second edition of the Emissions & Generation Resource Integrated Database with year 1997 data Third edition of the Emissions & Generation Resource Integrated Database with year 1998 data Fourth edition of the Emissions & Generation Resource Integrated Database with years 1999 and 2000 data (1996-1998 data were also reissued without change) Fifth edition of the Emissions & Generation Resource Integrated Database with year 2004 data Sixth edition of the Emissions & Generation Resource Integrated Database with year 2005 data (2004 data were also reissued without change) Seventh edition of the Emissions & Generation Resource Integrated Database with year 2007 data (2005 and 2004 data were also reissued without change) Technical Support Document for eGR!D2018 j pg, vi ------- ABBREVIATIONS \\ N VJRONYMS eGRID2009 eGRID2010 eGRID2012 eGRID2014 eGRID2016 eGRID2018 EGC EIA ELCALLOC EPA FERC FIPS GGL GHG GWh GWP Hg ICR ID IPCC IPM ISO kg kWh lb MISO GJ MMBtu MMcf Eighth edition of the Emissions & Generation Resource Integrated Database with year 2009 data (2007, 2005, and 2004 data were also reissued without change) Ninth edition of the Emissions & Generation Resource Integrated Database with year 2010 data Tenth edition of the Emissions & Generation Resource Integrated Database with year 2012 data Eleventh edition of the Emissions & Generation Resource Integrated Database with year 2014 data Twelfth edition of the Emissions & Generation Resource Integrated Database with year 2016 data Thirteenth edition of the Emissions & Generation Resource Integrated Database with year 2018 data Electric generating company Energy Information Administration Electric allocation factor U.S. Environmental Protection Agency Federal Energy Regulatory Commission Federal Information Processing Standards Grid gross loss Greenhouse gas Gigawatt-hour Global warming potential Mercury Information collection request Identifier Intergovernmental Panel on Climate Change Integrated Planning Model Independent System Operator Kilogram Kilowatt-hour Pound Midcontinent Independent System Operator Gigajoule Million Btu Million cubic feet Technical Support Document for eGR!D2018 pg. vii ------- 43 AND ACRONYMS MSB Municipal solid waste - biomass component MSN Municipal solid waste - non-biomass component MSW Municipal solid waste MW Megawatt MWh Megawatt-hour NATCARB National Carbon Sequestration Database and Geographic Information System NEMS National Energy Modeling System NERC North American Electric Reliability Corporation NESCAUM Northeast States for Coordinated Air Use Management NETL National Energy Technology Laboratory NGO Nongovernmental Organization NOx Nitrogen oxides NREL National Renewable Energy Laboratory N2O Nitrous oxide OAP Office of Atmospheric Programs ORIS Office of Regulatory Information Systems ORISPL Office of Regulatory Information Systems Plant code ORNL Oak Ridge National Laboratory OTC Ozone Transport Commission PM Particulate matter RECs Renewable Energy Credits RTO Regional Transmission Organization SAR Second Assessment Report of the Intergovernmental Panel on Climate Change SO2 Sulfur dioxide TAR Third Assessment Report of the Intergovernmental Panel on Climate Change TJ Terajoule VRSA Voluntary Renewable Set-Aside Account Technical Support Document for eGR!D2018 j pg, viii ------- ABBREVIATIONS \\ N VJRONYMS [This page intentionally left blank.] Technical Support Document for eGR!D2018 ------- 1. Introduction SUMMARY OF eGRID YEAR 2018 DATA The Emissions & Generation Resource Integrated Database (eGRID) is a comprehensive source of data on the environmental characteristics of almost all electric power generated in the United States. The preeminent source of emissions data for the electric power sector, eGRID is based on available plant-specific data for all U.S. electricity generating plants that provide power to the electric grid and report data to the U.S. government. Data reported include, but are not limited to, net electric generation; resource mix (for renewable and nonrenewable generation); mass emissions of carbon dioxide (CO2), nitrogen oxides (NOx), sulfur dioxide (SO2), methane (CH4), and nitrous oxide (N2O); emission rates for CO2, NOx, SO2, CH4, and N2O; heat input; and nameplate capacity. eGRID reports this information on an annual basis (as well as by ozone season for NOx) at different levels of aggregation. eGRID2018, released in January 2020, is the thirteenth edition of eGRID. eGRID2018 includes two Excel workbooks, one with English units and one with metric units, that contain generator and unit spreadsheets as well as spreadsheets by aggregation level for data year 2018: plant, state, balancing authority, eGRID subregion, NERC region, and United States. The workbooks also include a spreadsheet that displays the grid gross loss and the variables that are used in its estimation for year 2018. This document provides a description of eGRID2018, including the methodology for developing the Excel spreadsheets for each level of aggregation and the grid gross loss calculation. Section 2 provides a summary of the database; Section 3 presents the methodology for emissions estimations, including adjustments for biomass and combined heat and power (CHP); Section 4 discusses eGRID specific identification codes, name changes and associations; Section 5 describes the data elements in detail; and Section 6 provides a list of references. There is also a set of four Appendices - Appendix A includes the file structure; Appendix B includes the eGRID subregion and NERC region representational maps; Appendix C includes crosswalks between different datasets and relevant data tables; and Appendix D contains information on previous releases of eGRID. Technical Support Document for eGR!D2018 ------- SUMMARY OF eGRID YEAR 2018 DATA 2. Summary of eGRID2018 Data 2.1 eGRID Files eGRID2018 contains electric power data at different levels of aggregation. The eGRID2018 data are displayed in two workbooks, one with English units of measure and the other with metric units of measure. As the database name implies, the focus of the data spreadsheets is on two areas: generation and emissions. In the English unit workbook, generation is expressed in both MWh and as a percentage (called "resource mix" - generation of a certain fuel or resource type divided by total generation). Carbon dioxide, NOx, and SO2 emissions are expressed in short tons; CH4,N20, and Hg emissions are expressed in pounds; emission rates for CO2, NOx, SO2, CH4, and N2O are expressed in lb/MWh and lb/MMBtu. In the Metric unit workbook, generation is expressed in MWh, Gigajoules (GJ), and as a percentage. Carbon dioxide, NOx, and SO2 emissions are expressed in metric tons; CH4, N2O, and Hg emissions are expressed in kilograms; emission rates for CO2, NOx, SO2, CH4, and N2O are expressed in both kg/MWh and kg/GJ. See Table C-7 for a list of English to Metric conversion factors. The eGRID2018 workbooks can be downloaded from the EPA eGRID website, https://www.epa.gov/energy/egrid. along with Summary Tables and this document. The workbooks contain eight levels of data aggregation: UNIT (unit), with 26,744 records; GEN (generator), with 27,944 records; PLNT (plant), with 10,969 records; ST (state), with 51 records; BA (balancing authority), with 73 records; SRL (eGRID subregion), with 26 records; NRL (NERC region), with 11 records; and US, with 1 record. The unit spreadsheet is sorted by state abbreviation, plant name, plant code, and boiler ID. The generator spreadsheet is sorted by state abbreviation, plant name, plant code, and generator ID. The plant spreadsheet is sorted by state abbreviation, plant name, and plant code. The state spreadsheet is sorted by state abbreviation, the balancing authority spreadsheet is sorted by balancing authority name, the eGRID subregion spreadsheet is sorted by eGRID subregion name, and the NERC region spreadsheet is sorted by NERC region acronym. The year 2018 grid gross loss spreadsheet is also included in the workbook. The spreadsheet structure for each of the spreadsheets is included in Appendix A. The spreadsheet structure also includes a description of the variables and the original data sources. Users should take note that eGRID's emissions and emission rates are calculated at the sources of generation and do not account for losses from transmission and distribution infrastructures. Please refer to Section 3.5 for information on how to account for line losses when assigning emission rates to Technical Supp i : jment for eGR!D20i3 | pg. 11 ------- SUMMARY OF eGRID YEAR 2018 DATA estimate indirect emissions associated with electricity purchases. Aggregated eGRID data only account for U.S. generation that takes place within the aggregated area and do not account for any electricity that is imported from or exported to other areas. The grid gross loss calculation, however, does account for U.S. regional interchanges with other U.S. regions as well as Canada and Mexico. In addition, although eGRID is based on existing Federal data sources, its development requires substantial attention to quality control. Accurate matching of entities from different databases requires great care, even where identification codes are available. Inconsistencies between data sources, missing data, and ambiguous data necessitate adjustments to values of individual data elements, especially identification data. In general, however, questionable data are not altered in order to maintain consistency with the original data sources. Please note that only certain eGRID spreadsheets can be linked from year 2018 to years 2016, 2014, 2012, 2010, 2009, 2007, 2005, or 2004. The spreadsheets that can be linked include the NERC region (by NERC acronym), eGRID subregion (by eGRID subregion acronym), state (by state abbreviation), plant (by Office of Regulatory Information Systems Plant [ORISPL] code), and the US. 2.2 What's New in eGRID There are several new data elements or changes to the eGRID methodology in eGRID2018: Mercury emissions (when available) are now included at the unit-level in the Unit file. Global warming potential (GWP) values were updated to the Fourth IPCC Assessment values to better align with other EPA sources reporting carbon dioxide equivalent emissions. New fields showing the heat input and emissions values used to adjust combined heat and power (CHP) plants and biomass plants were added to the Plant file. See Section 3.1.2 for more information. Sector information, determined by a plant's primary purpose, regulatory status, and CHP status, was added to the Plant file. The "Plant operator name" field was changed to "Plant transmission or distribution system owner name" and the "Utility service territory name" field was changed to "Utility name" to better align with the EIA source data. The emission factors for CFU and N2O for refined coal (RC) and waste coal (WC) were updated to match the emission factors for all other coal types to be consistent with guidance from the EPA Greenhouse Gas Reporting Program. The data year was added as a field to all files in eGRID2018. The data field "number of boilers" was updated to "number of units" and now matches the number of units for each plant represented in the Unit file. The emission factor for NOx emissions from flaring of landfill gas (LFG) used in the biomass adjustment of LFG was updated to match the emission factor from AP-42. The CH4, N2O, and CO2 equivalent input emission rates were added to the Plant, State, BA, NERC region, and US files. Technical Support Document for eGR!D2018 ------- SUMMARY OF eGRID YEAR 2018 DATA Nonbaseload generation by fuel and resource mix was added to the State, BA, NERC region, and US files. Fuel specific emission rates for CH4, N2O, and CC^e were added to the State, BA, eGRID Subregion, NERC region, and US files. The grid gross loss methodology now excludes exports to better align with the EIA methodology. See Section 3.5 for more information. 2.3 Uses and Users of eGRID eGRID data support a wide variety of users globally through a wide variety of uses. eGRID is valuable to those in the Federal Government, state and local governments, non-governmental organizations, academia, and companies who are generally seeking environmental information from the electric power sector in the United States. eGRID is most often used for the estimation of indirect emissions from electricity purchases, in greenhouse gas (GHG) inventories, for carbon footprinting, and for estimating avoided emissions from programs and projects that would reduce the consumption for grid supplied electricity. eGRID data are cited by emission inventory and registry protocols, various emission calculation tools and applications, many academic papers, and many consultants, and it is used for many research applications and efforts. Within EPA, eGRID data are used in the following applications and programs: Power Profiler web application, Climate Leaders protocols, ENERGYSTAR's Portfolio Manager and Target Finder, Waste Wise Office Carbon Footprint Tool, the Personal Greenhouse Gas Emissions Calculator, the Greenhouse Gas Equivalencies Calculator, and the Green Power Equivalency Calculator. When the EPA announced its "Apps for the Environment" challenge using EPA data, developers across the U.S. responded. EPA announced the winners on November 8, 2011 and the two top winning apps ~ Light Bulb Finder (http://www.lightbulbfinder net/) and Hootroot use eGRID data for a mobile app and/or a web app, as did several other entries (EPA, 2011). Another of the winning entries, loulebug (http://ioulebug .com/). uses eGRID data and developed a game to save energy as both a web and free iPhone app. In 2015, Executive Order 13693 was issued, requiring Federal agencies to reduce their greenhouse gas emissions from direct and indirect activities. The order requires that Federal agencies report their building information in EPA's Portfolio Manager which uses eGRID to estimate emission reductions. One of the most popular uses of eGRID is to determine the indirect GHG emissions from electricity purchases and avoided GHG emissions from projects and programs that reduce the demand for grid supplied electricity. For example, The Climate Registry, California's Mandatory GHG emissions reporting program (AB 32), and the Greenhouse Gas Protocol Initiative cite eGRID for use in estimating scope 2 (indirect) GHG emissions from electricity purchases in the United States (TCR, 2019; CARB, 2007; Greenhouse Gas Protocol, 2016). Most carbon footprint calculators that are applicable to the United States use eGRID data. The website, www.fueleconomv.gov, resulting from an EPA-U.S. Department of Energy (DOE) partnership, provides fuel economy information that consumers can use to make knowledgeable decisions when buying a car. The information can also help consumers achieve the best fuel economy from currently owned cars. This website showcases its Greenhouse Gas Emissions for Electric and Technical Support Document for eGR!D2018 ------- SUMMARY OF eGRID YEAR 2018 DATA Plug-in Hybrid Electric Vehicles calculator, http://www.fueleconomv.gov/feg/label/calculator.isp. which uses eGRID data to estimate the total GHG emissions from electric and plug-in hybrid vehicles, including emissions from electricity used to charge the vehicle. eGRID is cited as a data source at http://www.fueleconomv.gov/feg/label/calculations-information.shtml. In a similar vein, the Union of Concerned Scientists published a 2012 report using eGRID data to support its study results that it is advantageous to switch to a battery-powered vehicle, although there are wide differences in both real electricity costs and GHG emissions, depending on the region in which you live (UCS, 2012). EIA's National Energy Modeling System (NEMS)'s electricity market module supply regions are the eGRID subregions; the map used in their 2016 documentation (Figure 3) uses the eGRID subregion map and subregion colors, changing a few names (EIA, 2014). eGRID is also used by other Federal Government agencies such as Oak Ridge National Laboratory (ORNL) for their Combined Heat and Power Calculator, the National Energy Technology Laboratory (NETL) for their sponsored distributed National Carbon Sequestration Database and Geographic Information System (NATCARB), and the National Renewable Energy Laboratory (NREL) for their micropower distributed generation optimization model named HOMER. States and local governments rely on eGRID data for electricity labeling (environmental disclosure programs), emissions inventories, and registries as well as for efforts to analyze air emissions from the electric power sector. Several states have published state specific emissions information from eGRID or have used eGRID to inform policy decisions. The Maryland Department of the Environment determined eligibility for participation in the Voluntary Renewable Set-Aside Account (VRSA) using eGRID factors (Maryland, 2010); and in 2009, the Delaware Valley Regional Planning Commission (DVRPC) ~ a nine county region in Pennsylvania and New Jersey ~ completed a 2005 GHG inventory in support of regional efforts to quantify and reduce emissions associated with climate change, using eGRID factors (DVRPC, 2010). Tracking systems for renewable energy credits (RECs), such as ISO-New England's Generation Information System and PJM Environmental Information Services' Generation Attribute Tracking System utilize eGRID data. ISO New England used eGRID rates in developing the 2017 New England Electric Generator Air Emissions Report (http://www.iso-ne.com/svstem-planning/svstem-plans-studies/emissions'). eGRID is additionally used for nongovernmental organizations' (NGOs) tools and analysis. The following is a list of some known users and applications of eGRID data: Northeast States for Coordinated Air Use Management (NESCAUM) analysis; Powerscorecard.org; Ozone Transport Commission (OTC)'s Emission Workbook; GHG Protocol Initiative; Rocky Mountain Institute's Community Energy Finder; Leonardo Academy's Cleaner and Greener Environmental Program; National Resource Defense Council's Benchmarking Air Emissions; Berkeley Institute of the Environment; Cool Climate Carbon Footprint Calculator; Climate and Air Pollution Planning Assistant; Emission Solution's Carbon Footprint Calculator; International Council for Local Environmental Initiatives' Clean Air software, United States Department of Transportation Federal Transit Administration, Google PowerMeter; National Public Radio's Visualizing the U.S. Electric Grid; International Code Council; American Society of Heating, Refrigerating, and Air-Conditioning Technical Support Document for eGR!D2018 ------- SUMMARY OF eGRID YEAR 2018 DATA Engineers; American Council for an Energy-Efficient Economy's Local Energy Efficiency Policy Calculator; and World Resource Institute's Carbon Value Analysis Tool. The Center for Global Developments' Carbon Monitoring for Action Database (CARMA) at http://carma.org. which contains information about carbon emissions for power plant and companies in the U.S. as well as other countries, used eGRID year 2005 data as a base, according to the Center's David Wheeler (Wheeler, 2007). eGRID data also underlie the Global Energy Observatory U.S. power plant database. Carbon Visuals, which illustrate accurate volumetric images to visualize the carbon footprint of all U.S. power stations, used eGRID subregion GHG emission factors (http://www.carbonvisuals.com/proiects/2015/6/23/visualising-the-carbon-footprint-of-all-us-power- stations?rq=egrid; Carbon Visuals, 2014). The University of California, Berkeley's CoolClimate Carbon Footprint Maps use eGRID data (Jones and Kammen, 2013). Several papers have been written to clarify issues and respond to questions about the uses of eGRID. The following provides details on some of the most recent presentations and papers. In October 2019, "EPA's 2018 Emissions & Generation Resource Integrated Database (eGRID): Updates and Improvements," (Dorn et al., 2019a) was presented at the 18th Annual Community Modeling and Analysis System Conference. In August 2019, "Adding Particulate Matter to EPA's eGRID Database," (Dorn et al., 2019b) was presented at EPA's 2019 International Emissions Inventory Conference. In June 2019, "Adding Particulate Matter to EPA's eGRID Database," (Hoer et al., 2019) was presented at the Air and Waste Management Association's 112th Annual Conference & Exhibition. In October 2018, "EPA's Emissions & Generation Resource Integrated Database (eGRID): Improvements and Applications" (Cooley et al., 2019) was presented at the 17th Annual Community Modeling and Analysis System Conference. In May 2016, "How Part 75 Data is Used in GHG Reporting and EE/RE Quantification," (Johnson, 2016a) was presented at the EPRI Continuous Emissions Monitoring User Group Conference. In February 2016, "Emissions & Generation Resource integrated Database (eGRID)," (Johnson, 2016b) was presented at the Energy, Utility, and Environment Conference. In October 2015, "EPA's Emissions & Generation Resource Integrated Database (eGRID): Improvements and Applications: (Dorn et al., 2015) was presented at the Community Modeling and Analysis System Conference. In February 2015, "eGRID Updates," (Johnson, Schreifels, and Quiroz, 2015) was presented at the Energy, Utility, and Environment Conference. Technical Support Document for eGR!D2018 ------- SUMMARY OF eGRID YEAR 2018 DATA The paper "Using EPA's eGRID to Estimate GHG Emissions Reductions from Energy Efficiency" (Diem, Salhotra, and Quiroz, 2013) was presented at the International Energy Program Evaluation Conference, in August 2013. In lanuary 2013, "Using eGRID Data for Carbon Footprinting Electricity Purchases," (Diem and Quiroz, 2013) was presented at the Energy, Utility, and Environment Conference. The paper "How to use eGRID for Carbon Footprinting Electricity Purchases in Greenhouse Gas Emission Inventories" (Diem and Quiroz, 2012) was presented at the EPA 2012 International Emission Inventory Conference in August 2012. 2.4 eGRID Data Sources eGRID is developed using the following key data sources: EPA/CAMD: this includes data reported to EPA by electric generating units to comply with the regulations in 40 CFR Part 75. Data include annual emissions of CCh.NOx, SO2, and Hg; ozone season emissions of NOx; and annual and ozone season generation and heat input. The data are available at https://www.epa.gov/airmarkets. The EPA/CAMD data used in eGRID2018 was queried on May 21, 2019. EIA-860: this includes data reported to EIA on electric generators. Data include nameplate capacity, prime mover, primary fuel type, and indication of whether the generator is a combined-heat-and-power unit (EIA, 2019a). The EIA-860 data used in eGRID2018 was released on September 3, 2019. EIA-923: this includes data reported to EIA on fuel consumption and generation. Data include monthly generation and heat input at the unit or generator level for a subset of units and generators, and at the prime mover level for all plants. As discussed in more detail below, eGRID2018 uses unit- or generator-level data where available, and prime mover-level data for all other units and generators (EIA, 2019b). The EIA-923 data used in eGRID2018 was released on November 21, 2019. The key identifier of plants in the EPA/CAMD and EIA datasets is the ORISPL code. While the ORISPL code generally matches well for plants in the different datasets, there are some plants that have different ORISPL codes between the EPA/CAMD and EIA datasets. These plants are listed in Appendix C. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS 3. eGRID Methodology This section describes the methodologies utilized to develop eGRID2018. Some methods used for eGRID2018 are modified or refined from previous editions of eGRID, and are so noted in this section. Also see Section 2.2 for a list of changes to eGRID2018. 3.1 Estimation of Emissions The Unit file and Plant file in eGRID2018 include emissions data for CO2, NOx, SO2, CH4, and N2O, and the Unit file includes mercury (Hg) emissions.1 Carbon dioxide (CO2) is a product of combusting fossil fuels, as well as biogenic and other materials, and is the primary greenhouse gas (GHG) emitted by human activities that is driving global climate change; nitrogen oxides (NOx) are also emitted by electric generating units and are precursors to the formation of ozone, or smog, and fine particulates (PM2.5), and also contributes to acid rain and other environmental and human health impacts; sulfur dioxide (SO2) is emitted by electric generating units, especially with coal combustion, and is a precursor to acid rain and PM2.5 and is associated with other environmental and human health impacts. Methane (CH4) and nitrous oxide (N2O), two other GHGs emitted by electric generating units, have been included in eGRID since data year 2005 at the plant level. The eGRID emissions data for the three GHGs are used as default factors in a variety of climate protocols (including The Climate Registry, California's Mandatory GHG emissions reporting program (AB 32), and EPA's Climate Leaders) for indirect emissions estimation calculations (TCR, 2019; CARB, 2007; EPA, 2019). Emissions estimates are included at the unit level, in the Unit file, as well as summed to the plant level, in the Plant file. The sum of unit level emissions from the Unit file will equal the unadjusted plant level emissions in the Plant file, apart from Hg emissions. Plant level emissions in eGRID reflect a combination of monitored and estimated data. Emissions and emission rates in eGRID represent emissions and rates at the point(s) of generation. While they do account for losses within the generating plants (net generation), they do not take into account any power purchases, imports, or exports of electricity into a specific state or any other grouping of plants, and they do not account for any transmission and distribution losses between the points of generation and the points of consumption. Also, eGRID does not account for any pre-combustion emissions associated with the extraction, processing, and transportation of fuels and other materials used at the plants or any emissions associated with the construction of the plants. eGRID emissions and heat input that are displayed in the Unit file are unadjusted, while the Plant file contains emissions and heat input that are adjusted for biomass and/or CHP units, where applicable. The Plant file also contains unadjusted emissions. The subsequent aggregation files are based on adjusted emissions. All emission rates in the Plant file and all aggregation files are based on adjusted 1 The Plant file also contain fields for emissions of mercury. However, while electric generating units started to report mercury data to EPA/CAMD in 2015, the data are incomplete. We have included the unit-level emissions, but since only a portion of the units at one plant may not list mercury emissions, we have not summed these emissions to the plant-level. Therefore, we have retained these fields in anticipation of being able to report plant-level mercury emissions and emission rates in a future edition of eGRID. Technical Support Document for eGRID2018 I pg-17 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS emissions, net generation, and adjusted heat input. Both the source(s) of emissions data and adjustment flags are provided in the Plant file. 3.1.1 Unit Level and Plant Level Unadjusted Emission Estimates 3.1.1.1 Annual Emission Estimates for CO2, NOx, and SO2 Unit File Unit level emissions in the eGRID Unit file are estimated in a three-step process: 1. We include unit-level emissions and heat input data from EPA/CAMD; 2. For units that report to EIA at the unit level but not to EPA/CAMD, we include the reported unit-level heat input from EIA; and 3. For all other units that report EIA at the plant level, we distribute prime mover-level heat input to each unit based on that unit's proportion of nameplate capacity. For units that report to EIA but not to EPA/CAMD (steps 2 and 3), we estimate emissions by multiplying the heat input by the fuel-specific emission factors shown in Appendix C. Generally, emission sources that report to EPA/CAMD are fossil fuel-fired boilers and turbines serving an electric generator with a nameplate capacity greater than 25 MW and producing electricity for sale. Additionally, some sources not serving a generator or serving a generator less than 25 MW also report to EPA/CAMD. For units that report to EPA/CAMD only during the ozone season, the non-ozone season heat input is taken from the EIA-923. The non-ozone season heat input for each included unit was distributed from the prime-mover level based on the nameplate capacity of that unit (step 3 above). The EIA-923 distributed non-ozone season heat input is added to the ozone season heat input from EPA/CAMD. Non-ozone season emissions for NOx are calculated and added to the reported EPA/CAMD ozone season NOx emissions. The emissions for CO2 and SO2 for these units are calculated using the methodology discussed below, using the updated heat input. The heat input and emission adjustment only applies to 167 units out of the total 247 units in EPA/CAMD that reported only during the ozone season. There are 80 units that cannot be updated to reflect annual data values due to differences for these units in the EPA/CAMD and EIA data. C02 As discussed above, the majority of CO2 emissions reported in eGRID2018 are monitored data from EPA/CAMD. For units that report to EIA but not to EPA/CAMD, or for units from EPA/CAMD where there are gaps in CO2 emissions data, the CO2 emissions are estimated based on heat input and an emission factor. The emission factors are primarily from the default CO2 emission factors from the EPA Mandatory Reporting of Greenhouse Gases Final Rule (EPA, 2009, Table C-l). For fuel types that are included in eGRID2018 but are not in the EPA Mandatory Reporting of Greenhouse Gases Final Rule, additional emission factors are used from the 2006 Intergovernmental Panel on Climate Change (IPCC) Guidelines for National Greenhouse Gas Inventories and the EPA Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2015 (IPCC, 2007a; EPA, 2017). Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS Several fuel types do not have direct reported emission factors, so emission factors from similar fuel types are used: The emission factor for natural gas is used to estimate emissions from process gas and other gas; The emission factor for anthracite, bituminous, and lignite coal are used to estimate emissions from refined coal and waste coal; and The emission factor for other biomass liquids is used to estimate emissions from sludge waste and liquid wood waste. The CO2 emissions from hydrogen, nuclear, purchased steam, solar, waste heat, water, wind, and energy storage are considered to be zero. The CO2 emissions for units with a fuel cell prime mover are also assumed to be zero. A list of the CO2 emission factors used in eGRID2018 can be found in Table C-l in Appendix C. NOx Similar to CO2, the emissions from NOx come from monitored data from EPA/CAMD where available. For all other units, the NOx emissions are based on heat input multiplied by an emission factor. For some units, EIA reports unit-level NOx emission rates (lb/MMBtu) for both annual and ozone season emissions, from EIA Form 923, Schedule 8C. These unit-level emissions rates are multiplied by the unit-level heat input used to estimate annual and ozone season NOx emissions. For all other units that report to EIA but do not report to EPA/CAMD, the unit-level heat input is multiplied by a prime mover- and fuel-specific emission factor from EPA's AP-42 Compilation of Air Pollutant Emission Factors or the EIA Electric Power Annual (EPA, 1995; EIA, 2019e, Table A-2). Ozone season NOx emissions include emissions from May through September. For units where the NOx emissions are estimated with an emission factor, the NOx ozone season emissions are based on the emission factor multiplied by the heat input for May through September. See Table C-2 in Appendix C for the NOx emission factors used in eGRID2018. SO2 As with the other pollutants, emissions of SO2 are taken from monitored data from EPA/CAMD where available. For all other units, SO2 emissions are based on heat input multiplied by an emission factor. Unlike for NOx, EIA does not report unit-level emissions rates for SO2. Therefore, the SO2 emissions for all non- EPA/CAMD units are estimated using emission factors from EPA's AP-42 or the EIA Electric Power Annual, which are specific to fuel, prime mover, and in the case of boilers, boiler type (EPA 1995; EIA, 2019e, Table A-l). For some fuels, such as coal and oil, the emission factor from AP-42 depends on the sulfur content of the fuel. For many units, EIA reports monthly unit-level data on the sulfur content of the fuel consumed, and these data are used with the AP-42 emission factors to estimate SO2 emissions. For Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS units without unit-level data on the sulfur content of fuels, the sulfur content is based on an average of the reported sulfur contents for units that have the same prime mover and fuel type. For some units for which we calculated SO2 emissions with an emission factor, EIA reports SO2 control efficiencies. For these units the estimated SO2 emissions are multiplied by (1 - control efficiency) to estimate the controlled emissions. Units that do not have unit-level control efficiency data are assumed to be uncontrolled. The control efficiencies are not used for units where the emissions data are from EPA/CAMD, because these emissions already take controls into account. See Table C-3 in Appendix C for the SO2 emission factors used in eGRID2018. Geothermal Geothermal emissions are estimated for CO2, SO2, and NOx. While CO2 is a gas in the geothermal reservoir, SO2 and NOx result from hydrogen sulfide combustion. The three pollutants' emission factors, obtained from a 2007 Geothermal Energy Association environmental guide (GEA, 2007), are applied to plant net generation, and differ depending on the type of geothermal plant as identified in various reports from the Geothermal Energy Association (GEA, 2016). For a binary or flash/binary geothermal plant, there are no CO2, SO2, or NOx emissions since the plant operates a closed system; for a flash geothermal plant, there are no NOx emissions and minimal CO2 and SO2 emissions; and for a dry steam geothermal plant, there are minimal CO2, SO2, and NOx emissions. See Table C-6 in Appendix C for the geothermal emission factors used in eGRID2018. Plant File The emissions of CO2, NOx, and SO2 in the Plant file are the sum of all unit-level emissions at a plant from the Unit file. 3.1.1.2 Annual Emission Estimates for CH4, N20, and CO2 equivalent Emissions for CH4, N2O, and CC>2-equivalent (CChe) are included in eGRID2018at the plant level.2 The emissions for CH4 and N2O are calculated using heat input data and emission factors from the EPA or the IPCC. The emission factors are primarily from the EPA Mandatory Reporting of Greenhouse Gases Final Rule (EPA, 2009, Table C-l). For fuel types that are included in eGRID2018 but not in Table C-l of the EPA Mandatory Reporting of Greenhouse Gases Final Rule, additional emission factors are used from the 2006 IPCC Guidelines for National Greenhouse Gas Inventories and the EPA Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2015 (IPCC, 2007a; EPA, 2017). Several fuel types do not have direct reported emission factors, so emission factors from similar fuel types are used: The emission factor for natural gas is used to estimate emissions from process gas and other gas; 2 Nitrous oxide is an oxide of nitrogen that is not part of the NOx subset of oxides of nitrogen. N20 is a greenhouse gas, the emissions of which are contributing to global climate change. N20 should not be confused with NOx. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS The emission factor for anthracite, bituminous, and lignite coal are used to estimate emissions from refined coal and waste coal; and The emission factor for other biomass liquids is used to estimate emissions from sludge waste and liquid wood waste. The CH4 and N2O emissions for electricity used from energy storage (megawatt-hours), hydrogen, nuclear, purchased steam, solar, waste heat, water, and wind are considered to be zero. The CH4 and N2O emissions from units with a fuel cell prime mover are also considered to be zero. A list of the CH4 and N2O emission factors used in eGRID2018 can be found in Table C-lin Appendix C. The CO2 equivalent (CC^e) emissions, in tons, and total output emission rate (lb/MWh) are included in the Plant file and subsequent aggregation files. The CChe nonbaseload output emission rate (in lb/MWh) is included at the aggregated State, BA, NERC region, eGRID subregion, and US level in the eGRID file. CChe emissions are calculated based on the global warming potential of CO2, CH4, and N2O. Global warming potential is a value assigned to a GHG so that the emissions of different gases can be assessed on an equivalent basis to the emissions of the reference gas, CO2. Traditionally, the 100-year GWPs are used when calculating overall CO2 equivalent emissions, which is the sum of the products of each GHG emission value and their GWP. Based on the fourth IPCC assessment (2007) (AR4), the GWP of CO2 is 1, CH4 is 25 and N2O is 298. When calculating the CO2 equivalent, it is important to ensure that each of the GHG emission values has the same measurement units (i.e. either all in short tons or all in pounds), as CO2 emissions are expressed in short tons while both CH4 and N2O emissions are expressed in pounds in eGRID. The GWP was updated to AR4 in eGRID2018 to align with other EPA sources reporting CO2 equivalent emissions. Previous versions of eGRID used the second IPCC assessment (SAR). A comparison of the GWPs for CO2, CH4, and N2O is shown in Table 3-1 (EPA, 2017, Table 1-3; IPCC, 2007b, Table 3). Table 3-1. Comparison of 100-Year GWPs Gas SAR TAR AR4 AR5* CO2 1 1 1 1 CH4 21 23 25 34 N2O 310 296 298 298 *Note that the AR5 values include climate-carbon feedbacks 3.1.1.3 Annual Emission Estimates for Mercury Mercury emissions are reported to EPA/CAMD at the unit-level and are directly incorporated into the eGRID Unit file. Mercury emissions are not summed to the Plant file since the unit-level data may not be available for all units at a plant. While electric generating units started to report mercury data to EPA/CAMD in 2015 under the Mercury and Air Toxics Standards (MATS), the data are incomplete. The unit-level emissions are included in the Unit file, but since only a portion of the units at one plant may not list mercury emissions, they have not summed these emissions to the plant-level. However, the fields for Technical Support Document for eGRID2018 I pg- 21 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS Hg emissions and emissions rates in the Plant file have been retained so that these data may be included in future editions of eGRID. 3.1.2 Plant Level Adjusted Emission Estimates Emissions reported in eGRID represent emissions from fuel utilized only for electricity generation. For certain plants, there are two possible cases for which we adjust the emission estimates: (1) if the plant is a CHP facility; and (2) if one or more units at the plant burn biomass, including biogas (such as landfill, methane, and digester gas). The Plant file reports both adjusted and unadjusted emissions, while the Unit file reports only unadjusted emissions. Due to these adjustments, the adjusted emissions reported in eGRID may be different from emissions reported in other EPA sources. 3.1.2.1 Adjustments for Biomass Prior editions of eGRID applied a biomass adjustment to the annual emission values based on an assumption of zero emissions from biomass combustion. This assumes that the amount of carbon sequestered during biomass growth equals the amount released during combustion, without consideration of other factors. For reasons of consistency, the same approach is applied in eGRID2018. eGRID makes adjustments for biogas emissions, for biomass emissions other than biogas, and for solid waste emissions for specified pollutants. Solid waste typically consists of a mixture of biogenic materialssuch as wood, paper, and food wasteand fossil-based materialssuch as plastics and tires. EIA-923 reports fuel consumption at plants that combust municipal solid waste (MSW) as the biomass component (MSB) and the non-biomass component (MSN). Emissions from the biomass component of solid waste are adjusted, while emissions from the non-biomass component of solid waste are not adjusted. In eGRID2018, the fuel type for these plants is listed as MSW.3 The Plant file includes a biomass adjustment flag to indicate whether a biomass adjustment is made to the annual emission values for CO2, NOx, SO2, CH4, and N2O. The possible biomass adjustments to emissions are explained below. See Table C-l in Appendix C for a table of biomass fuel types used in the biomass adjustments to emissions in the Plant file. For plants that have a biomass adjustment, the amount of emissions that the total emissions are adjusted by are included in eGRID2018. The emissions adjustment values from CO2 are listed for all plants with a biomass flag and the emissions adjustment values from NOx, SO2, CH4, and N2O are listed for plants with a biomass flag with landfill gas. Table A-3 in Appendix A has a list of all the new fields added to the Plant file, including the biomass emissions adjustment values. Note that for plants that have both a biomass flag and a CHP flag, the biomass emissions adjustment value subtracted from the unadjusted emissions value will not match the adjusted emissions value. For these plants, the CHP adjustment value needs to be accounted for as well. See Section 3.1.2.3 below for a sample calculation of a plant with both a biomass and CHP adjustment. 3 Previous editions of eGRID estimated the split between the biomass and non-biomass components of MSW. Because the EIA-923 reports these components separately, this estimation is no longer necessary. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS C02 The emissions from biomass combustion at a plant are subtracted from the plant's overall unadjusted CO2 emissions. The CO2 emissions from biomass are reported at the plant level. To determine the biomass emissions if the CHP adjustment is also flagged, the adjusted emissions value from CHP plants must first be calculated (since the CHP plant adjustment is applied last; see Section 3.1.2.2 below). For EPA/CAMD units with a prime mover that matches EIA-923 prime movers that burn one or more biomass fuels, the CO2 emissions are adjusted by subtracting the biomass CO2 emissions calculated using the corresponding EIA-923 data (EIA, 2019b). In previous editions of eGRID, there were different flags for the biomass adjustment to represent different biomass fuels or differences in the emissions data source. NOx, SO2, CH4, and N2O Emissions adjustments for NOx, SO2, CH4, and N2O emissions are only conducted for landfill gas in eGRID. This adjustment is based on the assumption that in many cases landfills would flare the gas if they did not combust it for electricity generation. Therefore, we assume that, at a minimum, the gas would have been combusted in a flare and would have produced some emissions of NOx, SO2, CH4, and N2O anyway. Similar to the CO2 adjustments, biogas adjustments are made by deducting the emissions from landfill gas for NOx, SO2, CH4, and N2O from the overall plant total emissions. For NOx emissions from landfill gas, an emission factor for flaring of landfill gas, 0.02 tons per MMBtu, is used (EPA, 1995).4 See Table C-l in Appendix C for a list of CH4, and N2O emission factors and the landfill gas (LFG) values from Table C-3 for a list of SO2 emission factors. Note that CO2 is also adjusted for landfill gas, as described above. 3.1.2.2 Adjustments for CHP A CHP facility is a type of generating facility that produces electricity and another form of useful thermal energy (such as heat or steam) used for industrial, commercial, heating, or cooling purposes. CHP, also known as cogeneration, can convert energy more efficiently than facilities that separately produce heat and electricity. Plants in eGRID are designated as CHP facilities based on information from the EIA-860, EIA-923, and Department of Energy Combined Heat and Power Database datasets (EIA, 2019b; DOE, 2018). A flag indicating whether or not a plant is a CHP facility is included in the eGRID Plant file. Since emissions reported in eGRID represent electricity generation only, emissions associated with useful thermal outputthe amount of heat produced in a CHP facility that is used for purposes other than making electricityare excluded from the adjusted emissions. eGRID's CHP adjustment methodology is designed to allocate emissions for CHP plants between electricity and thermal output. If a plant is a CHP facility, the adjustment is applied to the emissions and heat input for the entire plant after any biomass adjustment has been made. 4 Note that this factor was converted from units of lb/standard cubic foot (scf) to tons/MMBtu based on a value of 500 Btu/scf (EPA, 2016). " cc meal Support Document for eGRID2018 | pg, 23 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS The methodology is based on multiplying emissions and heat input by an electric allocation factor, which is calculated as follows: 1. Calculate the useful thermal output. EIA-923 reports both total fuel consumption and fuel consumption for electricity generation.5 The useful thermal output value for eGRID2018 data is calculated from EIA-923 data as 0.8 multiplied by the difference in total heat input and electricity heat input in MMBtu. The value of 0.8 is an assumed efficiency factor from the combustion of the consumed fuel (EIA, 2019b). Useful Thermal Output = 0.8 x (Total Heat Input Electric Heat Input) 2. The electric allocation factor is calculated as the ratio of the electricity heat output to the sum of the electricity and steam heat outputs, where electricity heat output is the net generation in MWh multiplied by 3.413 to convert it to MMBtu, and steam heat output is 0.75 multiplied by the useful thermal output, in MMBtu. The 0.75 factor is another assumed efficiency factor, which accounts for the fact that once fuel is combusted for electricity generation, approximately 75 percent of the useful thermal output can be utilized for other purposes, such as space heating or industrial processes.6 3.413 x Net Generation Electric Allocation Factor = (0.75 x Useful Thermal Output) + (3.413 x Net Generation) If the useful thermal output is zero, then the electric allocation factor is set to one. The electric allocation factor should be between zero and one. If the electric allocation factor is calculated to be greater than one, it is set to one, and if the electric allocation factor is calculated to be less than zero, it is set to zero. In previous editions of eGRID, the CHP adjustment methodology involved a process for estimating the electric allocation factor in cases where a unit is listed as a CHP unit, but the total heat input and electric heat input reported by EIA were reported as equal. In discussions with EIA, we have determined that in these cases, there should be no CHP adjustment made. Therefore, for units listed as CHP units, but with a total heat input equal to the electric heat input, the useful thermal output is calculated to be 0, and the electric allocation factor is set to 1. This assumes that all of the heat input for these units is used for electricity generation and that useful thermal output is not produced. For plants that have a CHP adjustment, the amount of heat input and emissions that the total emissions are adjusted by are included in eGRID2018. The emissions adjustment values from heat input, NOx, SO2, CO2, CH4, and N2O are listed for plants with a CHP flag. Table A-3 in Appendix A has a list of all the new fields added to the Plant file, including the CHP heat input and emissions 5 CHP facilities do not report these values to EIA separately. They only report total fuel consumption, and EIA estimates the fuel consumption for electricity generation. 6 This assumes that the CHP units generate electricity first and use the waste heat for other purposes, also known as "topping." While there are some units that generate and use heat first and then use the waste heat to generate electricity, also known as "bottoming," data from the EIA shows that the vast majority of CHP facilities are topping facilities. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS adjustment values. Note that for plants that have both a biomass flag and a CHP flag, the unadjusted emissions multiplied by the electric allocation factor will not match the adjusted emissions value. For these plants, the biomass adjustment value needs to be accounted for as well. See Section 3.1.2.3 below for a sample calculation of a plant with both a biomass and CHP adjustment. 3.1.2.3 Plant-level adjustment example calculation There are several plants that have both a biomass adjustment and a CHP adjustment. The following calculation steps are used to determine the final presented CO2 adjusted emission values. 1. The biomass emissions are determined in accordance with section 3.1.2.1 and removed from the plant unadjusted annual CO2 emissions. UNC02 BI0C02 = PLC02bioremoved Where; UNC02 = plant unadjusted annual CO2 emissions BI0C02 = plant annual CO2 biomass emissions PLC02bio removed = plant annual CO2 emissions without biomass (intermediate value) 2. The electric allocation factor is determined in accordance with section 3.1.2.2 and the CHP adjustment is then conducted by multiplying the biomass adjusted plant emissions by the electric allocation factor. PLC02 jjIq removed ^ ELALLOC = PLC02AN Where; PLC02bio removed = plant annual CO2 emissions without biomass (intermediate value) ELALLOC = electric allocation factor (see section 3.1.2.2) PLC02AN = plant annual CO2 emissions (biomass and CHP adjusted) 3. The amount of CHP adjusted emissions are determined by subtracting the final adjusted plant emissions from the plant annual CO2 biomass emissions. PLC02bioremoved -PLC02AN = CHPC02 Where; PLC02bio removed = plant annual CO2 emissions without biomass (intermediate value) PLC02AN = plant annual CO2 emissions (biomass and CHP adjusted) CHPC02 = plant annual CO2 emissions CHP adjustment value Table 3-2 and the following equations show an example calculation of how the adjustments are done together. Table 3-2. Example Biomass and CHP CO2 Emissions Adjustment Calculation Plant Name Fuel ELALLOC UNC02 (tons) BI0C02 (tons) CHPC02 (tons) PLC02AN (tons) Example Plant OBG 0.1989 75,817 65,289 8,434 2,094 Technical Support Document for eGRID2018 I P9-25 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS 1. 75,817 tons 62,289 tons = 10,528 tons 2. 10,528 tons x 0.1989 = 2,094 tons 3. 10,528 tons 2,094 tons = 8,434 tons 3.1.3 Emission Rate Estimates Input and output emission rates are calculated for eGRID at the plant level in the Plant file, and the subsequent aggregated files. Annual and ozone season net generation and heat input values (adjusted for CHP plants) are required to calculate the emission rates. 3.1.3.1 Generation Net generation, in MWh, is the amount of electricity produced by the generator and transmitted to the electric grid. Net generation does not include any generation consumed by the plant. If generation consumed by the plant exceeds the gross generation of that plant, negative net generation will result. In these cases, the output emissions rates are set to 0, rather than report a negative emissions rate. Generator-level net generation as well as prime mover-level net generation is obtained from the EIA- 923. Ozone season generation is calculated by summing up the generation for the months of the ozone season, May through September (EIA, 2019b). The methodologies employed for obtaining year 2018 net generation data are described below. Generator-Level Net Generation The EIA-923 dataset reports generator-level generation for a subset of generators. This generator- level generation is reported in the Generator File in eGRID2018. For all other generators, which do not have data on generator-level generation, prime mover-level net generation is distributed to the generators in the Generator file based on the proportion of nameplate capacity of generators with that prime mover at a given plant. Ozone season net generation uses the same methodology, but only includes generation data for May to September. Annual and ozone season generation is distributed to generators with a status of operating, standby/backup, out of service but was operating for part of the data year, or retired if the retirement year is 2018. Generation is not distributed to generators if the generator is not yet in operation or retired before 2018. In some cases the sum of the generator-level generation does not equal the plant-level generation, even if all generator-level generation is available for all generators. In order to ensure that the generation in eGRID matches the plant-level generation data from EIA, distributed prime mover-level data are used in some cases in place of generator-level generation data. As explained above, some generator-level net generation data are missing or not reported for various generators in the 2018 EIA-923. EIA aggregates these missing data to the state level by fuel type, but it is not possible to distribute them back to the generator level accurately (EIA, 2019b). Plant-Level Net Generation The annual generation data in the Plant file are the sum of all generator-level generation at the plant from the Generator file. The ozone season generation data in the Plant file are a sum of all ozone season (May-September) generator-level generation at the plant from the Generator file. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS Combustion net generation is also developed (as is non-combustion generation) based on the fuel type generation of each plant. For plants that are only composed of combustion generating units, the plant combustion net generation is the same as the total plant net generation. For plants that have both combustion and non-combustion generating units, the combustion net generation will be less than the total net generation for that plant. 3.1.3.2 Heat Input Heat input, in MMBtu, is the amount of heat energy consumed by a generating unit that combusts fuel. The method for assigning unit-level heat input follows the same process as the method for assigning unit-level CO2 emissions (see section 3.1.1.1). Annual and ozone season unit-level heat input for eGRID is initially obtained from the reported EPA/CAMD emissions data. EPA/CAMD heat input is based either on stack flow and CO2/O2 monitoring or fuel flow and the heat content of fuel. If EPA/CAMD unit level heat input data are not reported or the overall plant is not included in the EPA/CAMD data, annual and ozone heat input data are obtained at the unit level or prime mover level from the EIA-923 monthly data (EIA, 2019b). For units that only report ozone season heat input to EPA/CAMD, a methodology is used to add the additional heat input for non-ozone season months from the EIA-923 (see discussion in Section 3.1.1.1). The Unit file unit level heat input is summed to the plant level and reported in the Plant file. 3.1.3.3 Emission Rates Output, input, and combustion emission rates are reported in the Plant, State, Balancing Authority, eGRID Subregion, NERC Region, and US eGRID files. The fuel-based and nonbaseload emission rates are reported in the State, Balancing Authority, eGRID Subregion, NERC Region, and US eGRID files. Output and Input Emission Rates Output emission rates for SO2, NOx, CO2, C02e, CH4, and N2O in lb/MWh, are reported in the Plant file. The output emission rates are calculated as total annual adjusted emissions divided by annual net generation. Input emission rates for SO2, NOx, and CO2, in lb/MMBtu, are calculated as the total annual emissions divided by the annual heat input. Fuel-based Emission Rates For the State, Balancing Authority, eGRID Subregion, NERC Region, and US eGRID files, coal, oil, gas, and fossil fuel output and input emission rates are calculated based on a plant's primary fuel (see Section 3.2). If a plant's primary fuel is coal, oil, gas, or another fossil fuel, then all of its adjusted emissions, adjusted heat input, and net generation from combustion are included in the respective aggregation level for that fuel category. For example, all plants in Alabama with coal as primary fuel will have their emissions, heat input, and combustion net generation summed to the state level and then the appropriate calculations will be applied to determine the coal-based output and input emission rates for Alabama. See Table 3-3 for a list of primary fuels and fuel categories used for fuel- based emission rates in the State, Balancing Authority, eGRID Subregion, NERC Region, and US eGRID files. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS Table 3-3. Fuel-based Emission Rates - Primary Fuel Category Fuel Code Description Fuel Category BIT Bituminous coal Coal LIG Lignite coal Coal SUB Subbituminous coal Coal RC Refined coal Coal WC Waste coal Coal SGC Coal-derived synthetic gas Coal COG Coke oven gas Coal NG Natural gas Gas BU Butane gas Gas DFO Distillate fuel oil Oil JF Jet fuel Oil KER Kerosene Oil PC Petroleum coke Oil RG Refinery gas Oil RFO Residual fuel oil Oil WO Waste oil Oil BFG Blast furnace gas Other fossil OG Other gas Other fossil TDF Tire-derived fuel Other fossil Nonbaseload Emission Rates In addition to emission rates for all plants, eGRID also reports emission rates for nonbaseload plants in the State, Balancing Authority, eGRID Subregion, NERC Region, and US eGRID files. The nonbaseload emission rates are sometimes used as an estimate to determine the emissions that could be avoided through projects that displace marginal fossil fuel generation, such as energy efficiency and/or renewable energy. Capacity factor is used as a surrogate for determining the amount of nonbaseload generation and emissions that occur at each plant. While there are other factors that can influence a particular unit's capacity factor besides dispatch or load order (e.g. maintenance and repairs), capacity factor is used as a surrogate for dispatch-order for this calculation. The nonbaseload information is published in eGRID at the aggregate level (state, balancing authority, eGRID subregion, NERC region, and the US), but not for individual plants. The nonbaseload emission rates are determined based on the plant-level capacity factor. All generation and emissions at plants with a low capacity factor (less than 0.2) are considered nonbaseload and are assigned a nonbaseload factor of 1. Plants with a capacity factor greater than 0.8 are considered baseload and are assigned a nonbaseload factor of 0. For plants with a capacity factor Technical Support Document for eGRID2018 I pg-28 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS between 0.2 and 0.8, we use a linear relationship to determine the percent of generation and emissions that is nonbaseload: Nonbaseload Factor = 5/3 x (Capacity Factor) + 4/3 To aggregate the nonbaseload generation and emissions, the plant-level generation and emissions are multiplied by the nonbaseload factor and summed to the state, balancing authority, eGRID subregion, NERC region, and US levels. The aggregated nonbaseload emissions and generation are used to calculate the nonbaseload output emission rates. While nonbaseload rates can be used to estimate the emissions reductions associated with projects that displace electricity generation, such as energy efficiency and/or renewable energy, these rates should not be used for assigning an emission value for electricity use in carbon-footprinting exercises or GHG emissions inventory efforts. Rather, eGRID subregion-level total output emission rates are recommended for estimating emissions associated with electricity use (scope 2 emissions). Note that generation from renewable fuels is not included in the nonbaseload calculations. Combustion Emission Rates Combustion output emission rates for all pollutants are estimated at the plant level and higher levels of aggregation. Combustion fuel-based output emissions rates are calculated by dividing total plant emissions by the combustion net generation for that plant. Generation from non-combustion sources, such as nuclear, hydro, geothermal, solar, and wind will not be included in the calculation of this rate. 3.2 Determination of Plant Primary Fuel The primary fuel of a plant is determined solely by the fuel that has the maximum heat input in the Unit file. For plants that do not consume any combustible fuel, the primary "fuel" is determined by the nameplate capacity of the units at the plant. The fuel from the unit with the highest nameplate capacity is used as the primary fuel. See Section 5 for a description of all possible unit and plant primary fuel codes. The EIA-923 includes solid waste plants as two fuel codes: municipal solid waste - biomass (MSB) and municipal solid waste - non-biomass (MSN). The EIA-860 only lists municipal solid waste under one code (MSW). In eGRID2018 the MSW fuel code is the only fuel code used for municipal solid waste in the Unit, Generator, and Plant files. While the MSB/MSN EIA-923 fuel information is used to calculate biomass adjusted emissions, these fuel codes are not listed in eGRID2018. See Section 3.1.2.1 for a discussion of the biomass adjustment methodology (EIA, 2019b). 3.3 Estimation of Resource Mix The resource mix is the collection of nonrenewable and renewable resources that are used to generate electricity for a plant. Nonrenewable resources include fossil fuels (e.g., coal, oil, gas, and other fossil) and nuclear energy sources; renewable energy resources include biomass, solar, wind, geothermal, and hydro. The resource mix is determined by calculating the percentage of the total generation that a given nonrenewable or renewable resource generated. In eGRID, the resource mix is Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS represented as generation, in MWh, for each nonrenewable or renewable resource category, as well as a percentage of the total. Each category for nonrenewable and renewable resources should sum to be 100 percent. eGRID plant resource mix and net generation are derived from the EIA-923 prime mover level data. For cases in which there is only one fuel and its generation is negative, that fuel's generation percent is assigned 100%. For cases in which there are fuels with both negative and positive net generation, the generation percentages only include the positive generation in both the denominator and numerator. For the three grouped aggregate categoriestotal net generation from nonrenewables, total net generation from all renewables, and total net generation from renewables minus hydrothe sum of the total net generation from nonrenewables and from all renewables equals the total net generation. It should be noted that there are cases where the sum of the generation by fuel type does not equal the value reported for total annual generation in eGRID. This is because the total annual generation is calculated using a mix of generator- and prime mover-level data from the EIA-923. The calculation of generation by fuel type uses only prime mover-level data (EIA, 2019b). 3.4 Aggregating Plant-Level Data eGRID includes five aggregated files based on the Plant file: State, Balancing Authority (BA), eGRID Subregion, NERC Region, and the US. The State file data are developed by summing up the Plant file data (adjusted heat input, adjusted emissions, adjusted fuel-based emissions, net generation, fuel-based net generation, nameplate capacity, and the plant data values needed to calculate nonbaseload emission rates), based on the state in which the plant is located. The Balancing Authority, eGRID Subregion, and NERC Region files are developed by summing up the plant data for each of the values for each aggregation level. However, the Balancing Authority file in eGRID2018 only includes balancing authorities with positive generation and/or emissions. The balancing authorities with zero generation and/or emission data have not been included in the Balancing Authority file. The US file is developed by taking the sum of all fields for all plants from the Plant file. Emission rates are recalculated at the state, balancing authority, eGRID subregion, NERC region, and US levels. Nonbaseload emission rates have also been included at the aggregated level. For a list of all variables included in the aggregated files, see Sections 5.4 through 5.8. The totals from the Plant, State, Balancing Authority, eGRID Subregion, NERC Region, and US files' adjusted heat input, adjusted emissions, adjusted fuel-based emissions, net generation, fuel- based net generation, and nameplate capacity data are equal, accounting for minor differences due to rounding. The following sections describe three of the levels of aggregation used to summarize the data from the Plant file, including the balancing authority, eGRID subregion, and NERC region levels. 3.4.1 Balancing Authority A balancing authority is a portion of an integrated power grid for which a single dispatcher has operational control of all electric generators. A balancing authority is the responsible entity that Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS integrates resource plans ahead of time, maintains demand and resource balance within a BA area, and supports interconnection frequency in real time. The balancing authority dispatches generators in order to meet an area's needs and can also control load to maintain the load-generation balance. Balancing authority ID codes are assigned to a plant based on the EIA-860 plant-level data and the balancing authority names are assigned to the corresponding balancing authority ID codes based on the EIA-861 (EIA, 2019a; EIA, 2019c). In Alaska and Hawaii, isolated electric utility systems, which are not part of an integrated power grid, have been grouped into nominal balancing authorities titled Alaska Miscellaneous and Hawaii Miscellaneous, respectively. These three balancing authorities have an ID code of "NA" since there are no ID codes available from EIA for these regions. Other plants with no listed balancing authority ID in the EIA-860 plant-level data have a code of "NA" and name of "No Balancing Authority" in eGRID2018. The balancing authority associated with a plant is reported to the EIA-860 plant-level data and used in eGRID2018. Since BAs are not strictly geographically based, shapefiles for mapping them are not available with eGRID2018. 3.4.2 eGRID Subregion eGRID subregions are identified and defined by EPA and were developed as a compromise between NERC regions (which EPA felt were too big) and balancing authorities (which EPA felt were generally too small). Using NERC regions and balancing authorities as a guide, the subregions were defined to limit the import and export of electricity in order to establish an aggregated area where the determined emission rates most accurately matched the generation and emissions from the plants within that subregion. A map of the eGRID subregions used for eGRID2018 is included in Appendix B. This map is representational and shows approximate boundaries that are based on electrical grid attributes, not on strict geographical boundaries.7 The 26 eGRID subregions are subsets of the NERC regions as configured in December 2010. The eGRID subregions themselves have not changed substantially since eGRID2000. Note, however, that some plants operating in each eGRID subregion can change from year to year. Plants are assigned to eGRID subregions in a multi-step process using NERC regions, balancing authorities (BAs), Transmission IDs, utility IDs, and NERC assessment data as a guide. First, there are two NERC regions that are located entirely within an eGRID subregion. Plants in NERC regions TRE (within eGRID subregion ERCT) and FRCC (within eGRID subregion FRCC) are directly assigned the corresponding eGRID subregion. About 10% of the plants are assigned using only the NERC region as a guide. Second, plants in BAs where the entire BA is located within the boundaries of an eGRID subregion are assigned accordingly (e.g., BA CISO is entirely within the boundaries of eGRID subregion CAMX). There are 59 BAs that have a one-to-one match with eGRID subregions. 7 Note that some areas may fall into multiple eGRID subregions due to the fact that they are supplied by multiple electricity providers. Visit Power Profiler (https://www.epa.gov/energv/power-profiler') for more information on determining the eGRID subregion for a given area. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS After the second step, about half of the plants are assigned to an eGRID subregion. The third step uses the Transmission or Distribution System Owner ID for each plant, reported in the EIA-860, in combination with their BA, to identify eGRID subregions for the remaining nine BAs that do not have a one-to-one match with an eGRID subregion. About 99% of the plants are assigned an eGRID subregion after step three. There are some plants that do not report Transmission ID or where the Transmission ID and BA span multiple eGRID subregions so an additional step using Utility ID, reported in the EIA-860, is used to identify additional eGRID subregion matches. After this fourth step, all but about 0.5% of the plants have been assigned. The last step in the process uses Long Term Reliability Assessment data, received from NERC, to assign additional plants to eGRID subregions based on the NERC assessment area. After completing these five steps, in eGRID2018 there were 24 plants that were not assigned to an eGRID subregion. Only one of these plants, the New Melones plant in CA (ORIS 6158), was operational in 2018. The historical assignments were retained for these plants, if applicable. For unassigned plants that were new plants in 2018, manual assignments were made based on the plant's physical location. The 26 eGRID subregion names and their acronyms for eGRID are displayed in Table 3-4. Table 3-4. eGRID Subregion Acronym and Names for eGRID eGRID Subregion eGRID Subregion Name FRCC FRCC All MROE MRO East MROW MRO West NEWE NPCC New England NYCW NPCC NYC/Westchester NYLI NPCC Long Island NYUP NPCC Upstate NY RFCE RFC East RFCM RFC Michigan RFCW RFC West SRMW SERC Midwest SRMV SERC Mississippi Valley SRSO SERC South SRTV SERC Tennessee Valley SRVC SERC Virginia/Carolina SPNO SPP North SPSO SPP South CAMX WECC California NWPP WECC Northwest RMPA WECC Rockies AZNM WECC Southwest Technical Support Document for eGRID2018 I pg-32 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS eGRID Subregion eGRID Subregion Name ERCT ERCOT All AKGD ASCC Alaska Grid AKMS ASCC Miscellaneous HIOA HICC Oahu HIMS HICC Miscellaneous 3.4.3 NERC Region NERC region refers to a region designated by the North American Electric Reliability Corporation (NERC). Each NERC region listed in eGRID represents one of ten regional portions of the North American electricity transmission grid: eight in the contiguous United States, plus Alaska and Hawaii (which are not part of the formal NERC regions, but are considered so in eGRID). Note that some plants can change NERC region from year to year. The ten NERC region names and their acronyms for eGRID are displayed in Table 3-5. Although some NERC regions include portions of Canada and/or Mexico that are integrated with U.S. grids, eGRID aggregation data are limited to generation within the U.S. A representation of the NERC region map used for eGRID is included in Figure B-2 in Appendix B. This map is representational and shows approximate boundaries that are not based on strict geographical boundaries. Table 3-5. NERC Region Acronym and Names for eGRID NERC Region NERC Name ASCC Alaska Systems Coordinating Council FRCC Florida Reliability Coordinating Council HICC Hawaiian Islands Coordinating Council MRO Midwest Reliability Organization NPCC Northeast Power Coordinating Council RFC Reliability First Corporation SERC SERC Reliability Corporation TRE Texas Regional Entity WECC Western Electricity Coordinating Council Note that as of 2018, SPP was no longer a NERC region (FERC, 2018). 3.5 Grid Gross Loss eGRID output emission rates do not account for any line losses between the points of consumption and the points of generation. For example, because there are line losses, one kilowatt hour of electricity consumption requires a little more than one kilowatt hour of electricity generation. To account for transmission and distribution line losses when applying eGRID output emission rates to Technical Support Document for eGRID2018 I P9-33 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS electricity consumption within a certain region, consumption is divided by (one minus the grid gross loss [as a decimal]) (Table 3-6). The methodology for calculating grid gross loss uses data from EIA's State Electricity Profiles.8 Utilities report the information used in these calculations directly to EIA through EIA-861. To align more closely with EIA estimates, the methodology for calculating GGL changed slightly in 2017. The previous methodology used for eGRID2014 and eGRID2016 did not account for interstate trade values that were included in total disposition for each state, which led to a slight double counting of values. The revised methodology excludes net exports from each state's total disposition. The formula for calculating GGL remains nearly the same as the previous methodology, with the exception that net interstate exports are subtracted from the total disposition in the denominator. The methodology for estimating grid gross loss uses the following data points for each state from the EIA State Electricity Profiles: 1. Total Disposition. This is the total amount of electricity sold directly to customers, sold for resale, furnished without charge, consumed by the respondent without charge, and lost. It is equal to the total amount of electricity generated. 2. Net Interstate Exports. This is the total amount of electricity exported to other states. 3. Direct Use. This is the total amount of electricity used by plants and/or utilities in the region that is not sold for wholesale or resale; direct use electricity is not transmitted through the grid and therefore does not have the potential to be lost. 4. Estimated Losses. This is the total amount of electricity, in MWh, in the region that is generated but is not sold for resale or wholesale, furnished without charge, or used by the generator or utility; i.e., electricity that is lost in transmission and distribution. These data are reported at the state level by EIA. We aggregate them to the NERC Interconnect level (Eastern, Western, ERCOT (Texas), as well as the states of Alaska and Hawaii, and the entire U.S.). State boundaries, however, do not perfectly correspond to Interconnect boundaries. Four states (Montana, Nebraska, New Mexico, and South Dakota) have generation in two Interconnects, and one state (Texas) has generation in three Interconnects. For these states, we distributed the data from the State Electricity Profiles based on the proportion of generation from these states in each Interconnect from the EIA-923 (EIA, 2019b). The aggregated data are then used to calculate grid gross loss as follows: Estimated Losses Grid Gross Loss = Total Disposition without Exports Direct Use The eGRID2018estimated grid gross loss percentages for each U.S. interconnect power grid are included in the file called "GGL18" in the eGRID workbook and are also displayed in Table 3-6. 8 Available at: http://www.eia.gov/electricity/state/ See Table 10: Supply and disposition of electricity Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS Table 3-6. eGRID2018 Grid Gross Loss (%) Power Grid Grid Gross Loss (%) Eastern 4.88% Western 4.80% ERCOT 4.87% Alaska 5.12% Hawaii 5.14% U.S. 4.87% "cc 1 lical Support Document c<,>K D2018 | pg, 35 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS 4. Specific eGRID Identifier Codes, Name Changes, and Associations 4.1 Plant Level 4.1.1 Plant ID Changes Some changes to EIA ORISPL ID codes are made in eGRID2018 to better reflect the EPA/CAMD data. Also, some EIA plants are combined into single plants to reflect EPA/CAMD data. The plants ArcelorMittal Indiana Harbor West and Indiana Harbor E 5 AC Station (ORISPL 10397 and 54995, respectively) are combined and the ORISPL changed to 10474 to match with the EPA/CAMD plant ArcelorMittal USA - Indiana Harbor East. The plants Sundevil Power Holdings - Gila River and Gila River Power Block 3 (ORISPL 59338 and 59784, respectively) are combined and the ORISPL changed to 55306 to match with the EPA/CAMD plant Gila River Power Station. A table of ORISPL ID code changes can be found in Table C-5 in Appendix C. 4.1.2 Longitude/Latitude Updates The following plants had the wrong latitude and longitude listed in the EIA-860 Plant file. The following updates, shown in Table 4-1, have been made based on the address provided in the EIA- 860 Plant file for each plant. Table 4-1. eGRID2018 Latitude/Longitude Updates Plant ID Plant Name Latitude Longitude 62262 Rolling Upland Wind Farm LLC 42.899029 -75.458456 62715 Wildcat Creek Wind Farm LLC 33.550555 -97.329444 62801 ORNI 34 LLC 34.407284 -119.511582 4.1.3 EPA/CAMD Plants Not Connected to the Grid There are several plants included in the EPA/CAMD data that are not connected to the electric grid. Therefore, these plants have been removed from eGRID2018 and are listed in Table 4-2 below. Technical Support Document for eGR!D2018 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS Table 4-2. eGRID2018 EPA/CAMD Plants Not Connected to the Grid Plant ID State Plant Name 478 CO Zuni 1594 MA Blackstone 2440 SC AbiBow US Inc. - Catawba Operations 2549 NY Huntley Power 10071 VA Virginia Renewable Power-Portsmouth LLC 10111 Ml DTE Pontiac North LLC 10381 NC Coastal Carolina Clean Power LLC 10675 CT AES Thames 10788 WV Chemours Belle Plant 50044 OH The Ohio State University 50151 WV UCC South Charleston Plant 50202 NY Niagara Generation, LLC 50247 OH Smart Papers LLC 50607 PA Veolia Energy Philadelphia - Schuylkill 54035 NC Roanoke Valley Energy Facility I 54571 PA North East Cogeneration Plant 54755 NC Roanoke Valley Energy Facility II 55098 TX Frontera Generation Facility 55422 FL Desoto County Energy Park 55703 TN Valero Refining Company-Tennessee, LLC "cc 1 lical Support Document c<,>K D2018 | pg, 37 ------- DESCRIPTION OF DATA ELEMENTS 5. Description of Data Elements eGRID2018 has 8 aggregation files: UNIT (unit), GEN (generator), PLNT (plant), ST (state), BA (Balancing Authority), SRL (eGRID subregion), NRL (NERC region), and the US (United States total). eGRID2018 also includes the regional grid gross loss factor data. Appendix A provides the file structure for eGRID2018, which includes variable descriptions and original data sources. Note that definitions for similar variables are not repeated after the description in the Plant file. For example, in the Plant file, the net generation in MWh is defined at the plant level for the data element PLNGENAN. For each subsequent file, the net generation, XXNGENAN (where XX is ST, BA, SR, NR, or the US) is not defined; it is simply the sum of PLNGENAN attributed to the aggregation entity. Note that values reported as 0 in eGRID are reported as 0 in the original data files. Values reported as blank in eGRID are either reported as blank in the original data files or are not included in the original data files. The following data element descriptions apply to fields in both the English unit and metric unit workbooks, but the descriptions below only are only represented in English units. 5.1 The UNIT (Unit) File There are 32 variables in the Unit file, which contains unit-level data. 1. eGRID2018 Unit File Sequence Number (SEQUNT18) - Unit-level records in the 2018 data file are sorted by state abbreviation, plant name, plant code, and unit ID, and are assigned a unique sequential number beginning with 1. This sequence number is unlikely to be the same as the sequence number in the eGRID2016 file for the same entity. 2. Data Year (YEAR) - The current eGRID data year. 3. Plant State Abbreviation (PSTATABB) - The state abbreviation of the state in which the plant is located. Source: EIA-860 4. Plant Name (PNAME) - The name associated with each plant. Source: EPA/CAMD; EIA-860 5. DOE/EIA ORIS Plant or Facility Code (ORISPL) - This plant code corresponds to PNAME and was originally developed for power plants by the Office of Regulatory Information Systems (ORIS), which was a part of the Federal Power Commission. It is now assigned by EIA and is used as a unique plant identification code for many EPA electric power databases. Note that some EIA ORISPL ID codes were changed to reflect EPA/CAMD ORISPL ID codes. See Section 4.1 for a discussion of ORISPL ID changes made to eGRID2018. See Appendix C for a table of all ORISPL changes made between EIA and EPA/CAMD. Source: EPA/CAMD; EIA-860 Technical Support Document for eGRID2018 I P9-38 ------- DESCRIPTION OF DATA ELEMENTS 6. Unit ID (UNITID) - The unit ID for the unit that produces the emissions. Source: EPA/CAMD, EIA-923 7. Prime Mover (PRMVR) - The unit's electric prime mover type. Possible values are: BA = Battery energy storage BT = Binary cycle turbine CA = Combined cycle steam turbine CC = Combined cycle - total unit CE = Compressed air energy storage CP = Concentrated solar power energy storage CS = Combined cycle - single shaft CT = Combined cycle combustion turbine FC = Fuel cell FW = Flywheel energy storage GT = Combustion (gas) turbine HY = Hydroelectric turbine IC = Internal combustion engine (diesel) OT = Other turbine PS = Hydraulic turbine - reversible (pumped storage) PV = Photovoltaic ST = Steam turbine (boiler, nuclear, geothermal, and solar steam) WS = Wind turbine - offshore WT = Wind turbine - onshore Source: EIA-860 8. Unit Operational Status (UNTOPST) - The unit's operational status in 2018. Possible values are: CN = Cancelled (previously reported as "planned") Future = Planned new generator IP = Planned new generator canceled, indefinitely postponed, or no longer in resource plan L = Regulatory approvals pending (not under construction) OA = Out of service (returned or will be returned to service) OP = Operating - in service OS = Out of service (not expected to be returned to service) OT = Other P = Planned for installation but regulatory approvals not initiated (not under construction) RE = Retired - no longer in service SB = Stand-by (long-term storage) SC = Cold stand-by (reserve); deactivated T = Regulatory approvals received (not under construction) TS = Testing, construction complete, but not yet in commercial operation Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS u v Under construction, less than 50% constructed Under construction, more than 50% constructed Source: EPA/CAMD, EIA-860 9. Clean Air Markets Division (CAMD) Program Flag (CAMDFLAG) - Indicates if the unit reported 2018 EPA/CAMD emissions and operation data to comply with either the Cross-State Air Pollution Rule or the Acid Rain Program. See https://www.epa.gov/airmarkets/clean-air-markets-programs for additional information. Source: EPA/CAMD 10. Program Codes (PRGCODE) - The programs, as reported to EPA/CAMD, that the unit was subject to in 2018. Values may be combined and separated by commas. The individual values are: ARP = Acid Rain Program CSNOX = Cross-State Air Pollution Rule for NOx (annual) CSOSG1, CSOSG2 = Cross-State Air Pollution Rule NOx Ozone Season Program See https://www.epa.gov/airmarkets/clean-air-markets-programs for additional information. Source: EPA/CAMD 11. Unit Bottom and Firing Type (BOTFIRTY) - The unit firing type. Possible values are: MATS NHNOX NSPS4T RGGI CSS02G1, CSS02G2 SIPNOX (Group 1, Group 2) = Cross-State Air Pollution Rule for SO2 (Group 1, Group 2) = Mercury and Air Toxics Standards = New Hampshire's special NOx program = New Source Performance Standards Subpart TTTT Program = Regional Greenhouse Gas Initiative = NOx SIP Call CC CELL CT CYCLONE DUCTBURNER FLUIDIZED IGC OTHER BOILER OTHER TURBINE PROCESS STOKER TANGENTIAL TURBO Blank Combined cycle Cell Combustion turbine Cyclone firing Ductburner Fluidized bed firing Integrated gasification combined cycle Other boiler Other turbine Refinery process heater Stoker, spreader, vibrating grate, or slinger boiler Tangential, concentric, or corner-fired boiler Turbo Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS VERTICAL VERTICAL/ARCH WALL = Vertically-fired boiler = Vertical or arch firing = Wall-fired boiler Source: EPA/CAMD, EIA-860 12. Number of Associated Generators (NUMGEN) - The number of generators associated with each EIA-860 boiler in the file. Source: EIA-860 13. Unit Primary Fuel (FUELU1) - The primary fuel determined from EIA-923 boiler or generator reported data or the primary fuel reported to EPA/CAMD. Possible values are: AB = Agricultural byproduct BFG = Blast furnace gas BIT = Bituminous coal BLQ = Black liquor COG = Coke oven gas DFO = Distillate fuel oil, light fuel oil, diesel oil GEO = Geothermal JF = Jet fuel KER = Kerosene LFG = Landfill gas LIG = Lignite coal MSW = Municipal solid waste MWH = Electricity used for energy storage (megawatt hour) NG = Natural gas NUC = Nuclear OBG = Other biomass gas (digester gas, methane, and other biomass gases) OBL = Other biomass liquids OBS = Other biomass solid OG = Other gas OTH = Other PC = Petroleum coke PG = Gaseous propane PRG = Process gas PUR = Purchased steam RC = Refined coal RFO = Residual fuel oil, heavy fuel oil, petroleum SGC = Coal-derived synthetic gas SLW = Sludge waste SUB = Subbituminous coal SUN = Solar TDF = Tire-derived fuel WAT = Water WC = Waste coal WDL = Wood, wood waste liquid WDS = Wood, wood waste solid Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS WH = Waste heat WND = Wind WO = Waste oil Source: EPA/CAMD, EIA-923, EIA-860 14. Unit Operating Hours (HRSOP) - The number of hours that an EPA/CAMD unit reported operating during the year. Source: EPA/CAMD 15. Unit Unadjusted Annual Heat Input (HTIAN) - The unit's unadjusted annual total heat input, in MMBtu, based on the values reported to EPA/CAMD or calculated using EIA-923 unit data. Source: EPA/CAMD; EIA-923 16. Unit Unadjusted Ozone Season Heat Input (HTIOZ) - The unit's unadjusted ozone season (May through September) heat input, in MMBtu, based on the values reported to EPA/CAMD or calculated using EIA-923 unit data. Source: EPA/CAMD; EIA-923 17. Unit Unadjusted Annual NOx Emissions (NOXAN) - The unit's unadjusted NOx emissions, in short tons, based on the values reported to EPA/CAMD or calculated using EIA-923 unit data and unit-specific emissions rates or the emission factors listed in Appendix C. Source: EPA/CAMD; EIA-923 18. Unit Unadjusted Ozone Season NOx Emissions (NOXOZ) - The unit's unadjusted ozone season (May through September) NOx emissions, in short tons, based on values reported to EPA/CAMD or calculated using EIA-923 unit data and unit-specific ozone-season emissions rates or the emission factors listed in Appendix C. Source: EPA/CAMD; EIA-923 19. Unit Unadjusted Annual SO2 Emissions (S02AN) - The unit's unadjusted annual SO2 emissions, in short tons, based on the values reported to EPA/CAMD or calculated using EIA-923 unit data and the emission factors listed in Appendix C. When not available, it is zero. Source: EPA/CAMD; EIA-923 20. Unit Unadjusted Annual CO2 Emissions (C02AN) - The unit's unadjusted annual CO2 emissions, in short tons, based on the values reported to EPA/CAMD or calculated using EIA-923 unit data and emission factors listed in Appendix C. Source: EPA/CAMD; EIA-923 21. Unit unadjusted annual Hg emissions (HGAN) - The unit's unadjusted annual Hg emissions, in pounds, based on the values reported to EPA/CAMD. Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS Source: EPA/CAMD 22. Unit Unadjusted Annual Heat Input Source (HTIANSRC) Identifies the annual heat input data source. Source: EPA/CAMD; EIA-923 23. Unit Unadjusted Ozone Season Heat input source (HTIOZSRC) Identifies the ozone season heat input data source. Source: EPA/CAMD; EIA-923 24. Unit Unadjusted Annual NOx Emissions Source (NOXANSRC) Identifies the annual NOx emissions data source. Source: EPA/CAMD; EIA-923 25. Unit Unadjusted Ozone Season NOx Emissions Source (NOXOZSRC) Identifies the ozone-season NOx emissions data source. Source: EPA/CAMD; EIA-923 26. Unit Unadjusted Annual SO2 Emissions Source (S02SRC) Identifies the annual SO2 emissions data source. Source: EPA/CAMD; EIA-923 27. Unit Unadjusted Annual CO2 Emissions Source (C02SRC) Identifies the annual CO2 emissions data source. Source: EPA/CAMD; EIA-923 28. Unit Unadjusted Annual Hg Emissions Source (HGSRC) Identifies the annual Hg emissions data source. Source: EPA/CAMD 29. Unit SO2 (Scrubber) First Control Device (S02CTLDV) - The first reported SO2 control device. Values may be combined and separated by commas. Possible values are: = blank CD = Circulating dry scrubber DA = Dual alkali DL = Dry lime flue gas desulfurization unit DSI = Dry sorbent (powder) injection type EK = Electrostatic precipitator, cold side, without flue gas conditioning FBL = Fluidized bed JB = Jet bubbling reactor (wet) scrubber LIJ = Lime injection MA = Mechanically aided type (wet) scrubber 0 = Other (EPA/CAMD) OT = Other equipment (E1A-860) PA = Packed type (wet) scrubber SB = Sodium based SD = Spray dryer type/dry FGD/semi-dry FGD Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS SP = Spray type (wet) scrubber TR = Tray type (wet) scrubber VE = Venturi type (wet) scrubber WL = Wet lime flue gas desulfurization unit WLS = Wet limestone Source: EPA/CAMD, EIA-860 30. Unit NOx First Control Device (NOXCTLDV) - The first reported NOx control device. Values may be combined and separated by commas. Possible values are: = Blank CM = Combustion modification/fuel reburning DLNB = Dry low NOx premixed technology H20 = Water injection LNB = Low NOx burner LNBO = Low NOx burner with overfire air LNC1 = Low NOx burner technology with close-coupled overfire air LNC2 = Low NOx burner technology with separated OF A LNC3 = Low NOx burner technology with close-coupled and separated overfire air LNCB = Low NOx burner technology for cell burners NH3 = Ammonia injection O/OT = Other OFA = Overfire air SCR = Selective catalytic reduction (EPA/CAMD) SN = Selective noncatalytic reduction (EIA-860) SNCR = Selective noncatalytic reduction (EPA/CAMD) SR = Selective catalytic reduction (EIA-860) STM = Steam injection Source: EPA/CAMD 31. Unit Hg Activated Carbon Injected System Flag (HGCTLDV) - The activated carbon injection mercury control flag. Source: EIA-860 32. Unit Year On-Line (UNTYRONL) - The four-digit year the unit came on-line. Source: EPA/CAMD, EIA-860 5.2 The GEN (Generator) File There are 17 variables in the second file, GEN, which contains generator level data. This file includes generation from steam boilers and nuclear units in the EIA-923, plant prime movers in the EIA-923 that have only one generator in the EIA-860, and the EIA-923 plant prime movers where generation is distributed to the generator level based on nameplate capacity. 1. eGRID2018 File Generator Sequence Number (SEQGEN18) - Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 2. 3. 4. 5. 6. 7. 8. The generator records in the 2018 generator data file are sorted by state abbreviation, plant name, plant code, and generator ID, and are assigned a unique sequential number beginning with 1. This sequence number is unlikely to be the same as the sequence number in the eGRID2016 file for the same entity. Data Year (YEAR) - The current eGRID data year. Plant State Abbreviation (PSTATABB) - The state abbreviation in which the plant is located. Source: EIA-860 Plant Name (PNAME) - The name associated with each plant. Source: EPA/CAMD; EIA-860 DOE/EIA ORIS Plant or Facility Code (ORISPL) - This plant code was developed for power plants by the Office of Regulatory Information Systems (ORIS), which was a part of the Federal Power Commission. It is now assigned by EIA and is used as a unique plant identification code for many EPA electric power databases. Note that some EIA ORISPL ID codes were changed to reflect EPA/CAMD ORISPL ID codes. See Section 4.1 for a discussion of ORISPL ID changes made to eGRID2018. See Table C-5 in Appendix C for a table of all ORISPL changes made between EIA and EPA/CAMD. Source: EPA/CAMD; EIA-860 Generator ID (GENID) - The electrical generation unit (generator) at a plant. In the majority of cases, there is a one-to-one correspondence with the boiler ID if it is a steam generator. Sources: EIA-860 Number of Associated Boilers (NUMBLR) - The number of EIA-860 boilers associated with each generator in the file. Sources: EIA-860 Generator Status (GENSTAT) - The reported generator status at the end of 2018. Possible values are: CN = Cancelled (previously reported as "planned") IP = Planned new generator canceled, indefinitely postponed, or no longer in resource plan L OA OP OS OT = Regulatory approvals pending (not under construction) = Out of service (returned or will be returned to service) = Operating - in service = Out of service (not expected to be returned to service) = Other Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS P = Planned for installation but regulatory approvals not initiated (not under construction) RE = Retired - no longer in service SB = Stand-by (long-term storage) T = Regulatory approvals received (not under construction) TS = Testing, construction complete, but not yet in commercial operation U = Under construction, less than 50% constructed V = Under construction, more than 50% constructed Generators with one of these above generator status values are considered potentially operating generators (including generators with status = 'RE', if the retirement date is 2018 or later). Source: EIA-860 9. Generator Prime Mover Type (PRMVR) - The reported generator's electric generator type. Possible values are: BA = Battery energy storage BT = Binary cycle turbine CA = Combined cycle steam turbine CC = Combined cycle - total unit CE = Compressed air energy storage CP = Concentrated solar power energy storage CS = Combined cycle - single shaft CT = Combined cycle combustion turbine FC = Fuel cell FW = Flywheel energy storage GT = Combustion (gas) turbine HY = Hydroelectric turbine IC = Internal combustion engine (diesel) OT = Other turbine PS = Hydraulic turbine - reversible (pumped storage) PV = Photovoltaic ST = Steam turbine (boiler, nuclear, geothermal, and solar steam) WS = Wind turbine - offshore WT = Wind turbine - onshore Source: EIA-860 10. Generator Primary Fuel (FUELG1) - The potential primary fuel reported for the generator. Possible values are: Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS AB = Agricultural by-products BFG = Blast furnace gas BIT = Bituminous coal BLQ = Black liquor COG = Coke oven gas DFO = Distillate fuel oil, diesel, No. 1, No. 2, and No. 4 fuel oils GEO = Geothermal JF = Jet fuel KER = Kerosene LFG = Landfill gas LIG = Lignite coal MSW = Municipal solid waste MWH = Electricity NG = Natural gas NUC = Nuclear OBG = Other biomass gas (digester gas, methane, and other biomass gases) OBL = Other biomass liquids OBS = Other biomass solids OG = Other gas OTH = Other unknown PC = Petroleum coke PG = Gaseous propane PRG = Process gas PUR = Purchased steam RC = Refined coal RFO = Residual fuel oil SGC = Synthesis gas - coal-derived SGP = Synthesis gas - petroleum coke SUB = Subbituminous coal SUN = Solar TDF = Tire-derived fuel WAT = Water WC = Waste coal WDL = Wood waste liquid (excluding black liquor) WDS = Wood, wood waste solid WH = Waste heat WND = Wind WO = Waste oil Source: EIA-860 11. Generator Nameplate Capacity (NAMEPCAP) - The nameplate capacity, in MW, of the generator. Source: EIA-860 12. Generator Capacity Factor (CFACT) - This field is calculated at the generator level: CFACT = (GENNTAN) / (NAMEPCAP * 8760). The value should generally be between 0 and 1. However, according to reported data, there are outliers where, a generator's capacity factor is greater than 1. The capacity factor for plants with negative net generation is set to 0. Technical Support Document for eGRID2018 | pg. 47 ------- DESCRIPTION OF DATA ELEMENTS 13. Generator Annual Net Generation (GENNTAN) - The reported net generation in MWh. Sources: EIA-923 14. Generator Ozone Season Net Generation (GENNTOZ) - The generator five-month ozone season (May through September) net generation in MWh, based on monthly generator generation data. Sources: EIA-923 15. Generation Data Source (GENERSRC) - The data source of the generator net generation data. The values are as follows: Blank (no generator level data) Distributed from EIA-923 Generation and Fuel EIA-923 Generator File Data from EIA-923 Generator File overwritten with distributed data from EIA-923 Generation and Fuel 16. Generator Year On-Line (GENYRONL) - The four-digit year the generator came on-line. Source: EIA-860 17. Generator Planned or Actual Retirement Year (GENYRRET) - The four-digit year the generator retired or is planned to retire. Source: EIA-860 5.3 The PLNT (Plant) File There are 139 variables in the Plant file (PLNT). 1. eGRID2018 File Plant Sequence Number (SEQPLT18) - The plant records in the 2018plant data file are sorted by state abbreviation and plant name, and are assigned a unique sequential number beginning with 1. This sequence number is unlikely to be the same as the sequence number in the eGRID2016 file for the same entity. 2. Data Year (YEAR) - The current eGRID data year. 3. Plant State Abbreviation (PSTATABB) - The state abbreviation in which the plant is located. Source: EIA-860 4. Plant Name (PNAME) - The name associated with each plant. Source: EPA/CAMD; EIA-860 Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 5. DOE/EIA ORIS Plant or Facility Code (ORISPL) - This plant code corresponds to PNAME and was originally developed for power plants by the Office of Regulatory Information Systems (ORIS), which was a part of the Federal Power Commission. It is now assigned by EIA and is used as a unique plant identification code for many EPA electric power databases, too. Note that some EIA ORISPL ID codes were changed to reflect EPA/CAMD ORISPL ID codes. See Section 4.1 for a discussion of ORISPL ID changes made to eGRID2018. See Table C-5 in Appendix C for a table of all ORISPL changes made between EIA and EPA/CAMD. Source: EPA/CAMD; EIA-860 6. Plant Transmission or Distribution System Owner Name (OPRNAME) - The name associated with the owner of the transmission or distribution system company to which the plant is interconnected Source: EIA-860 7. Plant Transmission or Distribution System Owner ID (OPRCODE) - The transmission or distribution system owner ID. Each transmission or distribution system has a unique company code assigned by EIA, with some exceptions. Plants with no operating company ID assigned by EIA are listed as -9999 in eGRID2018. Source: EIA-860 8. Utility Name (UTLSRVNM) - The name of the owner of the utility service territory (a utility company or EGC) [and previously known as the utility service area] in which the plant is located. Source: EIA-860 9. Utility ID (UTLSRVID) - The unique ID code associated with the utility name. Source: EIA-860 10. Plant-level Sector (SECTOR) - The plant level sector name, assigned by the purpose, regulatory status, and CHP status at the plant. Possible values are: Commercial CHP Commercial Non-CHP Electric Utility Industrial CHP Industrial Non-CHP Independent Power Producer (IPP) CHP Independent Power Producer (IPP) Non-CHP Source: EIA-860 11. Balancing Authority Name (BANAME) - The name of the balancing authority for the plant. The balancing authority is associated with the plant's eGRID subregion and NERC region. "cc 1 lical Support Document c<,>K D2018 | pg, 49 ------- DESCRIPTION OF DATA ELEMENTS Source: EIA-860, EIA-861 12. Balancing Authority Code (BACODE) - The code of the balancing authority for the plant. Source: EIA-860, EIA-861 13. NERC Region Acronym (NERC) - The acronym for the NERC region in which the plant is located. The NERC region is associated with the plant's BA and eGRID subregion. A representation of the eGRID NERC region map is included in Appendix B. Source: EIA-860 14. eGRID Subregion Acronym (SUBRGN) - The acronym for the eGRID subregion in which the plant is located. The eGRID subregion is associated with the plant's balancing authority and NERC region. A representation of the eGRID subregion map is included in Appendix B. Source: EPA 15. eGRID Subregion Name (SRNAME) - The name of the eGRID subregion in which the plant is located. Source: EPA 16. Plant Associated ISO/RTO Territory (ISORTO) - The name, if applicable, of the Independent System Operator (ISO) or Regional Transmission Organization (RTO) associated with the plant. Possible values are CAISO, ERCOT, ISONE, MISO, NYISO, PJM, SPP, or blank. Source: EIA-860 17. Plant FIPS State Code (FIPSST) - The two-digit Federal Information Processing Standards (FIPS) state character code of the state in which the plant is located. The codes are from the National Institute of Standards and Technology (US Census, 2017). Source: US Census 18. Plant FIPS County Code (FIPSCNTY) - The three digit FIPS county character code of the county in which the plant is located. The codes are from the National Institute of Standards and Technology (US Census, 2017). Source: US Census 19. Plant County Name (CNTYNAME) - The name of the county in which the plant is located. Source: EIA-860 20. Plant Latitude (LAT) - The latitude, in degrees to four decimal places, associated with the plant. Source: EIA-860 Technical Support Document for eGRID2018 | pg. 50 ------- DESCRIPTION OF DATA ELEMENTS 21. Plant Longitude (LON) - The longitude, in degrees to four decimal places, associated with the plant. Source: EIA-860 22. Number of Units (NUMUNT) - The number of operating units within a plant. Source: EIA-860 23. Number of Generators (NUMGEN) - The number of potentially operating generators within a plant. Source: EIA-860 24. Plant Primary Fuel (PLPRMFL) - The plant's primary fuel based on maximum heat input of fuel consumed by the plant. If the plant does not consume fuel, it is based on the maximum nameplate capacity. Possible values are: AB = Agricultural byproduct BFG = Blast furnace gas BIT = Bituminous coal BLQ = Black liquor COG = Coke oven gas DFO = Distillate fuel oil, light fuel oil, diesel oil GEO = Geothermal steam JF = Jet fuel KER = Kerosene LFG = Landfill gas LIG = Lignite coal MSW = Municipal solid waste MWH = Electricity used for energy storage (megawatt hour) NG = Natural gas NUC = Nuclear material OBG = Other biomass gas OBL = Other biomass liquid OBS = Other biomass solid OG = Other gas OTH = Other (unknown) PC = Petroleum coke PRG = Process gas PUR = Purchased fuel (unknown) RC = Refined coal RFO = Residual fuel oil, heavy fuel oil, petroleum SGC = Coal-derived synthetic gas SUB = Subbituminous coal SUN = Sun TDF = Tire-derived fuel WAT = Water WC = Waste coal Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS WDL WDS WH WND WO = Wood, wood waste liquid = Wood, wood waste solid = Waste heat = Wind = Waste oil Source: EPA/CAMD; EIA-860 25. Plant Primary Coal/Oil/Gas/Other Fossil Fuel Category (PLFUELCT) - The fuel category for the primary fuel of the plant. This field is "COAL" if the plant's primary fuel is derived from coal (fuel type = BIT, COG, LIG, RC, SGC, SUB, WC), "OIL" if it is derived from oil (DFO, JF, KER, PC, RFO, WO), "GAS" if it is derived from gas (BU, NG, PG), "OFSL" if it is another fossil fuel (BFG, OG, TDF), "NUCLEAR" if it is derived from nuclear (NUC), "HYDRO" if it is derived from hydro power (WAT), "SOLAR" if it is derived from solar power, (SUN), "WIND" if it is derived from wind power (WND), "GEOTHERMAL" if it is derived from geothermal power (GEO), "OTHF" if it is derived from waste heat/unknown/purchased (MWH, OTH, PRG, PUR, WH), and "BIOMASS" if it is derived from biomass sources (AB, BLQ, LFG, MSW, OBG, OBL, OBS, WDL, WDS). 26. Flag indicating if the plant burned or generated any amount of coal (COALFLAG) - A flag to indicate if the plant burned coal or if it has positive heat input and generated electricity from coal. The plant will not be flagged if the plant has negative coal generation and no coal heat input for 2018. 27. Plant Capacity Factor (CAPFAC) - The plant capacity factor, expressed with four decimal places. It is calculated as follows: CAPFAC = (PLNGENAN / (NAMEPCAP * 8760)) Although the value should be between 0 and 1, there are outliers. 28. Plant Nameplate Capacity (NAMEPCAP) - The nameplate capacity of the plant, in MW. Source: EIA-860 29. Nonbaseload Factor (NBFACTOR) - The proportion of generation that is considered nonbaseload generation. A value of 0 means that all of the generation is baseload generation. See Section 3 for more information. Source: Calculated 30. Biogas/Biomass Plant Adjustment Flag (RMBMFLAG) - A biogas (landfill gas, digester gas)/biomass adjustment flag used to indicate where emissions are adjusted for plants using biogas or biomass fuels. A facility's emissions reported in eGRID may be different from that reported in other EPA sources, such as EPA/CAMD's emissions data, due to this adjustment. Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 31. Combined Heat and Power (CHP) Plant Adjustment Flag (CHPFLAG) - A flag to indicate if the plant is a CHP facility. A CHP facility's emissions and heat input reported in eGRID may be different from that reported in other EPA sources, such as EPA/CAMD's emissions data, due to this adjustment. Source: EPA/CAMD; EIA-860 32. CHP Plant Useful Thermal Output (USETHRMO) - The useful thermal output, in MMBtu, estimated for a CHP facility. Source: EIA-923 calculated 33. CHP Plant Power to Heat Ratio (PWRTOHT) - The power to heat ratio for a CHP facility, which is the ratio of the heat value of electricity generated (3413 * kWh output) to the facility's useful thermal output. 34. CHP Plant Electric Allocation Factor (ELCALLOC) - The CHP plant's decimal fraction of the emissions that are attributed to electricity. It is derived as the ratio of the electric heat output to the sum of the electric and steam heat outputs, where the steam output is 75% of the useful thermal output. The electric allocation factor is used to allocate emissions from a CHP facility to both electricity generation and useful thermal output. For non-CHP plants, eGRID uses an electric allocation factor of 1.0. 35. Plant Pumped Storage Flag (PSFLAG) - Indicates if the plant has at least one pumped storage generator. Source: EIA-860 36. Plant Annual Heat Input from Combustion (PLHTIAN) - The total annual heat input from combustion, in MMBtu, for the plant. For CHP plants, the value is adjusted by the electric allocation factor. 37. Plant Ozone Season Heat Input from Combustion (PLHTIOZ) - The five-month ozone season (May through September) heat input from combustion, in MWh, for the plant. For CHP plants, the value is adjusted by the electric allocation factor. 38. Plant Total Annual Heat Input (PLHTIANT) - The total annual heat input from combustion and noncombustion units, in MMBtu, for the plant. For CHP plants, the value is adjusted by the electric allocation factor. 39. Plant Total Ozone Season Heat Input (PLHTIOZT) - The five-month ozone season (May through September) heat input from combustion and noncombustion units, in MWh, for the plant. For CHP plants, the value is adjusted by the electric allocation factor. 40. Plant Annual Net Generation (PLNGENAN) - The total reported annual net generation, in MWh, for the plant, summed from the Unit file. Source: EIA-923 Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 41. Plant Ozone Season Net Generation (PLNGENOZ) - The five-month ozone season (May through September) net generation for the plant. Source: EIA-923 42. Plant Annual NOx Emissions (PLNOXAN) - The total annual NOx emissions, in short tons, for the plant. Biogas components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. This adjusted emissions field is estimated by first making the biogas adjustment (if it exists) and then applying the electric allocation factor (if the plant is a CHP). 43. Plant Ozone Season NOx Emissions (PLNOXOZ) - The five-month ozone season (May through September) NOx emissions, in short tons, for the plant. Biogas components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. This adjusted emissions field is estimated by first making the biogas adjustment (if it exists) and then applying the electric allocation factor (if the plant is a CHP). 44. Plant Annual SO2 Emissions (PLS02AN) - The total annual SO2 emissions, in short tons, for the plant. Landfill gas components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. This adjusted emissions field is estimated by first making the landfill gas adjustment (if it exists) and then applying the electric allocation factor (if the plant is a CHP). 45. Plant Annual CO2 Emissions (PLC02AN) - The total annual CO2 emissions, in short tons, for the plant. All CO2 emissions from biomass fuels are adjusted to zero. For CHP plants, the value is adjusted by the electric allocation factor. This adjusted emissions field is estimated by first making the biomass adjustment (if it exists) and then applying the electric allocation factor (if the plant is a CHP). 46. Plant Annual CH4 Emissions (PLCH4AN) - The total annual CH4 emissions, in pounds, for the plant. Biogas biomass components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. This adjusted emissions field is estimated by first making the biomass adjustment (if it exists) and then applying the electric allocation factor (if the plant is a CHP). 47. Plant Annual N2O Emissions (PLN20AN) - The total annual N2O emissions, in pounds for the plant. Biogas biomass components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. This adjusted emissions field is estimated by first making the biomass adjustment (if it exists) and then applying the electric allocation factor (if the plant is a CHP). 48. Plant Annual CO2 Equivalent Emissions (PLC02EQA) - The annual CO2 equivalent emissions, in short tons, for the plant. This value is a universal standard of measurement. The GWPs from the second IPCC assessment are used for the calculation; the formula is as follows: ". : hnical Support Document for eGR!D2018 | 54 ------- 49, 50, 51, 52, 53, 54, 55, 56, 57, 58, 59, DESCRIPTION OF DATA ELEMENTS PLC02EQA = ((1* PLC02AN) + (21* PLCH4AN / 2000) + (310 * PLN20AN / 2000)). Plant Annual Hg Emissions (PLHGAN) - Not calculated for eGRID2018. Plant Annual NOx Total Output Emission Rate (PLNOXRTA) - This field, in lb/MWh, is calculated as follows: PLNOXRTA = 2000 * (PLNOXAN / PLNGENAN). Plant Ozone Season NOx Total Output Emission Rate (PLNOXRTO) - This field, in lb/MWh, is calculated as follows: PLNOXRTO = 2000 * (PLNOXOZ / PLNGENOZ). Plant Annual SO2 Total Output Emission Rate (PLS02RTA) - This field, in lb/MWh, is calculated as follows: PLS02RTA = 2000 * (PLS02AN / PLNGENAN). Plant Annual CO2 Total Output Emission Rate (PLC02RTA) - This field, in lb/MWh, is calculated as follows: PLC02RTA = 2000 * (PLC02AN / PLNGENAN). Plant Annual CH4 Total Output Emission Rate (PLCH4RTA) - This field, in lb/MWh, is calculated as follows: PLCH4RTA = PLCH4AN / PLNGENAN. Plant Annual N2O Total Output Emission Rate (PLN20RTA) - This field, in lb/MWh, is calculated as follows: PLN20RTA = PLN20AN / PLNGENAN Plant Annual CO2 Equivalent Total Output Emission Rate (PLC2ERTA) - This field, in lb/MWh, is calculated as follows: PLC2ERTA = 2000 * (PLC02EQA / PLNGENAN). Plant Annual Hg Total Output Emission Rate (PLHGRTA) - Not calculated for eGRID2018. Plant Annual NOx Input Emission Rate (PLNOXRA) - This field, in lb/MMBtu, is calculated as follows: PLNOXRA = 2000 * (PLNOXAN / PLHTIAN). Plant Ozone Season NOx Input Emission Rate (PLNOXRO) - This field, in lb/MMBtu, is calculated as follows: PLNOXRO = 2000 * (PLNOXOZ / PLHTIOZ). Technical Support Document for eGR!D2018 ------- 60, 61, 62, 63, 64, 65, 66, 67, 68, 69, 70, 71, DESCRIPTION OF DATA ELEMENTS Plant Annual SO2 Input Emission Rate (PLS02RA) - This field, in lb/MMBtu, is calculated as follows: PLS02RA = 2000 * (PLS02AN / PLHTIAN). Plant Annual CO2 Input Emission Rate (PLC02RA) - This field, in lb/MMBtu, is calculated as follows: PLC02RA = 2000 * (PLC02AN / PLHTIAN). Plant Annual CH4 Input Emission Rate (PLCH4RA) - This field, in lb/MMBtu, is calculated as follows: PLC02RA = 2000 * (PLCH4AN / PLHTIAN). Plant Annual N2O Input Emission Rate (PLN20RA) - This field, in lb/MMBtu, is calculated as follows: PLC02RA = 2000 * (PLN20AN / PLHTIAN). Plant Annual CO2 Equivalent Input Emission Rate (PLC2ERA) - This field, in lb/MMBtu, is calculated as follows: PLC02RA = 2000 * (PLC02EQA / PLHTIAN). Plant Annual Hg Input Emission Rate (PLHGRA) - Not calculated for eGRID2018. Plant Annual NOx Combustion Output Emission Rate (PLNOXCRT) - This field, in lb/MWh, is calculated as follows: PLNOXCRT = 2000 * (PLNOXAN / PLGENACY). Plant Ozone Season NOx Combustion Output Emission Rate (PLNOXCRO) - This field, in lb/MWh, is calculated as follows: PLNOXCRO = 2000 * (PLNOXOZ / ((PLGENACY * PLNGENOZ) / PLNGENAN)). Plant Annual SO2 Combustion Output Emission Rate (PLS02CRT) - This field, in lb/MWh, is calculated as follows: PLS02CRT = 2000 * (PLS02AN / PLGENACY). Plant Annual CO2 Combustion Output Emission Rate (PLC02CRT) - This field, in lb/MWh, is calculated as follows: PLC02CRT = 2000 * (PLC02AN / PLGENACY). Plant Annual CH4 Combustion Output Emission Rate (PLCH4CRT) - This field, in lb/MWh, is calculated as follows: PLCH4CRT = PLCH4AN / PLGENACY. Plant Annual N2O Combustion Output Emission Rate (PLN20CRT) - This field, in lb/MWh, is calculated as follows: Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS PLN20CRT = PLN20AN / PLGENACY. 72. Plant Annual Hg Combustion Output Emission Rate (PLHGCRT) - Not calculated for eGRID2018. 73. Plant Unadjusted Annual NOx Emissions (UNNOX) - The total plant-level unadjusted annual NOx emissions, in short tons. 74. Plant Unadjusted Ozone Season NOx Emissions (UNNOXOZ) - The unadjusted five-month ozone season (May through September) NOx emissions, in short tons, for the plant. 75. Plant Unadjusted Annual SO2 Emissions (UNS02) - The total plant-level unadjusted annual SO2 emissions, in short tons. 76. Plant Unadjusted Annual CO2 Emissions (UNC02) - The total plant-level unadjusted annual CO2 emissions, in short tons. 77. Plant Unadjusted Annual CH4 Emissions (UNCH4) - The total plant-level unadjusted annual CH4 emissions, in pounds. 78. Plant Unadjusted Annual N2O Emissions (UNN20) - The total plant-level unadjusted annual N2O emissions, in pounds. 79. Plant Unadjusted Annual Hg Emissions (UNHG) - Not calculated for eGRID2018. 80. Plant Unadjusted Annual Heat Input from Combustion (UNHTI) - The total plant-level unadjusted annual heat input from combustion, in MMBtu. Sources: EPA/CAMD, EIA-923 81. Plant Unadjusted Ozone Season Heat Input from Combustion (UNHTIOZ) - The five-month ozone season (May through September) heat input from combustion, in MMBtu for the plant. Sources: EPA/CAMD, EIA-923 82. Plant Unadjusted Total Annual Heat Input (UNHTIT) - The total plant-level unadjusted annual heat input from combustion and noncombustion units, in MMBtu. Sources: EPA/CAMD, EIA-923 83. Plant Unadjusted Total Ozone Season Heat Input (UNHTIOZT) - The five-month ozone season (May through September) heat input from combustion and noncombustion units, in MMBtu for the plant. Sources: EPA/CAMD, EIA-923 84. Plant Unadjusted Annual NOx Emissions Source (UNNOXSRC ) - The source of plant-level unadjusted annual NOx emissions. Technical Support Document for eGRID2018 | per 57 ------- DESCRIPTION OF DATA ELEMENTS 85. Plant Unadjusted Ozone Season NOx Emissions Source (UNNOZSRC) - The source of plant-level unadjusted ozone NOx emissions. 86. Plant Unadjusted Annual SO2 Emissions Source (UNS02SRC) - The source of plant-level unadjusted annual SO2 emissions. 87. Plant Unadjusted Annual CO2 Emissions Source (UNC02SRC) - The source of plant-level unadjusted annual CO2 emissions. 88. Plant Unadjusted Annual CH4 Emissions Source (UNCH4SRC) - The source of plant-level unadjusted annual CH4 emissions. 89. Plant Unadjusted Annual N2O Emissions Source (UNN20SRC) - The source of plant-level unadjusted annual N2O emissions. 90. Plant Unadjusted Annual Hg Emissions Source (UNHGSRC) - Not calculated for eGRID2018. 91. Plant Unadjusted Annual Heat Input Source (UNHTISRC) - The source of plant-level unadjusted annual heat input. 92. Plant Unadjusted Ozone Season Heat Input Source (UNHOZSRC) - The source of plant-level unadjusted ozone season heat input. 93. Plant Annual NOx Biomass Emissions (BIONOX) - The annual plant-level NOx biomass emissions, in tons. This is the value the total emissions are adjusted by for the biomass emissions adjustments. See Section 3.1.2.1 for more information. Source: EIA-923 94. Plant Ozone Season NOx Biomass Emissions (BIONOXOZ) - The five-month ozone season (May through September) plant-level NOx biomass emissions, in tons. This is the value the total emissions are adjusted by for the biomass emissions adjustments. See Section 3.1.2.1 for more information. Source: EIA-923 95. Plant Annual SO2 Biomass Emissions (BI0S02) - The annual plant-level SO2 biomass emissions, in tons. This is the value the total emissions are adjusted by for the biomass emissions adjustments. See Section 3.1.2.1 for more information. Source: EIA-923 96. Plant Annual CO2 Biomass Emissions (BI0C02) - The annual plant-level CO2 biomass emissions, in tons. This is the value the total emissions are adjusted by for the biomass emissions adjustments. See Section 3.1.2.1 for more information. Source: EIA-923 Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 97. Plant Annual CH4 Biomass Emissions (BIOCH4) - The annual plant-level CH4 biomass emissions, in pounds. This is the value the total emissions are adjusted by for the biomass emissions adjustments. See Section 3.1.2.1 for more information. Source: EIA-923 98. Plant Annual N2O Biomass Emissions (BI0N20) - The annual plant-level N2O biomass emissions, in pounds. This is the value the total emissions are adjusted by for the biomass emissions adjustments. See Section 3.1.2.1 for more information. Source: EIA-923 99. Plant Combustion Annual Heat Input CHP Adjustment Value (CHPCHTI) - The annual plant-level heat input adjustment value for CHP plants, in MMBtu. See Section 3.1.2.2 for more information. 100. Plant Combustion Ozone Season Heat Input CHP Adjustment Value (CHPCHTIOZ) - The five-month ozone season (May through September) plant-level heat input adjustment value for CHP plants, in MMBtu. See Section 3.1.2.2 for more information. 101. Plant Annual NOx Emissions CHP Adjustment Value (CHPNOX) - The annual plant-level NOx emissions adjustment value for CHP plants, in tons. See Section 3.1.2.2 for more information. 102. Plant Ozone season NOx Emissions CHP Adjustment Value (CHPNOXOZ) - The five-month ozone season (May through September) plant-level NOx emissions adjustment value for CHP plants, in tons. See Section 3.1.2.2 for more information. 103. Plant Annual SO2 Emissions CHP Adjustment Value (CHPS02) - The annual plant-level SO2 emissions adjustment value for CHP plants, in tons. See Section 3.1.2.2 for more information. 104. Plant Annual CO2 Emissions CHP Adjustment Value (CHPC02) - The annual plant-level CO2 emissions adjustment value for CHP plants, in tons. See Section 3.1.2.2 for more information. 105. Plant Annual CH4 Emissions CHP Adjustment Value (CHPCH4) - The annual plant-level CH4 emissions adjustment value for CHP plants, in pounds. See Section 3.1.2.2 for more information. 106. Plant Annual N2O Emissions CHP Adjustment Value (CHPN20) - The annual plant-level N2O emissions adjustment value for CHP plants, in pounds. See Section 3.1.2.2 for more information. 107. Plant Nominal Heat Rate (PLHTRT) - The plant nominal heat rate, in Btu/kWh, for partial combustion plants. It is calculated as follows: Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS PLHTRT = 1000 * (PLHTIAN / PLGENACY) For CHP plants, the value is, in effect, adjusted by the electric allocation factor, since the heat input has been adjusted. 108. Plant Annual Coal Net Generation (PLGENACL) - The plant annual net generation, in MWh, for coal. Fuel codes that are included in coal are BIT, COG, SUB, LIG, WC, and SC. 109. Plant Annual Oil Net Generation (PLGENAOL) - The plant annual net generation, in MWh, for oil. Fuel codes included in oil are DFO, JF, KER, OO, PC, RFO, RG, and WO. 110. Plant Annual Gas Net Generation (PLGENAGS) - The plant annual net generation, in MWh, for natural gas. Fuel codes included in gas are NG and PG. 111. Plant Annual Nuclear Net Generation (PLGENANC) - The plant annual net generation, in MWh, for nuclear. The fuel code is NUC. 112. Plant Annual Hydro Net Generation (PLGENAHY) - The plant annual net generation, in MWh, for hydro. The fuel code is WAT. 113. Plant Annual Biomass Net Generation (PLGENABM) - The annual net generation, in MWh, for biomass. Biomass is a fuel derived from organic matter such as wood and paper products, agricultural waste, or methane (e.g., from landfills). The renewable portion of solid waste, fuel code MSB, is included as biomass, as are AB, BLQ, DG, LFG, ME, OBL, OBS, PP, SLW, WDL, and WDS. 114. Plant Annual Wind Net Generation (PLGENAWI) - The plant annual net generation, in MWh, for wind. The fuel code is WND. 115. Plant Annual Solar Net Generation (PLGENASO) - The plant annual net generation, in MWh, for solar. The fuel code is SUN. 116. Plant Annual Geothermal Net Generation (PLGENAGT) - The plant annual net generation, in MWh, for geothermal. The fuel code is GEO. 117. Plant Annual Other Fossil Net Generation (PLGENAOF) - The plant annual net generation, in MWh, for other fossil fuel that cannot be categorized as coal, oil, or gas. Other fossil fuel codes include BFG, COG, HY, LB, MH, MSF, OG, PRG, and TDF. 118. Plant Annual Other Unknown/ Purchased Fuel Net Generation (PLGENAOP) - The plant annual net generation, in MWh, for other unknown/purchased. Fuel codes include OTH, PUR, orWH. Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 119. Plant Annual Total Nonrenewables Net Generation (PLGENATN) - The annual total nonrenewables net generation, in MWh, for the plant. Nonrenewables are exhaustible energy resources such as coal, oil, gas, other fossil, nuclear power, and other unknown/purchased fuel. This field is the sum of PLGENACL, PLGENAOL, PLGENAGS, PLGENAOF, PLGENANC, and PLGENAOP. 120. Plant Annual Total Renewables Net Generation (PLGENATR) - The annual total renewables net generation, in MWh, for the plant. Renewables are inexhaustible energy resources such as biomass, wind, solar, geothermal, and hydro. This field is the sum of PLGENABM, PLGENAWI, PLGENASO, PLGENAGT, and PLGENAHY. 121. Plant Annual Total Nonhydro Renewables Net Generation (PLGENATH) - The annual total nonhydro renewables net generation, in MWh, for the plant. This field is the sum of PLGENABM, PLGENAWI, PLGENASO, and PLGENAGT. 122. Plant Annual Total Combustion Net Generation (PLGENACY) - The annual total combustion net generation, in MWh, for the plant. This field is the sum of PLGENACL, PLGENAOL, PLGENAGS, PLGENAOF, PLGENABM, and PLGENAOP. 123. Plant Annual Total Noncombustion Net Generation (PLGENACN) - The annual total noncombustion net generation, in MWh, for the plant. This field is the sum of PLGENANC, PLGENAHY, PLGENAWI, PLGENASO, and PLGENAGT. 124. Plant Coal Generation Percent (PLCLPR) - The coal resource mix expressed as a percent of plant annual net generation. PLCLPR = 100 * (PLGENACL / PLNGENAN). 125. Plant Oil Generation Percent (PLOLPR) - The oil resource mix expressed as a percent of plant annual net generation. PLOLPR = 100 * (PLGENAOL / PLNGENAN). 126. Plant Gas Generation Percent (PLGSPR) - The gas resource mix expressed as a percent of plant annual net generation. PLGSPR = 100 * (PLGENAGS / PLNGENAN). 127. Plant Nuclear Generation Percent (PLNCPR) - The nuclear resource mix expressed as a percent of plant annual net generation. PLNCPR = 100 * (PLGENANC / PLNGENAN). 128. Plant Hydro Generation Percent (PLHYPR) - The hydro resource mix expressed as a percent of plant annual net generation. PLHYPR = 100 * (PLGENAHY / PLNGENAN). Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 129. Plant Biomass Generation Percent (PLBMPR) - The biomass resource mix expressed as a percent of plant annual net generation. PLBMPR = 100 * (PLGENABM / PLNGENAN). 130. Plant Wind Generation Percent (PLWIPR) - The wind resource mix expressed as a percent of plant annual net generation. PLWIPR = 100 * (PLGENAWI / PLNGENAN). 131. Plant Solar Generation Percent (PLSOPR) - The solar resource mix expressed as a percent of plant annual net generation. PLSOPR = 100 * (PLGENASO / PLNGENAN). 132. Plant Geothermal Generation Percent (PLGTPR) - The geothermal resource mix expressed as a percent of plant annual net generation. PLGTPR = 100 * (PLGENAGT / PLNGENAN). 133. Plant Other Fossil Generation Percent (PLOFPR) - The other fossil resource mix expressed as a percent of plant annual net generation. PLOFPR = 100 * (PLGENAOF / PLNGENAN). 134. Plant Other Unknown/Purchased Fuel Generation Percent (PLOPPR) - The other unknown/purchased fuel/waste heat resource mix expressed as a percent of plant annual net generation. PLOPPR = 100 * (PLGENAOP / PLNGENAN). 135. Plant Total Nonrenewables Generation Percent (PLTNPR) - The total nonrenewables resource mix expressed as a percent of plant annual net generation. PLTNPR = 100 * (PLGENATN / PLNGENAN). 136. Plant Total Renewables Generation Percent (PLTRPR) - The total renewables resource mix expressed as a percent of plant annual net generation. PLTRPR = 100 * (PLGENATR/PLNGENAN). 137. Plant Total Nonhydro Renewables Generation Percent (PLTHPR) - The total nonhydro renewables resource mix expressed as a percent of plant annual net generation. PLTHPR = 100 * (PLGENATH / PLNGENAN). 138. Plant Total Combustion Generation Percent (PLCYPR) - The total combustion resource mix expressed as a percent of plant annual net generation. PLCYPR = 100 * (PLGENACY / PLNGENAN). Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 139. Plant Total Noncombustion Generation Percent (PLCNPR) - The total noncombustion resource mix expressed as a percent of plant annual net generation. PLCNPR = 100 * (PLGENACN / PLNGENAN). 5.4 The ST (State) File There are 163 variables in the fourth file, ST, which contains state level data. All size, heat input, generation, and emission values are derived by aggregating from the plant level based on the state in which the plant is located. Aggregated variable names generally begin with "ST." Variables that are either identical to those in the plant file or different from those in the plant file by the first two letters of their names (e.g., STHTIAN instead of PLHTIAN) are not re-defined here. 1. Data Year (YEAR) - 2. State Abbreviation (PSTATABB) - 3. FIPS State Code (FIPSST) - 4. State Nameplate Capacity (NAMEPCAP) - 5. State Annual Heat Input from Combustion (STHTIAN) - 6. State Ozone Season Heat Input from Combustion (STHTIOZ) - 7. State Total Annual Heat Input (STHTIANT) - 8. State Total Ozone Season Heat Input (STHTIOZT) - 9. State Annual Net Generation (STNGENAN) - 10. State Ozone Season Net Generation (STNGENOZ) - 11. State Annual NOx Emissions (STNOXAN) - 12. State Ozone Season NOx Emissions (STNOXOZ) - 13. State Annual SO2 Emissions (STS02AN) - 14. State Annual CO2 Emissions (STC02AN) - 15. State Annual CH4 Emissions (STCH4AN) - 16. State Annual N2O Emissions (STN20AN) - 17. State Annual CO2 Equivalent Emissions (STC02EQA) - This field, in short tons, is the sum of each state's plants' PLC02EQA "cc 1 lical Support Document c<,>K D2018 | pg, 63 ------- 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29, DESCRIPTION OF DATA ELEMENTS State Annual Hg Emissions (STHGAN) - State Annual NOx Total Output Emission Rate (STNOXRTA) - This field, in lb/MWh, is calculated as follows: STNOXRTA = 2000 * (STNOXAN / STNGENAN). State Ozone Season NOx Total Output Emission Rate (STNOXRTO) - This field, in lb/MWh, is calculated as follows: STNOXRTO = 2000 * (STNOXOZ / STNGENOZ). State Annual SO2 Total Output Emission Rate (STS02RTA) - This field, in lb/MWh, is calculated as follows: STS02RTA = 2000 * (STS02AN / STNGENAN). State Annual CO2 Total Output Emission Rate (STC02RTA) - This field, in lb/MWh, is calculated as follows: STC02RTA = 2000 * (STC02AN / STNGENAN). State Annual CH4 Total Output Emission Rate (STCH4RTA) - This field, in lb/MWh, is calculated as follows: STHCH4RTA = STCH4AN / STNGENAN. State Annual N2O Total Output Emission Rate (STN20RTA) - This field, in lb/MWh, is calculated as follows: STN20RTA = STN20AN / STNGENAN. State Annual CO2 Equivalent Total Output Emission Rate (STC2ERTA) - This field, in lb/MWh, is calculated as follows: STC2ERTA = 2000 * (STC02EQA / STNGENAN). State Annual Hg Total Output Emission Rate (STHGRTA) - Not calculated for eGRID2018. State Annual NOx Input Emission Rate (STNOXRA) - This field, in lb/MMBtu, is calculated as follows: STNOXRA = 2000 * (STNOXAN / STHTIAN). State Ozone Season NOx Input Emission Rate (STNOXRO) - This field, in lb/MMBtu, is calculated as follows: STNOXRO = 2000 * (STNOXOZ / STHTIOZ). State Annual SO2 Input Emission Rate (STS02RA) - This field, in lb/MMBtu, is calculated as follows: STS02RA = 2000 * (STS02AN / STHTIAN). Technical Support Document for eGR!D2018 ------- 30, 31, 32, 33, 34, 35, 36, 37, 38, 39, 40, 41, 42, DESCRIPTION OF DATA ELEMENTS State Annual CO2 Input Emission Rate (STC02RA) - This field, in lb/MMBtu, is calculated as follows: STC02RA = 2000 * (STC02AN / STHTIAN). State Annual CH4 Input Emission Rate (STCH4RA) - This field, in lb/MMBtu, is calculated as follows: STCH4RA = 2000 * (STCH4AN / STHTIAN). State Annual N2O Input Emission Rate (STN20RA) - This field, in lb/MMBtu, is calculated as follows: STN20RA = 2000 * (STN20AN / STHTIAN). State Annual CO2 Equivalent Input Emission Rate (STC2ERA) - This field, in lb/MMBtu, is calculated as follows: STC2ERA = 2000 * (STC02EQA/ STHTIAN). State Annual Hg Input Emission Rate (STHGRA) - Not calculated for eGRID2018. State Annual NOx Combustion Output Emission Rate (STNOXCRT) - This field, in lb/MMBtu, is calculated as follows: STNOXCRT =2000 * (STNOXAN / STGENACY). State Ozone Season NOx Combustion Output Emission Rate (STNOXCRO) - This field, in lb/MMBtu, is calculated as follows: STNOXCRO = 2000 * (STNOXOZ / ((STGENACY* STNGENOZ)/STNGENAN)). State Annual SO2 Combustion Output Emission Rate (STS02CRT) - This field, in lb/MMBtu, is calculated as follows: STS02CRT = 2000 * (STS02AN / STGENACY). State Annual CO2 Combustion Output Emission Rate (STC02CRT) - This field, in lb/MMBtu, is calculated as follows: STC02CRT = 2000 * (STC02AN / STGENACY). State Annual CH4 Combustion Output Emission Rate (STCH4CRT) - This field, in lb/MMBtu, is calculated as follows: STCH4CRT = STCH4AN / STGENACY. State Annual N2O Combustion Output Emission Rate (STN20CRT) - This field, in lb/MMBtu, is calculated as follows: STN20CRT = STN20AN / STGENACY. State Annual Hg Combustion Output Emission Rate (STHGCRT) - Not calculated for eGRID2018. State Annual NOx Coal Output Emission Rate (STCNOXRT) - Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS The sum of the annual NOx emissions from all plants in the state that have coal as the primary fuel (PLPRMFL) divided by the sum of the annual combustion net generation from the same set of plants, and multiplied by a unit conversion factor, in lb/MWh. 43. State Annual NOx Oil Output Emission Rate (STONOXRT) - The sum of the annual NOx emissions from all plants in the state that have oil as the primary fuel (PLPRMFL) divided by the sum of the annual combustion net generation from the same set of plants, and multiplied by a unit conversion factor, in lb/MWh. 44. State Annual NOx Gas Output Emission Rate (STGNOXRT) - The sum of the annual NOx emissions from all plants in the state that have natural gas as the primary fuel (PLPRMFL) divided by the sum of the annual combustion net generation from the same set of plants, and multiplied by a unit conversion factor, in lb/MWh. 45. State Annual NOx Fossil Fuel Output Emission Rate (STFSNXRT) - The sum of the annual NOx emissions from all plants in the state that have any fossil fuel (coal, oil, gas, or other fossil) as the primary fuel (PLPRMFL) divided by the sum of the annual combustion net generation from the same set of plants, and multiplied by a unit conversion factor, in lb/MWh. 46. - State Ozone Season NOx Coal, Oil, Gas, and Fossil Fuel Output Emission 49. Rates - The descriptions of the ozone season NOx fields, in lb/MWh, contain the same information as annual NOx fields #42 through #45, respectively. The state ozone season combustion net generation, used in the denominator of the equations, is calculated as the ratio of the state annual to ozone season net generation for that fuel times the state annual combustion net generation. 50. - State Annual SO2 Coal, Oil, Gas, and Fossil Fuel Output Emission 53. Rates - The descriptions of the annual SO2 fields, in lb/MWh, contain the same information as annual NOx fields #42 through #45, respectively. 54. - State Annual CO2 Coal, Oil, Gas, and Fossil Fuel Output Emission 57. Rates - The descriptions of annual CO2 fields, in lb/MWh, contain the same information as annual NOx fields #42 through #45, respectively. 58. - State Annual CH4 Coal, Oil, Gas, and Fossil Fuel Output Emission 61. Rates - The descriptions of annual CH4 fields, in lb/MWh, contain the same information as annual NOx fields #42 through #45, respectively. Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 62. - State Annual N2O Coal, Oil, Gas, and Fossil Fuel Output Emission 65. Rates - The descriptions of annual N2O fields, in lb/MWh, contain the same information as annual NOx fields #42 through #45, respectively. 66. - State Annual CO2 Equivalent Coal, Oil, Gas, and Fossil Fuel Output Emission 69. Rates - The descriptions of annual CO2 equivalent fields, in lb/MWh, contain the same information as annual NOx fields #42 through #45, respectively. 70. - State Annual Hg Coal, Oil, Gas, and Other Fossil Fuel Output Emission 71. Rates - Not calculated. 72. - State Annual NOx, Ozone Season NOx, Annual SO2, Annual CO2, Annual CH4, 101. Annual N2O, Annual CO2 Equivalent Coal, Oil, Gas, and Fossil Fuel Input Emission Rates; and Annual Hg Coal and Fossil Fuel Input Emission Rates - The descriptions of these fields, primary fuel-specific input emission rates, contain the same information that fields #42 through #45 do for primary fuel-specific output emission rates - except that the calculations include heat input, rather than net generation. These values are calculated in the same manner as the input emission rates, using heat input in place of generation. 102. - State Annual NOx, Ozone Season NOx, Annual SO2, Annual CO2, Annual CH4, 109. Annual N2O, Annual CO2 Equivalent, and Annual Hg Nonbaseload Output Emission Rate - These fields, in lb/MWh, are calculated as the sum of the annual nonbaseload NOx, ozone season nonbaseload NOx, annual nonbaseload SO2, annual nonbaseload CO2, annual nonbaseload CH4, annual nonbaseload N2O emissions, and annual nonbaseload CO2 equivalent divided by the sum of annual nonbaseload net generation in the state and then multiplied by a unit conversion factor. These fields are intended to provide a more refined estimate of avoided emissions than the fossil-fuel average output emission rate. The nonbaseload emissions and generation include only emissions and generation from combustion sources and exclude emissions and generation from plants that have high capacity factors. The remaining emissions and generation are weighted by a factor which is a function of capacity factor. For more information, see Section 3.1.3 on emission rate estimates. 110. State Annual Coal Net Generation (STGENACL) - 111. State Annual Oil Net Generation (STGENAOL) - 112. State Annual Gas Net Generation (STGENAGS) - 113. State Annual Nuclear Net Generation (STGENANC) - 114. State Annual Hydro Net Generation (STGENAHY) - "cc 1 lical Support Document c<,>K D2018 | pg, 67 ------- DESCRIPTION OF DATA ELEMENTS 115. State Annual Biomass Net Generation (STGENABM) - 116. State Annual Wind Net Generation (STGENAWI) - 117. State Annual Solar Net Generation (STGENASO) - 118. State Annual Geothermal Net Generation (STGENAGT) - 119. State Annual Other Fossil Net Generation (STGENAOF) - 120. State Annual Other Unknown/Purchased Fuel Net Generation (STGENAOP) - 121. State Annual Total Nonrenewables Net Generation (STGENATN) - 122. State Annual Total Renewables Net Generation (STGENATR) - 123. State Annual Total Nonhydro Renewables Net Generation (STGENATH) - 124. State Annual Total Combustion Net Generation (STGENACY) - 125. State Annual Total Noncombustion Net Generation (STGENACN) - 126. State Coal Generation Percent (STCLPR) - 127. State Oil Generation Percent (STOLPR) - 128. State Gas Generation Percent (STGSPR) - 129. State Nuclear Generation Percent (STNCPR) - 130. State Hydro Generation Percent (STHYPR) - 131. State Biomass Generation Percent (STBMPR) - 132. State Wind Generation Percent (STWIPR) - 133. State Solar Generation Percent (STSOPR) - 134. State Geothermal Generation Percent (STGTPR) - 135. State Other Fossil Generation Percent (STOFPR) - 136. State Other Unknown/Purchased Fuel Generation Percent (STOPPR) - 137. State Total Nonrenewables Generation Percent (STTNPR) - 138. State Total Renewables Generation Percent (STTRPR) - Technical Support Document for eGRID2018 | pg. 68 ------- DESCRIPTION OF DATA ELEMENTS 139. State Total Nonhydro Renewables Generation Percent (STTHPR) - 140. State Total Combustion Generation Percent (STCYPR) - 141. State Total Noncombustion Generation Percent (STCNPR) - 142. State Annual Nonbaseload Coal Net Generation (STNBGNCL) - 143. State Annual Nonbaseload Oil Net Generation (STNBGNOL) - 144. State Annual Nonbaseload Gas Net Generation (STNBGNGS) - 145. State Annual Nonbaseload Nuclear Net Generation (STNBGNNC) - 146. State Annual Nonbaseload Hydro Net Generation (STNBGNHY) - 147. State Annual Nonbaseload Biomass Net Generation (STNBGNBM) - 148. State Annual Nonbaseload Wind Net Generation (STNBGNWI) - 149. State Annual Nonbaseload Solar Net Generation (STNBGNSO) - 150. State Annual Nonbaseload Geothermal Net Generation (STNBGNGT) - 151. State Annual Nonbaseload Other Fossil Net Generation (STNBGNOF) - 152. State Annual Nonbaseload Other Unknown/Purchased Fuel Net Generation (STNBGNOP) - 153. State Nonbaseload Coal Generation Percent (STNBCLPR) - 154. State Nonbaseload Oil Generation Percent (STNBOLPR) - 155. State Nonbaseload Gas Generation Percent (STNBGSPR) - 156. State Nonbaseload Nuclear Generation Percent (STNBNCPR) - 157. State Nonbaseload Hydro Generation Percent (STNBHYPR) - 158. State Nonbaseload Biomass Generation Percent (STNBBMPR) - 159. State Nonbaseload Wind Generation Percent (STNBWIPR) - 160. State Nonbaseload Solar Generation Percent (STNBSOPR) - 161. State Nonbaseload Geothermal Generation Percent (STNBGTPR) - 162. State Nonbaseload Other Fossil Generation Percent (STNBOFPR) - Technical Support Document for eGRID2018 | pg. 69 ------- DESCRIPTION OF DATA ELEMENTS 163. State Nonbaseload Other Unknown/Purchased Fuel Generation Percent (STNBOPPR) - 5.5 The BA (Balancing Authority) File There are 163 variables in the fifth file, BA, which contains location (operator)-based balancing authority data. All generation and emission values are derived by aggregating from the plant level based on the associated balancing authority. All variables have been described in previous file variable descriptions. Aggregated variable names generally begin with "BA." 5.6 The SRL (eGRID Subregion) File There are 163 variables in the sixth file, SRL, which contains location (operator)-based eGRID subregions. All generation and emission values are derived by aggregating from the plant level based on the associated eGRID subregion. All other variables in the eGRID Subregion file have been described in previous file variable descriptions. Aggregated variable names generally begin with "SR." 5.7 The NRL (NERC Region) File There are 163 variables in the seventh file, NRL, which contains location (operator)-based NERC region data. All generation and emission values are derived by aggregating from the plant level based on the associated NERC region. The only variable in this file that has not been described in a previous file variable description is NERCNAME, the NERC region name associated with the NERC region acronym (see Section 3.4.1). Aggregated variable names generally begin with "NR." 5.8 The US (U.S.) File There are 161 variables in the eighth file, US, which contains data for the entire United States. All generation and emission values are derived by aggregating from the plant level. All variables have been described in previous file variable descriptions. Aggregated variable names generally begin with "US." 5.9 The Regional Grid Gross Loss File There are five variables in the GGL file, reported in eGRID at the regional level based on the aforementioned aggregated state level data: 1. Data Year (YEAR) - The current eGRID data year. 2. REGION One of the three interconnect power grids in the U.S.: Eastern, Western, or ERCOT, plus the states of Alaska and Hawaii, and the entire U.S. Technical Support Document for eGR!D2018 ------- DESCRIPTION OF DATA ELEMENTS 3. Estimated Losses (ESTLOSS) The total amount of electricity, in MWh, in the region that is generated but is not sold for resale or wholesale, furnished without charge, or used by the generator or utility; i.e., electricity that is lost in transmission and distribution. Source: EIA State Electricity Profiles, Supply and disposition of electricity, 1990- 2016. 4. Total Disposition without Exports (TOTDISP) The total amount of electricity, in MWh, in the region that is sold directly to customers, sold for resale, furnished without charge, consumed by the respondent without charge, and lost; i.e., all electricity generated, without exports. Source: EIA State Electricity Profiles, Supply and disposition of electricity, 1990- 2018. 5. Direct Use (DIRCTUSE) The total amount of electricity, in MWh, used by plants and/or utilities in the region that is not sold for wholesale or resale; direct use electricity is not transmitted through the grid and therefore does not have the potential to be lost. Source: EIA State Electricity Profiles, Supply and disposition of electricity, 1990- 2016. 6. Grid Gross Loss (GGRSLOSS) The estimated grid gross loss as a percent. The formula used is [ESTLOSS/(TOTDISP - DIRCTUSE)] *100 The grid gross loss values can be used when applying eGRID GHG factors (eGRID subregion annual GHG total output emission rates) to consumption. Specifically, to account for indirect emissions associated with consumption of electricity (both from generation and from transmission and distribution line losses) divide the product of the electricity consumption and the generation based eGRID total output emission rates by (one minus the grid gross loss as a decimal). See the equation below: GHG emis cons= GHG emis rate * Consumption / (l-ggl%/100)/2000 Where; GHG emis cons = a specified GHG emission associated with a certain amount of electricity consumption (generation and line losses) in short tons, GHG emis rate = eGRID subregion annual total output emission rate in lb/MWh for a specified GHG, Consumption = the given electricity consumption in MWh (kWh/1000), and ggl% = the estimated regional grid gross loss as a percent. If reporting the indirect emissions for the electricity generation (scope 2 emissions) separately from the indirect emissions as a result of transmission and distribution line losses (scope 3 emissions), then the scope 2 emissions are simply the consumption in MWh multiplied by the eGRID subregion annual total output emission rate in lb/MWh, and the scope 3 emissions are calculated in the following equation: Technical Supp i : ument for eGRID2018 | pg. 71 ------- DESCRIPTION OF DATA ELEMENTS GHG emis 11 Where; GHG emis 11 GHG emis rate Consumption ggl% GHG emis rate * Consumption * (ggl%/100) / (l-ggl%/100)/2000 a specified GHG emission associated with the line losses of a certain amount of electricity consumption in short tons, eGRID subregion annual total output emission rate in lb/MWh for a specified GHG, the given electricity consumption in MWh (= kWh/1000), and the estimated regional grid gross loss as a percent. Technical Support Document for eGR!D2018 ------- REFERENCES 6. References CARB, 2007: California Air Resources Board "Regulation for the Mandatory Reporting of Greenhouse Gas Emissions (AB 32 requirements)" Table 5 in Appendix A, December 2007. http://www.arb.ca.gov/regact/2007/ghg2007/frofinoal.pdf Carbon Visuals, 2016: "Visualizing the carbon footprint of all US power stations," http://www.carbonvisuals.com/proiects/2015/6/23/visualising-the-carbon-footprint-of-all-us- power-stations ? rq=eGRID Cooley et al., 2019: "EPA's Emissions & Generation Resource Integrated Database (eGRID): Improvements and Applications" presented at the 17th Annual Community Modeling and Analysis System Conference, https://www.cmascenter.org/conference/2018/agenda.cfm Diem, Salhotra and Quiroz, 2013: Diem, A., M. Salhotra, and C. Quiroz, "Using EPA's eGRID to Estimate GHG Emissions Reductions from Energy Efficiency" International Energy Program Evaluation Conference, Chicago IL, August 2013. Diem and Quiroz, 2013: Diem, A. and C. Quiroz, "Using eGRID Data for Carbon Footprinting Electricity Purchases," Energy, Utility, and Environment Conference, Phoenix, Arizona, January 2013. Diem and Quiroz, 2012: Diem, A., and C. Quiroz, "How to use eGRID for Carbon Footprinting Electricity Purchases in Greenhouse Gas Emission Inventories" presented at the U.S. Environmental Protection Agency 2012 International Emission Inventory Conference, Tampa, Florida, August 2012. http: //www. epa.gov/ttn/chief/ conference/ei20/se ssion3/adiem .pdf Dorn et al., 2019a: "EPA's Emissions & Generation Resource Integrated Database (eGRID): Updates and Improvements," presented at the 18th Annual Community Modeling and Analysis System Conference, https://www.cmascenter.org/conference/2019/agenda.cfm Dorn et al.. 2019b: "Adding Particulate Matter to EPA's eGRID Database." presented at the 2019 International Emissions Inventory Conference, https://www.epa.gov/sites/production/files/2019- 08/documents/825am dorn.pdf Dorn et al., 2015: "EPA's Emissions & Generation Resource Integrated Database (eGRID): Improvements and Applications," presented at the Community Modeling and Analysis System Conference, https://www.cmascenter.org/conference/2015/agenda.cfm DOE, 2018: U.S. Department of Energy, Energy Efficiency and Renewable Energy, Combined Heat and Power Installation Database, https://doe.icfwebservices.com/chpdb/ DVRPC, 2010: Delaware Valley Regional Planning Commission, Regional Greenhouse Gas Emissions Inventory, revised December 2010. http://www.dvrpc.org/reports/09038A.pdf EIA, 2019a: Energy Information Administration, "2018 Annual Electric Generator Report," Form EIA-860, Washington, DC, 2019. https://www.eia.gov/electricitv/data/eia860/ Technical Support Document for eGRID2018 I P9-73 ------- REFERENCES EIA, 2019b: Energy Information Administration, "2018 Power Plant Operations Report," Form EIA- 923, Washington, DC, 2019. https://www.eia.gov/electricitv/data/eia923/ EIA, 2019c: Energy Information Administration, "2018 Annual Electric Power Industry Report," Form EIA-861, Washington, DC, 2019. https ://www. eia. gov/electricitv/data/ eia8 61 / EIA, 2019d: Energy Information Administration, "2018 State Electricity Profiles." http: //www .eia. gov/electricitv/state/ EIA, 2019e: Energy Information Administration, "Electric Power Annual," Tables A-l and A-2, Washington, DC, 2019. https://www.eia.gov/electricitv/annual/ EIA, 2014: Energy Information Administration, "The Electricity Market Module of the National Energy Modeling System: Model Documentation 2014," Figure 3, Washington, DC, August 2014. http://\v\v\v.cia.go\/outlooks/aco/ncms/documcntation/clcctncitv/pdf/m()68(2014).pdf EPA, 2019: EPA Center for Corporate Climate Leadership, https://www.epa.gov/climateleadership EPA, 2017: Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2015. https://www.epa.gov/ghgemissions/inventory-us-greenhouse-gas-emissions-and-sinks-1990-2015 EPA, 2016: LFG Energy Project Development Handbook. Landfill Methane Outreach Program. https://www.epa.gov/sites/production/files/2016-ll/documents/pdh full.pdf EPA, 1995: U.S. Environmental Protection Agency, "Compilation of Air Pollutant Emission Factors, Volume I: Stationary Point and Area Source, AP-42, Fifth Edition." https://www.epa.gov/air- emissions-factors-and-quantification/ap-42-compilation-air-emission-factors EPA, 2009: U.S. Environmental Protection Agency, Final Mandatory Reporting of Greenhouse Gases Rule (Table C-l, Default CO2 Emission Factors and High Heat Values for Various Types of Fuel and Table C-2, Default CH4 and N2O Emission Factors for Various Types of Fuel), Washington, D C., October 30, 2009. https://www.epa.gov/sites/production/files/2015-Q6/documents/ghg-mrr-finalrule.pdf FERC. 2018: United States Federal Energy Regulatory Commission, "Order Granting Approvals in Connection with the Dissolution of the Southwest Power Pool Regional Entitv."https://www.ferc.gov/CalendarFiles/20180504141902-RR18-3-000.pdf GEA, 2007: Alyssa Kagel, Diana Bates, and Karl Gawell. Table 3, Air Emissions Summary, in "A Guide to Geothermal Energy and the Environment", Geothermal Energy Association, Washington, D.C., April 2007. http://geo-energv.org/reports/Environmental%20Guide.pdf GEA, 2016: Geothermal Energy Association, geothermal plant type from annual power production reports, http://geo-energy.org/reports.aspx. Greenhouse Gas Protocol, 2016: The Greenhouse Gas Protocol, http://www.ghgprotocol.org/ Technical Support Document for eGR!D2018 ------- REFERENCES Hoer, et at., 2019: "Adding Particulate Matter to EPA's eGRID Database," presented at the Air and Waste Mangement Association's 112th Annual Conference & Exhibition. https://www.awma.org/files/ACE%202019/ACEFinalProgram2019-FINAL-6-5-2019.pdf IPCC, 2007a: The Intergovernmental Panel on Climate Change (IPCC), "2006 IPCC Guidelines for National Greenhouse Gas Inventories", volume 2 (Energy), April 2007. http://www.ipcc- nggip.iges.or.jp/public/2006gl/pdf/2 Volume2/V2 2 Ch2 Stationary Combustion.pdf IPCC, 2007b: The Intergovernmental Panel on Climate Change (IPCC), "Climate Change 2007: The Physical Science Basis," 2007. https://www.ipcc.ch/site/assets/uploads/2018/05/ar4 wgl full report-l.pdf Johnson, 2016a: Travis Johnson, "How Part 75 Data is Used in GHG Reporting and EE/RE Quantification," EPRI Continuous Emissions Monitoring User Group Conference, Detroit, MI, May 2016. Johnson, 2016b: Travis Johnson, "Emissions & Generation Resource integrated Database (eGRID)," Energy, Utility, and Environment Conference, San Diego, CA, February 2016. Johnson, Schreifels, and Quiroz, 2015: Johnson, T., J. Schreifels, and C. Quiroz, "eGRID Updates." Energy, Utility, and Environment Conference, San Diego, CA, February 2015. Jones and Kammen, 2013: "Data & Calculations for "Quantifying Carbon Footprint Reduction Opportunities for U.S. Households" Cool Climate Network Maps https://docs.google.eom/file/d/OBwI9ptFOU10iM2IzNWEOYTOtNiY4NSOOMzM5LWFkZDUt OWNkY 2NkNTMxOTM4 http://coolclimate.berkelev.edu/maps Maryland, 2010: Maryland Department of the Environment, Technical Support Document for Amendments to COMAR 26.09 MD CO2 Budget Training Program, Baltimore, MD, October 25, 2010. http://www.mde.state.md.us/programs/Air/ClimateChange/RGGI/Documents/TSD MD CQ2 B udgetTradingProgram Amendment.pdf TCR, 2019: The Climate Registry, "General Reporting Protocol Version 3.0," https://www.theclimateregistrv.org/tools-resources/reporting-protocols/general-reporting- protocol/ UCS, 2012: Union of Concerned Scientists, "State of Charge: Electric Vehicles' Global Warming Emissions and Fuel-Cost Savings Across the United States, April 2012. http://www.ucsusa.org/clean vehicles/technologies and fuels/hybrid fuelcell and electric vehi cles/emissions-and-charging-costs-electric- cars.html?utm source=SP&utm medium=head&utm campaign=EV%2BReport US Census, 2017: United States Census Bureau, "2016 State, County, Minor Civil Division, and Incorporated Place FIPS Codes," https://www.census.gov/geographies/reference- files/2016/demo/popest/2016-fips .html Technical Support Document for eGR!D2018 ------- REFERENCES Wheeler, 2007: David Wheeler, Senior Fellow, Center for Global Development, CARMA developer, personal communication, November 30, 2007. "cc 1 lical Support Document c<,>K D2018 | pg, 76 ------- APPENDIX A Appendix A. eGRID File Structure - Variable Descriptions for eGRID2018 The structure of the nine files - including descriptions of the variables, unit of measurement, and original source(s) of data - are delineated below in the file structure. NOTE: Italics indicates new field; bold indicates methodological change. Units in the following tables represent the units in the English unit eGRID2018 workbook. Table A-1. eGRID File Structure, eGRID2018 UNIT Unit File Field Name Description Unit Source(s) 1 SEQUNT18 eGRID2018 file unit sequence number assigned 2 YEAR Data year 3 PSTATABB Plant state abbreviation EIA-860 4 PNAME Plant name EPA/CAMD 5 ORISPL DOE/EIA ORIS plant or facility code EPA/CAMD, EIA-860 6 UNITID Unit ID EPA/CAMD, EIA-923 7 PRMVR Prime Mover EPA/CAMD, EIA-860 8 UNTOPST Unit operational status EPA/CAMD, EIA-860 9 CAMDFLAG CAMD Program flag EPA/CAMD 10 PRGCODE Program code(s) EPA/CAMD 11 BOTFIRTY Boiler bottom and firing type EPA/CAMD, EIA-860 12 NUMGEN Number of associated generators EIA-860 13 FUELU1 Unit primary fuel EPA/CAMD, EIA-923, EIA-860 14 HRSOP Unit operating hours hours EPA/CAMD 15 HTIAN Unit unadjusted annual heat input MMBtu EPA/CAMD, EIA-923 16 HTIOZ Unit unadjusted ozone season heat input MMBtu EPA/CAMD, EIA-923 17 NOXAN Unit unadjusted annual NOx emissions tons EPA/CAMD, EIA-923 18 NOXOZ Unit unadjusted ozone season NOx emissions tons EPA/CAMD, EIA-923 19 S02AN Unit unadjusted annual S02 emissions tons EPA/CAMD 20 C02AN Unit unadjusted annual C02 emissions tons EPA/CAMD 21 HGAN Unit unadjusted annual mercury emissions lbs EPA/CAMD 22 HTIANSRC Unit unadjusted annual heat input source EPA/CAMD, EIA-923 23 HTIOZSRC Unit unadjusted ozone season heat input source EPA/CAMD, EIA-923 24 NOXANSRC Unit unadjusted annual NOx emissions source EPA/CAMD, EIA-923 25 NOXOZSRC Unit unadjusted ozone season NOx emissions source EPA/CAMD, EIA-923 26 S02SRC Unit unadjusted annual S02 emissions source EPA/CAMD, EIA-923 27 C02SRC Unit unadjusted annual C02 emissions source EPA/CAMD, EIA-923 28 HGSRC Unit unadjusted annual mercury emissions source EPA/CAMD 29 S02CTLDV Unit S02 (scrubber) first control device EPA/CAMD, EIA-860 30 NOXCTLDV Unit NOx first control device EPA/CAMD 31 HGCTLDV Unit Hg activated carbon injection system flag EIA-860 32 UNTYRONL Unit year on-line EPA/CAMD, EIA-860 Technical Support Document for eGRID2018 I pg-77 ------- Field 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 APPENDIX A Table A-2. eGRID File Structure, eGRID2018 GEN Generator File Name Description Unit Source(s) SEQGEN18 eGRID2018 file generator sequence number assigned YEAR Data year PSTATABB Plant state abbreviation EIA-860 PNAME Plant name EPA/CAMD; EIA-860 ORISPL DOE/EIA ORIS plant or facility code EPA/CAMD; EIA-860 GENID Generator ID EIA-860 NUMBLR Number of associated boilers EIA-860 GENSTAT Generator status EIA-860 PRMVR Generator prime mover type EIA-860 FUELG1 Generator primary fuel EIA-860 NAMEPCAP Generator nameplate capacity MW EIA-860 CFACT Generator capacity factor calculated GENNTAN Generator annual net generation MWh EIA-923 GENNTOZ Generator ozone season net generation MWh EIA-923 GENERSRC Generation data source Generator year on-line assigned GENYRONL Generator year retired EIA-860 GENYRRET EIA-860 I 78 Technical Support Document for eGR!D2018 ------- APPENDIX A Table A-3. eGRID File Structure, eGRID2018 PLNT Plant File Field Name Description Unit Source(s) 1 SEQPLT18 eGRID 2018 file plant sequence number assigned 2 YEAR Data year 3 PSTATABB Plant state abbreviation EIA-860 4 PNAME Plant name EPA/CAMD; EIA-860 5 ORISPL DOE/EIA ORIS plant or facility code EPA/CAMD; EIA-860 6 OPRNAME Plant operator name EIA-860 7 OPRCODE Plant operator ID EIA-860 8 UTLSRVNM Utility service territory name EIA-860 9 UTLSRVID Utility service territory ID EIA-860 10 SECTOR Plant-level sector EIA-860 11 BANAME Balancing authority name EIA-860; EIA-861 12 BACODE Balancing authority ID code EIA-860; EIA-861 13 NERC NERC region acronym EIA-860 14 SUBRGN eGRID subregion acronym EPA 15 SRNAME eGRID subregion name EPA 16 ISORTO Plant associated ISO/RTO Territory EIA-860 17 FIPSST Plant FIPS state code US Census 18 FIPSCNTY Plant FIPS county code US Census 19 CNTYNAME Plant county name EIA-860 20 LAT Plant latitude EIA-860 21 LON Plant longitude EIA-860 22 NUMUNT Number of units EIA-860 23 NUMGEN Number of generators EIA-860 24 PLPRMFL Plant primary fuel EPA/CAMD; EIA-923 25 PLFUELCT Plant primary fuel category assigned 26 COALFLAG Flag indicating if the plant burned or generated any amount of coal assigned 27 CAPFAC Plant capacity factor calculated 28 NAMEPCAP Plant nameplate capacity MW EIA-860 29 NBFACTOR Plant nonbaseload factor calculated 30 RMBMFLAG Biogas/biomass plant adjustment flag assigned 31 CHPFLAG Combined heat and power (CHP) plant adjustment flag EPA/CAMD; EIA-860 32 USETHRMO CHP plant useful thermal output MMBtu EIA-923 calculated 33 PWRTOHT CHP plant power to heat ratio calculated 34 ELCALLOC CHP plant electric allocation factor calculated 35 PSFLAG Plant pumped storage flag EIA-860 36 PLHTIAN Plant annual heat input for combustion units MMBtu EPA/CAMD; EIA-923 37 PLHTIOZ Plant ozone season heat input for combustion units MMBtu EPA/CAMD; EIA-923 38 PLHTIANT Plant annual heat input for all units MMBtu EPA/CAMD; EIA-923 39 PLHTIOZT Plant ozone season heat input for all units MMBtu EPA/CAMD; EIA-923 40 PLNGENAN Plant annual net generation MWh EIA-923, EPA/CAMD 41 PLNGENOZ Plant ozone season net generation MWh EIA-923, EPA/CAMD 42 PLNOXAN Plant annual NOx emissions tons EPA/CAMD; calculated 43 PLNOXOZ Plant ozone season NOx emissions tons EPA/CAMD; calculated 44 PLS02AN Plant annual S02 emissions tons EPA/CAMD; calculated 45 PLC02AN Plant annual C02 emissions tons EPA/CAMD; calculated 46 PLCH4AN Plant annual CH4 emissions lbs calculated 47 PLN20AN Plant annual N20 emissions lbs calculated "cc 1 lical Support Document c<,>K D2018 | pg, 79 ------- APPENDIX A Field Name Description Unit Source(s) 48 PLC02EQA Plant annual C02 equivalent emissions ((1 * PLC02AN ) + (21 * PLCH4AN/2000) + (310 * PLN20AN/2000)) tons calculated 49 PLHGAN Plant annual Hg emissions lbs not calculated 50 PLNOXRTA Plant annual NOx total output emission rate Ib/MWh calculated 51 PLNOXRTO Plant ozone season NOx total output emission rate Ib/MWh calculated 52 PLS02RTA Plant annual S02 total output emission rate Ib/MWh calculated 53 PLC02RTA Plant annual C02 total output emission rate Ib/MWh calculated 54 PLCH4RTA Plant annual CH4 total output emission rate Ib/MWh calculated 55 PLN20RTA Plant annual N20 total output emission rate Ib/MWh calculated 56 PLC2ERTA Plant annual C02 equivalent total output emission rate Ib/MWh calculated 57 PLHGRTA Plant annual Hg total output emission rate Ib/MWh not calculated 58 PLNOXRA Plant annual NOx input emission rate Ib/MMBtu calculated 59 PLNOXRO Plant ozone season NOx input emission rate Ib/MMBtu calculated 60 PLS02RA Plant annual S02 input emission rate Ib/MMBtu calculated 61 PLC02RA Plant annual C02 input emission rate Ib/MMBtu calculated 62 PLCH4RA Plant annual CH4 input emission rate Ib/MMBtu calculated 63 PLN20RA Plant annual N20 input emission rate Ib/MMBtu calculated 64 PLC2ERA Plant annual C02 equivalent input emission rate Ib/MMBtu calculated 65 PLHGRA Plant annual Hg input emission rate Ib/MMBtu not calculated 66 PLNOXCRT Plant annual NOx combustion output emission rate Ib/MWh calculated 67 PLNOXCRO Plant ozone season NOx combustion output emission rate Ib/MWh calculated 68 PLS02CRT Plant annual S02 combustion output emission rate Ib/MWh calculated 69 PLC02CRT Plant annual C02 combustion output emission rate Ib/MWh calculated 70 PLCH4CRT Plant annual CH4 combustion output emission rate Ib/MWh calculated 71 PLN20CRT Plant annual N20 combustion output emission rate Ib/MWh calculated 72 PLHGCRT Plant annual Hg combustion output emission rate Ib/MWh not calculated 73 UNNOX Plant unadjusted annual NOx emissions tons E PA/CAM D, EIA-923 74 UNNOXOZ Plant unadjusted ozone season NOx emissions tons EPA/CAMD, EIA-923 75 UNS02 Plant unadjusted annual S02 emissions tons EPA/CAMD, EIA-923 76 UNC02 Plant unadjusted annual C02 emissions tons EPA/CAMD, EIA-923 77 UNCH4 Plant unadjusted annual CH4 emissions lbs EPA/CAMD, EIA-923 78 UNN20 Plant unadjusted annual N20 emissions lbs EPA/CAMD, EIA-923 79 UNHG Plant unadjusted annual Hg emissions lbs not calculated 80 UNHTI Plant unadjusted annual heat input for combustion units MMBtu EPA/CAMD, EIA-923 81 UNHTIOZ Plant unadjusted ozone season heat input for combustion units MMBtu EPA/CAMD, EIA-923 82 UNHTIT Plant unadjusted annual heat input for all units MMBtu EPA/CAMD, EIA-923 83 UNHTIOZT Plant unadjusted ozone season heat input for all units MMBtu EPA/CAMD, EIA-923 84 UNNOXSRC Plant unadjusted annual NOx emissions source EPA/CAMD, EIA-923 85 UNNOZSRC Plant unadjusted ozone season NOx emissions source EPA/CAMD, EIA-923 86 UNS02SRC Plant unadjusted annual S02 emissions source EPA/CAMD, EIA-923 87 UNC02SRC Plant unadjusted annual C02 emissions source EPA/CAMD, EIA-923 88 UNCH4SRC Plant unadjusted annual CH4 emissions source EPA/CAMD, EIA-923 Technical Support Document for eGRID2018 I P9-80 ------- APPENDIX A Field Name Description Unit Source(s) 89 UNN20SRC Plant unadjusted annual N20 emissions source E PA/CAM D, EIA-923 90 UNHGSRC Plant unadjusted annual Hg emissions source calculated 91 UNHTISRC Plant unadjusted annual heat input source EPA/CAMD, EIA-923 92 UNHOZSRC Plant unadjusted ozone season heat input source EPA/CAMD, EIA-923 93 BIONOX Plant annual NOx biomass emissions tons EIA-923 94 BIONOXOZ Plant ozone season NOx biomass emissions tons EIA-923 95 BI0S02 Plant annual S02 biomass emissions tons EIA-923 96 BI0C02 Plant annual C02 biomass emissions tons EIA-923 97 BIOCH4 Plant annual CH4 biomass emissions lbs EIA-923 98 BI0N20 Plant annual N20 biomass emissions lbs EIA-923 99 CHPCHTI Plant combustion heat input CHP adjustment value MMBtu calculated 100 CHPCHTIOZ Plant combustion ozone season heat input CHP adjustment value MMBtu calculated 101 CHPNOX Plant annual NOx emissions CHP adjustment value tons calculated 102 CHPNOXOZ Plant ozone season NOx emissions CHP adjustment value tons calculated 103 CHPS02 Plant annual S02 emissions CHP adjustment value tons calculated 104 CHPC02 Plant annual C02 emissions CHP adjustment value lbs calculated 105 CHPCH4 Plant annual CH4 emissions CHP adjustment value lbs calculated 106 CHPN20 Plant annual N20 emissions CHP adjustment value lbs calculated 107 PLHTRT Plant nominal heat rate Btu/kWh calculated 108 PLGENACL Plant annual coal net generation MWh EIA-923 109 PLGENAOL Plant annual oil net generation MWh EIA-923 110 PLGENAGS Plant annual gas net generation MWh EIA-923 111 PLGENANC Plant annual nuclear net generation MWh EIA-923 112 PLGENAHY Plant annual hydro net generation MWh EIA-923 113 PLGENABM Plant annual biomass net generation MWh EIA-923 114 PLGENAWI Plant annual wind net generation MWh EIA-923 115 PLGENASO Plant annual solar net generation MWh EIA-923 116 PLGENAGT Plant annual geothermal net generation MWh EIA-923 117 PLGENAOF Plant annual other fossil net generation MWh EIA-923 118 PLGENAOP Plant annual other unknown/purchased fuel net generation MWh EIA-923 119 PLGENATN Plant annual total nonrenewables net generation MWh EIA-923 120 PLGENATR Plant annual total renewables net generation MWh EIA-923 121 PLGENATH Plant annual total nonhydro renewables net generation MWh EIA-923 122 PLGENACY Plant annual total combustion net generation MWh EIA-923 123 PLGENACN Plant annual total noncombustion net generation MWh EIA-923 124 PLCLPR Plant coal generation percent (resource mix) % calculated 125 PLOLPR Plant oil generation percent (resource mix) % calculated 126 PLGSPR Plant gas generation percent (resource mix) % calculated 127 PLNCPR Plant nuclear generation percent (resource mix) % calculated 128 PLHYPR Plant hydro generation percent (resource mix) % calculated 129 PLBMPR Plant biomass generation percent (resource mix) % calculated 130 PLWIPR Plant wind generation percent (resource mix) % calculated 131 PLSOPR Plant solar generation percent (resource mix) % calculated Technical Support Document for eGRID2018 I pg- 81 ------- APPENDIX A Field Name Description Unit Source(s) 132 PLGTPR Plant geothermal generation percent (resource mix) % calculated 133 PLOFPR Plant other fossil generation percent (resource mix) % calculated 134 PLOPPR Plant other unknown/purchased fuel generation percent (resource mix) % calculated 135 PLTNPR Plant total nonrenewables generation percent (resource mix) % calculated 136 PLTRPR Plant total renewables generation percent (resource mix) % calculated 137 PLTHPR Plant total nonhydro renewables generation percent (resource mix) % calculated 138 PLCYPR Plant total combustion generation percent (resource mix) % calculated 139 PLCNPR Plant total noncombustion generation percent (resource mix) % calculated "cc 1 lical Support Document c<,>K D2018 | pg, 82 ------- ield ~T~ 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27" 28 29 30 37 32 33 34 35~ 36 37 38 39 40 41 42~ 43 44 45 46 47 48 49 50 APPENDIX A Table A-4. eGRID File Structure, eGRID2018 ST State File Name Description Unit YEAR Data year PSTATABB State abbreviation FIPSST FIPS state code NAMEPCAP State nameplate capacity MW STHTIAN State annual heat input from combustion MMBtu STHTIOZ State ozone season heat input from combustion MMBtu STHTIANT State total annual heat input MMBtu STHTIOZT State total ozone season heat input MMBtu STNGENAN State annual net generation MWh STNGENOZ State ozone season net generation MWh STNOXAN State annual NOx emissions tons STNOXOZ State ozone season NOx emissions tons STS02AN State annual S02 emissions tons STC02AN State annual C02 emissions tons STCH4AN State annual CH4 emissions lbs STN20AN State annual N20 emissions lbs STC02EQA State annual C02 equivalent emissions tons STHGAN State annual Hg emissions lbs STNOXRTA State annual NOx total output emission rate Ib/MWh STNOXRTO State ozone season NOx total output emission rate Ib/MWh STS02RTA State annual S02 total output emission rate Ib/MWh STC02RTA State annual C02 total output emission rate Ib/MWh STCH4RTA State annual CH4 total output emission rate Ib/MWh STN20RTA State annual N20 total output emission rate Ib/MWh STC2ERTA State annual C02 equivalent total output emission rate Ib/MWh STHGRTA State annual Hg total output emission rate not calculated STNOXRA State annual NOx input emission rate Ib/MMBtu STNOXRO State ozone season NOx input emission rate Ib/MMBtu STS02RA State annual S02 input emission rate Ib/MMBtu STC02RA State annual C02 input emission rate Ib/MMBtu STCH4RA State annual CH4 input emission rate Ib/MMBtu STN20RA State annual N20 input emission rate Ib/MMBtu STC2ERA State annual C02 equivalent input emission rate Ib/MMBtu STHGRA State annual Hg input emission rate not calculated STNOXCRT State annual NOx combustion output emission rate Ib/MWh STNOXCRO State ozone season NOx combustion output emission rate Ib/MWh STS02CRT State annual S02 combustion output emission rate Ib/MWh STC02CRT State annual C02 combustion output emission rate Ib/MWh STCH4CRT State annual CH4 combustion output emission rate Ib/MWh STN20CRT State annual N20 combustion output emission rate Ib/MWh STHGCRT State annual Hg combustion output emission rate not calculated STCNOXRT State annual NOx coal output emission rate Ib/MWh STONOXRT State annual NOx oil output emission rate Ib/MWh STGNOXRT State annual NOx gas output emission rate Ib/MWh STFSNXRT State annual NOx other fossil fuel output emission rate Ib/MWh STCNXORT State ozone season NOx coal output emission rate Ib/MWh STONXORT State ozone season NOx oil output emission rate Ib/MWh STGNXORT State ozone season NOx gas output emission rate Ib/MWh STFSNORT State ozone season NOx other fossil fuel output emission rate Ib/MWh STCS02RT State annual S02 coal output emission rate Ib/MWh | I5* Technical Support Document for eGR!D2018 ------- APPENDIX A Field Name Description Unit 51 ST0S02RT State annual S02 oil output emission rate Ib/MWh 52 STGS02RT State annual S02 gas output emission rate Ib/MWh 53 STFSS2RT State annual S02 other fossil fuel output emission rate Ib/MWh 54 STCC02RT State annual C02 coal output emission rate Ib/MWh 55 ST0C02RT State annual C02 oil output emission rate Ib/MWh 56 STGC02RT State annual C02 gas output emission rate Ib/MWh 57 STFSC2RT State annual C02 other fossil fuel output emission rate Ib/MWh 58 STCCH4RT State annual CH4 coal output emission rate Ib/MWh 59 STOCH4RT State annual CH4 oil output emission rate Ib/MWh 60 STGCH4RT State annual CH4 gas output emission rate Ib/MWh 61 STFCH4RT State annual CH4 fossil fuel output emission rate Ib/MWh 62 STCN20RT State annual N20 coal output emission rate Ib/MWh 63 ST0N20RT State annual N20 oil output emission rate Ib/MWh 64 STGN20RT State annual N20 gas output emission rate Ib/MWh 65 STFN20RT State annual N20 fossil fuel output emission rate Ib/MWh 66 STCC2ERT State annual C02 equivalent coal output emission rate Ib/MWh 67 STOC2ERT State annual C02 equivalent oil output emission rate Ib/MWh 68 STGC2ERT State annual C02 equivalent gas output emission rate Ib/MWh 69 STFSC2ERT State annual C02 equivalent fossil fuel output emission rate Ib/MWh 70 STCHGRT State annual Hg coal output emission rate not calculated 71 STFSHGRT State annual Hg other fossil fuel output emission rate not calculated 72 STCNOXR State annual NOx coal input emission rate Ib/MMBtu 73 STONOXR State annual NOx oil input emission rate Ib/MMBtu 74 STGNOXR State annual NOx gas input emission rate Ib/MMBtu 75 STFSNXR State annual NOx other fossil fuel input emission rate Ib/MMBtu 76 STCNXOR State ozone season NOx coal input emission rate Ib/MMBtu 77 STONXOR State ozone season NOx oil input emission rate Ib/MMBtu 78 STGNXOR State ozone season NOx gas input emission rate Ib/MMBtu 79 STFSNOR State ozone season NOx other fossil fuel input emission rate Ib/MMBtu 80 STCS02R State annual S02 coal input emission rate Ib/MMBtu 81 STOS02R State annual S02 oil input emission rate Ib/MMBtu 82 STGS02R State annual S02 gas input emission rate Ib/MMBtu 83 STFSS2R State annual S02 other fossil fuel input emission rate Ib/MMBtu 84 STCC02R State annual C02 coal input emission rate Ib/MMBtu 85 STOC02R State annual C02 oil input emission rate Ib/MMBtu 86 STGC02R State annual C02 gas input emission rate Ib/MMBtu 87 STFSC2R State annual C02 other fossil fuel input emission rate Ib/MMBtu 88 STCCH4R State annual CH4 coal input emission rate Ib/MMBtu 89 STOCH4R State annual CH4 oil input emission rate Ib/MMBtu 90 STGCH4R State annual CH4 gas input emission rate Ib/MMBtu 91 STFCH4R State annual CH4 fossil fuel input emission rate Ib/MMBtu 92 STCN20R State annual A/20 coal input emission rate Ib/MMBtu 93 STON20R State annual A/20 oil input emission rate Ib/MMBtu 94 STGN20R State annual N20 gas input emission rate Ib/MMBtu 95 STFN20R State annual N20 fossil fuel input emission rate Ib/MMBtu 96 STCC2ER State annual C02 equivalent coal input emission rate Ib/MMBtu 97 STOC2ER State annual C02 equivalent oil input emission rate Ib/MMBtu 98 STGC2ER State annual C02 equivalent gas input emission rate Ib/MMBtu 99 STFSC2ER State annual C02 equivalent fossil fuel input emission rate Ib/MMBtu 100 STCHGR State annual Hg coal input emission rate not calculated 101 STFSHGR State annual Hg other fossil fuel input emission rate not calculated "cc 1 lical Support Document c<,>K D2018 | pg, 84 ------- APPENDIX A Field Name Description Unit 102 STNBNOX State annual NOx nonbaseload output emission rate Ib/MWh 103 STNBNXO State ozone season NOx nonbaseload output emission rate Ib/MWh 104 STNBS02 State annual S02 nonbaseload output emission rate Ib/MWh 105 STNBC02 State annual C02 nonbaseload output emission rate Ib/MWh 106 STNBCH4 State annual CH4 nonbaseload output emission rate Ib/MWh 107 STNBN20 State annual N20 nonbaseload output emission rate Ib/MWh 108 STNBC2E State annual C02 equivalent nonbaseload output emission rate Ib/MWh 109 STNBHG State annual Hg nonbaseload output emission rate not calculated 110 STGENACL State annual coal net generation MWh 111 STGENAOL State annual oil net generation MWh 112 STGENAGS State annual gas net generation MWh 113 STGENANC State annual nuclear net generation MWh 114 STGENAHY State annual hydro net generation MWh 115 STGENABM State annual biomass net generation MWh 116 STGENAWI State annual wind net generation MWh 117 STGENASO State annual solar net generation MWh 118 STGENAGT State annual geothermal net generation MWh 119 STGENAOF State annual other fossil net generation MWh 120 STGENAOP State annual other unknown/purchased fuel net generation MWh 121 STGENATN State annual total nonrenewables net generation MWh 122 STGENATR State annual total renewables net generation MWh 123 STGENATH State annual total nonhydro renewables net generation MWh 124 STGENACY State annual total combustion net generation MWh 125 STGENACN State annual total noncombustion net generation MWh 126 STCLPR State coal generation percent (resource mix) % 127 STOLPR State oil generation percent (resource mix) % 128 STGSPR State gas generation percent (resource mix) % 129 STNCPR State nuclear generation percent (resource mix) % 130 STHYPR State hydro generation percent (resource mix) % 131 STBMPR State biomass generation percent (resource mix) % 132 STWIPR State wind generation percent (resource mix) % 133 STSOPR State solar generation percent (resource mix) % 134 STGTPR State geothermal generation percent (resource mix) % 135 STOFPR State other fossil generation percent (resource mix) % 136 STOPPR State other unknown/purchased fuel generation percent (resource mix) % 137 STTNPR State total nonrenewables generation percent (resource mix) % 138 STTRPR State total renewables generation percent (resource mix) % 139 STTHPR State total nonhydro renewables generation percent (resource mix) % 140 STCYPR State total combustion generation percent (resource mix) % 141 STCNPR State total noncombustion generation percent (resource mix) % 142 STNBGNCL State annual total nonbaseload coal generation MWh 143 STNBGNOL State annual total nonbaseload oil generation MWh 144 STNBGNGS State annual total nonbaseload gas generation MWh 145 STNBGNNC State annual total nonbaseload nuclear generation MWh 146 STNBGNHY State annual total nonbaseload hydro generation MWh 147 STNBGNBM State annual total nonbaseload biomass generation MWh 148 STNBGNWI State annual total nonbaseload wind generation MWh 149 STNBGNSO State annual total nonbaseload solar generation MWh 150 STNBGNGT State annual total nonbaseload geothermal generation MWh 151 STNBGNOF State annual total nonbaseload other fossil generation MWh 152 STNBGNOP State annual total nonbaseload other unknown/purchased fuel generation MWh 153 STNBCLPR State nonbaseload coal generation percent (resource mix) % 154 STNBOLPR State nonbaseload oil generation percent (resource mix) % "cc 1 lical Support Document c<,>K D2018 | pg, 85 ------- APPENDIX A Field Name Description Unit 155 STNBGSPR State nonbaseload gas generation percent (resource mix) % 156 STNBNCPR State nonbaseload nuclear generation percent (resource mix) % 157 STNBHYPR State nonbaseload hydro generation percent (resource mix) % 158 STNBBMPR State nonbaseload biomass generation percent (resource mix) % 159 STNBWIPR State nonbaseload wind generation percent (resource mix) % 160 STNBSOPR State nonbaseload solar generation percent (resource mix) % 161 STNBGTPR State nonbaseload geothermal generation percent (resource mix) % 162 STNBOFPR State nonbaseload other fossil generation percent (resource mix) % 163 STNBOPPR State nonbaseload other unknown/purchased fuel generation percent (resource mix) % "cc 1 lical Support Document c<,>K D2018 | pg, 86 ------- APPENDIX A Table A-5. eGRID File Structure, eGRID2018 BA File, Balancing Authority (BA) File Field Name Description Unit 1 YEAR Data year 2 BANAME BA name 3 BACODE BA code 4 NAMEPCAP BA nameplate capacity MW 5 BAHTIAN BA annual heat input from combustion MMBtu 6 BAHTIOZ BA ozone season heat input from combustion MMBtu 7 BAHTIANT BA total annual heat input MMBtu 8 BAHTIOZT BA total ozone season heat input MMBtu 9 BANGENAN BA annual net generation MWh 10 BANGENOZ BA ozone season net generation MWh 11 BANOXAN BA annual NOx emissions tons 12 BANOXOZ BA ozone season NOx emissions tons 13 BAS02AN BA annual S02 emissions tons 14 BAC02AN BA annual C02 emissions tons 15 BACH4AN BA annual CH4 emissions lbs 16 BAN20AN BA annual N20 emissions lbs 17 BAC02EQA BA annual C02 equivalent emissions tons 18 BAHGAN BA annual Hg emissions lbs 19 BANOXRTA BA annual NOx total output emission rate Ib/MWh 20 BANOXRTO BA ozone season NOx total output emission rate Ib/MWh 21 BAS02RTA BA annual S02 total output emission rate Ib/MWh 22 BAC02RTA BA annual C02 total output emission rate Ib/MWh 23 BACH4RTA BA annual CH4 total output emission rate Ib/MWh 24 BAN20RTA BA annual N20 total output emission rate Ib/MWh 25 BAC2ERTA BA annual C02 equivalent total output emission rate Ib/MWh 26 BAHGRTA BA annual Hg total output emission rate Ib/MWh 27 BANOXRA BA annual NOx input emission rate Ib/MMBtu 28 BANOXRO BA ozone season NOx input emission rate Ib/MMBtu 29 BAS02RA BA annual S02 input emission rate Ib/MMBtu 30 BAC02RA BA annual C02 input emission rate Ib/MMBtu 31 BACH4RA BA annual CH4 input emission rate Ib/MMBtu 32 BAN20RA BA annual N20 input emission rate Ib/MMBtu 33 BAC2ERA BA annual C02 equivalent input emission rate Ib/MMBtu 34 BAHGRA BA annual Hg input emission rate Ib/MMBtu 35 BANOXCRT BA annual NOx combustion output emission rate Ib/MWh 36 BANOXCRO BA ozone season NOx combustion output emission rate Ib/MWh 37 BAS02CRT BA annual S02 combustion output emission rate Ib/MWh 38 BAC02CRT BA annual C02 combustion output emission rate Ib/MWh 39 BACH4CRT BA annual CH4 combustion output emission rate Ib/MWh 40 BAN20CRT BA annual N20 combustion output emission rate Ib/MWh 41 BAHGCRT BA annual Hg combustion output emission rate Ib/MWh 42 BACNOXRT BA annual NOx coal output emission rate Ib/MWh 43 BAONOXRT BA annual NOx oil output emission rate Ib/MWh 44 BAGNOXRT BA annual NOx gas output emission rate Ib/MWh 45 BAFSNXRT BA annual NOx fossil fuel output emission rate Ib/MWh 46 BACNXORT BA ozone season NOxcoal output emission rate Ib/MWh 47 BAONXORT BA ozone season NOx oil output emission rate Ib/MWh 48 BAGNXORT BA ozone season NOx gas output emission rate Ib/MWh 49 BAFSNORT BA ozone season NOx fossil fuel output emission rate Ib/MWh 50 BACS02RT BA annual S02 coal output emission rate Ib/MWh 51 BAOS02RT BA annual S02 oil output emission rate Ib/MWh 52 BAGS02RT BA annual S02 gas output emission rate Ib/MWh "cc 1 lical Support Document c<,>K D2018 | pg, 87 ------- APPENDIX A Field Name Description Unit 53 BAFSS2RT BA annual S02 fossil fuel output emission rate Ib/MWh 54 BACC02RT BA annual C02 coal output emission rate Ib/MWh 55 BA0C02RT BA annual C02 oil output emission rate Ib/MWh 56 BAGC02RT BA annual C02 gas output emission rate Ib/MWh 57 BAFSC2RT BA annual C02 fossil fuel output emission rate Ib/MWh 58 BACCH4RT BA annual CH4 coal output emission rate Ib/MWh 59 BA0CH4RT BA annual CH4 oil output emission rate Ib/MWh 60 BAGCH4RT BA annual CH4 gas output emission rate Ib/MWh 61 BAFCH4RT BA annual CH4 fossil fuel output emission rate Ib/MWh 62 BACN20RT BA annual N20 coal output emission rate Ib/MWh 63 BA0N20RT BA annual N20 oil output emission rate Ib/MWh 64 BAGN20RT BA annual N20 gas output emission rate Ib/MWh 65 BAFN20RT BA annual N20 fossil fuel output emission rate Ib/MWh 66 BACC2ERT BA annual C02 equivalent coal output emission rate Ib/MWh 67 BA0C2ERT BA annual C02 equivalent oil output emission rate Ib/MWh 68 BAGC2ERT BA annual C02 equivalent gas output emission rate Ib/MWh 69 BAFSC2ERT BA annual C02 equivalent fossil fuel output emission rate Ib/MWh 70 BACHGRT BA annual Hg coal output emission rate Ib/MWh 71 BAFSHGRT BA annual Hg fossil fuel output emission rate Ib/MWh 72 BACNOXR BA annual NOx coal input emission rate Ib/MMBtu 73 BAONOXR BA annual NOx oil input emission rate Ib/MMBtu 74 BAGNOXR BA annual NOx gas input emission rate Ib/MMBtu 75 BAFSNXR BA annual NOx fossil fuel input emission rate Ib/MMBtu 76 BACNXOR BA ozone season NOx coal input emission rate Ib/MMBtu 77 BAONXOR BA ozone season NOx oil input emission rate Ib/MMBtu 78 BAGNXOR BA ozone season NOx gas input emission rate Ib/MMBtu 79 BAFSNOR BA ozone season NOx fossil fuel input emission rate Ib/MMBtu 80 BACS02R BA annual S02 coal input emission rate Ib/MMBtu 81 BAOS02R BA annual S02 oil input emission rate Ib/MMBtu 82 BAGS02R BA annual S02 gas input emission rate Ib/MMBtu 83 BAFSS2R BA annual S02 fossil fuel input emission rate Ib/MMBtu 84 BACC02R BA annual C02 coal input emission rate Ib/MMBtu 85 BAOC02R BA annual C02 oil input emission rate Ib/MMBtu 86 BAGC02R BA annual C02 gas input emission rate Ib/MMBtu 87 BAFSC2R BA annual C02 fossil fuel input emission rate Ib/MMBtu 88 BACCH4R BA annual CH4 coal input emission rate Ib/MMBtu 89 BAOCH4R BA annual CH4 oil input emission rate Ib/MMBtu 90 BAGCH4R BA annual CH4 gas input emission rate Ib/MMBtu 91 BAFCH4R BA annual CH4 fossil fuel input emission rate Ib/MMBtu 92 BACN20R BA annual N20 coal input emission rate Ib/MMBtu 93 BAON20R BA annual N20 oil input emission rate Ib/MMBtu 94 BAGN20R BA annual N20 gas input emission rate Ib/MMBtu 95 BAFN20R BA annual N20 fossil fuel input emission rate Ib/MMBtu 96 BACC2ER BA annual C02 equivalent coal input emission rate Ib/MMBtu 97 BAOC2ER BA annual C02 equivalent oil input emission rate Ib/MMBtu 98 BAGC2ER BA annual C02 equivalent gas input emission rate Ib/MMBtu 99 BAFSC2ER BA annual C02 equivalent fossil fuel input emission rate Ib/MMBtu 100 BACHGR BA annual Hg coal input emission rate Ib/MMBtu 101 BAFSHGR BA annual Hg fossil fuel input emission rate Ib/MMBtu 102 BANBNOX BA annual NOx nonbaseload output emission rate Ib/MWh 103 BANBNXO BA ozone season NOx nonbaseload output emission rate Ib/MWh 104 BANBS02 BA annual S02 nonbaseload output emission rate Ib/MWh 105 BANBC02 BA annual C02 nonbaseload output emission rate Ib/MWh 106 BANBCH4 BA annual CH4 nonbaseload output emission rate Ib/MWh Technical Support Document for eGRID2018 I P9-88 ------- APPENDIX A Field Name Description Unit 107 BANBN20 BA annual N20 nonbaseload output emission rate Ib/MWh 108 BANBC2E BA annual C02 equivalent nonbaseload output emission rate Ib/MWh 109 BANBHG BA annual Hg nonbaseload output emission rate Ib/MWh 110 BAGENACL BA annual coal net generation MWh 111 BAGENAOL BA annual oil net generation MWh 112 BAGENAGS BA annual gas net generation MWh 113 BAGENANC BA annual nuclear net generation MWh 114 BAGENAHY BA annual hydro net generation MWh 115 BAGENABM BA annual biomass net generation MWh 116 BAGENAWI BA annual wind net generation MWh 117 BAGENASO BA annual solar net generation MWh 118 BAGENAGT BA annual geothermal net generation MWh 119 BAGENAOF BA annual other fossil net generation MWh 120 BAGENAOP BA annual other unknown/purchased fuel net generation MWh 121 BAGENATN BA annual total nonrenewables net generation MWh 122 BAGENATR BA annual total renewables net generation MWh 123 BAGENATH BA annual total nonhydro renewables net generation MWh 124 BAGENACY BA annual total combustion net generation MWh 125 BAGENACN BA annual total noncombustion net generation MWh 126 BACLPR BA coal generation percent (resource mix) % 127 BAOLPR BA oil generation percent (resource mix) % 128 BAGSPR BA gas generation percent (resource mix) % 129 BANCPR BA nuclear generation percent (resource mix) % 130 BAHYPR BA hydro generation percent (resource mix) % 131 BABMPR BA biomass generation percent (resource mix) % 132 BAWIPR BA wind generation percent (resource mix) % 133 BASOPR BA solar generation percent (resource mix) % 134 BAGTPR BA geothermal generation percent (resource mix) % 135 BAOFPR BA other fossil generation percent (resource mix) % 136 BAOPPR BA other unknown/purchased fuel generation percent (resource mix) % 137 BATNPR BA total nonrenewables generation percent (resource mix) % 138 BATRPR BA total renewables generation percent (resource mix) % 139 BATHPR BA total nonhydro renewables generation percent (resource mix) % 140 BACYPR BA total combustion generation percent (resource mix) % 141 BACNPR BA total noncombustion generation percent (resource mix) % 142 BANBGNCL BA annual total nonbaseload coal generation MWh 143 BANBGNOL BA annual total nonbaseload oil generation MWh 144 BANBGNGS BA annual total nonbaseload gas generation MWh 145 BANBGNNC BA annual total nonbaseload nuclear generation MWh 146 BANBGNHY BA annual total nonbaseload hydro generation MWh 147 BANBGNBM BA annual total nonbaseload biomass generation MWh 148 BANBGNWI BA annual total nonbaseload wind generation MWh 149 BANBGNSO BA annual total nonbaseload solar generation MWh 150 BANBGNGT BA annual total nonbaseload geothermal generation MWh 151 BANBGNOF BA annual total nonbaseload other fossil generation MWh 152 BANBGNOP BA annual total nonbaseload other unknown/purchased fuel generation MWh 153 BANBCLPR BA nonbaseload coal generation percent (resource mix) % 154 BANBOLPR BA nonbaseload oil generation percent (resource mix) % 155 BANBGSPR BA nonbaseload gas generation percent (resource mix) % 156 BANBNCPR BA nonbaseload nuclear generation percent (resource mix) % 157 BANBHYPR BA nonbaseload hydro generation percent (resource mix) % 158 BANBBMPR BA nonbaseload biomass generation percent (resource mix) % 159 BANBWIPR BA nonbaseload wind generation percent (resource mix) % "cc 1 lical Support Document c<,>K D2018 | pg, 89 ------- APPENDIX A Field Name Description Unit 160 BANBSOPR BA nonbaseload solar generation percent (resource mix) % 161 BANBGTPR BA nonbaseload geothermal generation percent (resource mix) % 162 BANBOFPR BA nonbaseload other fossil generation percent (resource mix) % 163 BANBOPPR BA nonbaseload other unknown/purchased fuel generation percent (resource mix) % "cc 1 lical Support Document c<,>K D2018 | pg, 90 ------- APPENDIX A Table A-6. eGRID File Structure, eGRID2018 SRL File, eGRID Subregion File Field Name Description Unit 1 YEAR Data year 2 SUBRGN eGRID subregion acronym 3 SRNAME eGRID subregion name 4 NAMEPCAP eGRID subregion nameplate capacity MW 5 SRHTIAN eGRID subregion annual heat input from combustion MMBtu 6 SRHTIOZ eGRID subregion ozone season heat input from combustion MMBtu 7 SRHTIANT eGRID subregion total annual heat input MMBtu 8 SRHTIOZT eGRID subregion total ozone season heat input MMBtu 9 SRNGENAN eGRID subregion annual net generation MWh 10 SRNGENOZ eGRID subregion ozone season net generation MWh 11 SRNOXAN eGRID subregion annual NOx emissions tons 12 SRNOXOZ eGRID subregion ozone season NOx emissions tons 13 SRS02AN eGRID subregion annual S02 emissions tons 14 SRC02AN eGRID subregion annual C02 emissions tons 15 SRCH4AN eGRID subregion annual CH4 emissions lbs 16 SRN20AN eGRID subregion annual N20 emissions lbs 17 SRC02EQA eGRID subregion annual C02 equivalent emissions tons 18 SRHGAN eGRID subregion annual Hg emissions lbs 19 SRNOXRTA eGRID subregion annual NOx total output emission rate Ib/MWh 20 SRNOXRTO eGRID subregion ozone season NOx total output emission rate Ib/MWh 21 SRS02RTA eGRID subregion annual S02 total output emission rate Ib/MWh 22 SRC02RTA eGRID subregion annual C02 total output emission rate Ib/MWh 23 SRCH4RTA eGRID subregion annual CH4 total output emission rate Ib/MWh 24 SRN20RTA eGRID subregion annual N20 total output emission rate Ib/MWh 25 SRC2ERTA eGRID subregion annual C02 equivalent total output emission rate Ib/MWh 26 SRHGRTA eGRID subregion annual Hg total output emission rate Ib/MWh 27 SRNOXRA eGRID subregion annual NOx input emission rate Ib/MMBtu 28 SRNOXRO eGRID subregion ozone season NOx input emission rate Ib/MMBtu 29 SRS02RA eGRID subregion annual S02 input emission rate Ib/MMBtu 30 SRC02RA eGRID subregion annual C02 input emission rate Ib/MMBtu 31 SRCH4RA eGRID subregion annual CH4 input emission rate Ib/MMBtu 32 SRN20RA eGRID subregion annual N20 input emission rate Ib/MMBtu 33 SRC2ERA eGRID subregion annual C02 equivalent input emission rate Ib/MMBtu 34 SRHGRA eGRID subregion annual Hg input emission rate Ib/MMBtu 35 SRNOXCRT eGRID subregion annual NOx combustion output emission rate Ib/MWh 36 SRNOXCRO eGRID subregion ozone season NOx combustion output emission rate Ib/MWh 37 SRS02CRT eGRID subregion annual S02 combustion output emission rate Ib/MWh 38 SRC02CRT eGRID subregion annual C02 combustion output emission rate Ib/MWh 39 SRCH4CRT eGRID subregion annual CH4 combustion output emission rate Ib/MWh 40 SRN20CRT eGRID subregion annual N20 combustion output emission rate Ib/MWh 41 SRHGCRT eGRID subregion annual Hg combustion output emission rate Ib/MWh 42 SRCNOXRT eGRID subregion annual NOx coal output emission rate Ib/MWh 43 SRONOXRT eGRID subregion annual NOx oil output emission rate Ib/MWh 44 SRGNOXRT eGRID subregion annual NOx gas output emission rate Ib/MWh 45 SRFSNXRT eGRID subregion annual NOx fossil fuel output emission rate Ib/MWh 46 SRCNXORT eGRID subregion ozone season NOxcoal output emission rate Ib/MWh 47 SRONXORT eGRID subregion ozone season NOx oil output emission rate Ib/MWh 48 SRGNXORT eGRID subregion ozone season NOx gas output emission rate Ib/MWh 49 SRFSNORT eGRID subregion ozone season NOx fossil fuel output emission rate Ib/MWh 50 SRCS02RT eGRID subregion annual S02 coal output emission rate Ib/MWh 51 SROS02RT eGRID subregion annual S02 oil output emission rate Ib/MWh 52 SRGS02RT eGRID subregion annual S02 gas output emission rate Ib/MWh . : ileal Support Document*.- . «,>: D20 _ 91 ------- APPENDIX A Field Name Description Unit 53 SRFSS2RT eGRID subregion annual S02 fossil fuel output emission rate Ib/MWh 54 SRCC02RT eGRID subregion annual C02 coal output emission rate Ib/MWh 55 SR0C02RT eGRID subregion annual C02 oil output emission rate Ib/MWh 56 SRGC02RT eGRID subregion annual C02 gas output emission rate Ib/MWh 57 SRFSC2RT eGRID subregion annual C02 fossil fuel output emission rate Ib/MWh 58 SRCCH4RT eGRID subregion annual CH4 coal output emission rate Ib/MWh 59 SR0CH4RT eGRID subregion annual CH4 oil output emission rate Ib/MWh 60 SRGCH4RT eGRID subregion annual CH4 gas output emission rate Ib/MWh 61 SRFCH4RT eGRID subregion annual CH4 fossil fuel output emission rate Ib/MWh 62 SRCN20RT eGRID subregion annual N20 coal output emission rate Ib/MWh 63 SR0N20RT eGRID subregion annual N20 oil output emission rate Ib/MWh 64 SR0N20RT eGRID subregion annual N20 gas output emission rate Ib/MWh 65 SRFN20RT eGRID subregion annual N20 fossil output emission rate Ib/MWh 66 SRCC2ERT eGRID subregion annual C02 equivalent coal output emission rate Ib/MWh 67 SR0C2ERT eGRID subregion annual C02 equivalent oil output emission rate Ib/MWh 68 SRGC2ERT eGRID subregion annual C02 equivalent gas output emission rate Ib/MWh 69 SRFSC2ERT eGRID subregion annual C02 equivalent fossil fuel output emission rate Ib/MWh 70 SRCHGRT eGRID subregion annual Hg coal output emission rate Ib/MWh 71 SRFSHGRT eGRID subregion annual Hg fossil fuel output emission rate Ib/MWh 72 SRCNOXR eGRID subregion annual NOx coal input emission rate Ib/MMBtu 73 SRONOXR eGRID subregion annual NOx oil input emission rate Ib/MMBtu 74 SRGNOXR eGRID subregion annual NOx gas input emission rate Ib/MMBtu 75 SRFSNXR eGRID subregion annual NOx fossil fuel input emission rate Ib/MMBtu 76 SRCNXOR eGRID subregion ozone season NOx coal input emission rate Ib/MMBtu 77 SRONXOR eGRID subregion ozone season NOx oil input emission rate Ib/MMBtu 78 SRGNXOR eGRID subregion ozone season NOx gas input emission rate Ib/MMBtu 79 SRFSNOR eGRID subregion ozone season NOx fossil fuel input emission rate Ib/MMBtu 80 SRCS02R eGRID subregion annual S02 coal input emission rate Ib/MMBtu 81 SROS02R eGRID subregion annual S02 oil input emission rate Ib/MMBtu 82 SRGS02R eGRID subregion annual S02 gas input emission rate Ib/MMBtu 83 SRFSS2R eGRID subregion annual S02 fossil fuel input emission rate Ib/MMBtu 84 SRCC02R eGRID subregion annual C02 coal input emission rate Ib/MMBtu 85 SROC02R eGRID subregion annual C02 oil input emission rate Ib/MMBtu 86 SRGC02R eGRID subregion annual C02 gas input emission rate Ib/MMBtu 87 SRFSC2R eGRID subregion annual C02 fossil fuel input emission rate Ib/MMBtu 88 SRCCH4R eGRID subregion annual CH4 coal input emission rate Ib/MMBtu 89 SROCH4R eGRID subregion annual CH4 oil input emission rate Ib/MMBtu 90 SRGCH4R eGRID subregion annual CH4 gas input emission rate Ib/MMBtu 91 SRFCH4R eGRID subregion annual CH4 fossil input emission rate Ib/MMBtu 92 SRCN20R eGRID subregion annual N20 coal input emission rate Ib/MMBtu 93 SRON20R eGRID subregion annual N20 oil input emission rate Ib/MMBtu 94 SRGN20R eGRID subregion annual N20 gas input emission rate Ib/MMBtu 95 SRFN20R eGRID subregion annual N20 fossil input emission rate Ib/MMBtu 96 SRCC2ER eGRID subregion annual C02 equivalent coal input emission rate Ib/MMBtu 97 SROC2ER eGRID subregion annual C02 equivalent oil input emission rate Ib/MMBtu 98 SRGC2ER eGRID subregion annual C02 equivalent gas input emission rate Ib/MMBtu 99 SRFSC2ER eGRID subregion annual C02 equivalent fossil fuel input emission rate Ib/MMBtu 100 SRCHGR eGRID subregion annual Hg coal input emission rate Ib/MMBtu 101 SRFSHGR eGRID subregion annual Hg fossil fuel input emission rate Ib/MMBtu 102 SRNBNOX eGRID subregion annual NOx nonbaseload output emission rate Ib/MWh 103 SRNBNXO eGRID subregion ozone season NOx nonbaseload output emission rate Ib/MWh 104 SRNBS02 eGRID subregion annual S02 nonbaseload output emission rate Ib/MWh 105 SRNBC02 eGRID subregion annual C02 nonbaseload output emission rate Ib/MWh 106 SRNBCH4 eGRID subregion annual CH4 nonbaseload output emission rate Ib/MWh Technical Support Document for eGRID2018 I pg-92 ------- Field 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 APPENDIX A Name Description Unit SRNBN20 eGRID subregion annual N20 nonbaseload output emission rate Ib/MWh SRNBC2E eGRID subregion annua C02e nonbaseload output emission rate Ib/MWh SRNBHG eGRID subregion annua Hg nonbaseload output emission rate Ib/MWh SRGENACL eGRID subregion annua coal net generation MWh SRGENAOL eGRID subregion annua oil net generation MWh SRGENAGS eGRID subregion annua gas net generation MWh SRGENANC eGRID subregion annua nuclear net generation MWh SRGENAHY eGRID subregion annua hydro net generation MWh SRGENABM eGRID subregion annua biomass net generation MWh SRGENAWI eGRID subregion annua wind net generation MWh SRGENASO eGRID subregion annua solar net generation MWh SRGENAGT eGRID subregion annua geothermal net generation MWh SRGENAOF eGRID subregion annua other fossil net generation MWh SRGENAOP eGRID subregion annua other unknown/purchased fuel net generation MWh SRGENATN eGRID subregion annua total nonrenewables net generation MWh SRGENATR eGRID subregion annua total renewables net generation MWh SRGENATH eGRID subregion annua total nonhydro renewables net generation MWh SRGENACY eGRID subregion annua total combustion net generation MWh SRGENACN eGRID subregion annual total noncombustion net generation MWh SRCLPR eGRID subregion coal generation percent (resource mix) % SROLPR eGRID subregion oil generation percent (resource mix) % SRGSPR eGRID subregion gas generation percent (resource mix) % SRNCPR eGRID subregion nuclear generation percent (resource mix) % SRHYPR eGRID subregion hydro generation percent (resource mix) % SRBMPR eGRID subregion biomass generation percent (resource mix) % SRWIPR eGRID subregion wind generation percent (resource mix) % SRSOPR eGRID subregion solar generation percent (resource mix) % SRGTPR eGRID subregion geothermal generation percent (resource mix) % SROFPR eGRID subregion other fossil generation percent (resource mix) % SROPPR eGRID subregion other unknown/purchased fuel generation percent (resource mix) % SRTNPR eGRID subregion total nonrenewables generation percent (resource mix) % SRTRPR eGRID subregion total renewables generation percent (resource mix) % SRTHPR eGRID subregion total nonhydro renewables generation percent (resource mix) % SRCYPR eGRID subregion total combustion generation percent (resource mix) % SRCNPR eGRID subregion total noncombustion generation percent (resource mix) % SRNBGNCL eGRID subregion annual total nonbaseload coal generation MWh SRNBGNOL eGRID subregion annual total nonbaseload oil generation MWh SRNBGNGS eGRID subregion annual total nonbaseload gas generation MWh SRNBGNNC eGRID subregion annual total nonbaseload nuclear generation MWh SRNBGNHY eGRID subregion annual total nonbaseload hydro generation MWh SRNBGNBM eGRID subregion annual total nonbaseload biomass generation MWh SRNBGNWI eGRID subregion annual total nonbaseload wind generation MWh SRNBGNSO eGRID subregion annual total nonbaseload solar generation MWh SRNBGNGT eGRID subregion annual total nonbaseload geothermal generation MWh SRNBGNOF eGRID subregion annual total nonbaseload other fossil generation MWh SRNBGNOP eGRID subregion annual total nonbaseload other unknown/purchased fuel generation MWh SRNBCLPR eGRID subregion nonbaseload coal generation percent (resource mix) % SRNBOLPR eGRID subregion nonbaseload oil generation percent (resource mix) % SRNBGSPR eGRID subregion nonbaseload gas generation percent (resource mix) % SRNBNCPR eGRID subregion nonbaseload nuclear generation percent (resource mix) % SRNBHYPR eGRID subregion nonbaseload hydro generation percent (resource mix) % SRNBBMPR eGRID subregion nonbaseload biomass generation percent (resource mix) % | 93 Technical Support Document for eGR!D2018 ------- APPENDIX A Field Name Description Unit 159 SRNBWIPR eGRID subregion nonbaseload wind generation percent (resource mix) % 160 SRNBSOPR eGRID subregion nonbaseload solar generation percent (resource mix) % 161 SRNBGTPR eGRID subregion nonbaseload geothermal generation percent (resource mix) % 162 SRNBOFPR eGRID subregion nonbaseload other fossil generation percent (resource mix) % 163 SRNBOPPR eGRID subregion nonbaseload other unknown/purchased fuel generation percent (resource mix) % "cc 1 lical Support Document c<,>K D2018 | pg, 94 ------- Field 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 APPENDIX A Table A-7. eGRID File Structure, eGRID2018 NRL File, NERC Region File Name Description YEAR Data year NERC NERC region acronym NERCNAME NERC region name NAMEPCAP NERC region nameplate capacity NRHTIAN NERC region annual heat input from combustion NRHTIOZ NERC region ozone season heat input from combustion NRHTIANT NERC total region annual heat input NRHTIOZT NERC total region ozone season heat input NRNGENAN NERC region annual net generation NRNGENOZ NERC region ozone season net generation NRNOXAN NERC region annual NOx emissions NRNOXOZ NERC region ozone season NOx emissions NRS02AN NERC region annual S02 emissions NRC02AN NERC region annual C02 emissions NRCH4AN NERC region annual CH4 emissions NRN20AN NERC region annual N20 emissions NRC02EQA NERC region annual C02equivalent emissions NRHGAN NERC region annual Hg emissions NRNOXRTA NERC region annual NOx total output emission rate NRNOXRTO NERC region ozone season NOx total output emission rate I I IVw. J^UJul I I \ >*¦/X UUL|JUl ^1 I IIOOK region annual S02 total output emission rate region annual C02 total output emission rate NRS02RTA NERC NRC02RTA NERC i iui i ai ii iuui w lului i_i i i iooiui i i uiu region annual CH4 total output emission rate region annual N20 total output emission rate NRCH4RTA NERC NRN20RTA NERC NRC2ERTA NERC region annual C02 equivalent total output emission rate NRHGRTA NERC region annual Hg total output emission rate NRNOXRA NERC region annual NOx input emission rate NRNOXRO NERC region ozone season NOx input emission rate NRS02RA NERC region annual S02 input emission rate NRC02RA NERC region annual C02 input emission rate NRCH4RA NERC region annual CH4 input emission rate NRN20RA NERC region annual N20 input emission rate NRC2ERA NERC region annual C02 equivalent input emission rate NRHGRA NERC region annual Hg input emission rate NRNOXCRT NERC region annual NOx combustion output emission rate NRNOXCRO NERC region ozone season NOx combustion output emission rate NRS02CRT NERC region annual S02 combustion output emission rate NRC02CRT NERC region annual C02 combustion output emission rate NRCH4CRT NERC region annual CH4 combustion output emission rate NRN20CRT NERC region annual N20 combustion output emission rate NRHGCRT NERC region annual Hg combustion output emission rate NRCNOXRT NERC region annual NOx coal output emission rate NRONOXRT NERC region annual NOx oil output emission rate NRGNOXRT NERC region annual NOx gas output emission rate NRFSNXRT NERC region annual NOx fossil fuel output emission rate NRCNXORT NERC region ozone season NOxcoal output emission rate NRONXORT NERC region ozone season NOx oil output emission rate NRGNXORT NERC region ozone season NOx gas output emission rate NRFSNORT NERC region ozone season NOx fossil fuel output emission rate NRCS02RT NERC region annual S02 coal output emission rate NROS02RT NERC region annual S02 oil output emission rate NRGS02RT NERC region annual S02 gas output emission rate Technical Support Document for eGRID2018 I P9-95 ------- APPENDIX A Field Name Description Unit 53 NRFSS2RT NERC region annual S02 fossil fuel output emission rate Ib/MWh 54 NRCC02RT NERC region annual C02 coal output emission rate Ib/MWh 55 NR0C02RT NERC region annual C02 oil output emission rate Ib/MWh 56 NRGC02RT NERC region annual C02 gas output emission rate Ib/MWh 57 NRFSC2RT NERC region annual C02 fossil fuel output emission rate Ib/MWh 58 NRCCH4RT NERC region annual CH4 coal output emission rate Ib/MWh 59 NR0CH4RT NERC region annual CH4 oil output emission rate Ib/MWh 60 NRGCH4RT NERC region annual CH4 gas output emission rate Ib/MWh 61 NRFCH4RT NERC region annual CH4 fossil fuel output emission rate Ib/MWh 62 NRCN20RT NERC region annual N20 coal output emission rate Ib/MWh 63 NR0N20RT NERC region annual N20 oil output emission rate Ib/MWh 64 NRGN20RT NERC region annual N20 gas output emission rate Ib/MWh 65 NRFN20RT NERC region annual N20 fossil fuel output emission rate Ib/MWh 66 NRCC2ERT NERC region annual C02 equivalent coal output emission rate Ib/MWh 67 NR0C2ERT NERC region annual C02 equivalent oil output emission rate Ib/MWh 68 NRGC2ERT NERC region annual C02 equivalent gas output emission rate Ib/MWh 69 NRFSC2ERT NERC region annual C02 equivalent fossil fuel output emission rate Ib/MWh 70 NRCHGRT NERC region annual Hg coal output emission rate Ib/MWh 71 NRFSHGRT NERC region annual Hg fossil fuel output emission rate Ib/MWh 72 NRCNOXR NERC region annual NOx coal input emission rate Ib/MMBtu 73 NRONOXR NERC region annual NOx oil input emission rate Ib/MMBtu 74 NRGNOXR NERC region annual NOx gas input emission rate Ib/MMBtu 75 NRFSNXR NERC region annual NOx fossil fuel input emission rate Ib/MMBtu 76 NRCNXOR NERC region ozone season NOx coal input emission rate Ib/MMBtu 77 NRONXOR NERC region ozone season NOx oil input emission rate Ib/MMBtu 78 NRGNXOR NERC region ozone season NOx gas input emission rate Ib/MMBtu 79 NRFSNOR NERC region ozone season NOx fossil fuel input emission rate Ib/MMBtu 80 NRCS02R NERC region annual S02 coal input emission rate Ib/MMBtu 81 NROS02R NERC region annual S02 oil input emission rate Ib/MMBtu 82 NRGS02R NERC region annual S02 gas input emission rate Ib/MMBtu 83 NRFSS2R NERC region annual S02 fossil fuel input emission rate Ib/MMBtu 84 NRCC02R NERC region annual C02 coal input emission rate Ib/MMBtu 85 NROC02R NERC region annual C02 oil input emission rate Ib/MMBtu 86 NRGC02R NERC region annual C02 gas input emission rate Ib/MMBtu 87 NRCCH4R NERC region annual CH4 coal input emission rate Ib/MMBtu 88 NROCH4R NERC region annual CH4 oil input emission rate Ib/MMBtu 89 NRGCH4R NERC region annual CH4 gas input emission rate Ib/MMBtu 90 NRFCH4R NERC region annual CH4 fossil fuel input emission rate Ib/MMBtu 91 NRCN20R NERC region annual N20 coal input emission rate Ib/MMBtu 92 NRON20R NERC region annual N20 oil input emission rate Ib/MMBtu 93 NRGN20R NERC region annual N20 gas input emission rate Ib/MMBtu 94 NRFN20R NERC region annual N20 fossil fuel input emission rate Ib/MMBtu 95 NRCC2ER NERC region annual C02 equivalent coal input emission rate Ib/MMBtu 96 NROC2ER NERC region annual C02 equivalent oil input emission rate Ib/MMBtu 97 NRGC2ER NERC region annual C02 equivalent gas input emission rate Ib/MMBtu 98 NRFSC2ER NERC region annual C02 equivalent fossil fuel input emission rate Ib/MMBtu 99 NRFSC2R NERC region annual C02 fossil fuel input emission rate Ib/MMBtu 100 NRCHGR NERC region annual Hg coal input emission rate Ib/MMBtu 101 NRFSHGR NERC region annual Hg fossil fuel input emission rate Ib/MMBtu 102 NRNBNOX NERC region annual NOx nonbaseload output emission rate Ib/MWh 103 NRNBNXO NERC region ozone season NOx nonbaseload output emission rate Ib/MWh 104 NRNBS02 NERC region annual S02 nonbaseload output emission rate Ib/MWh 105 NRNBC02 NERC region annual C02 nonbaseload output emission rate Ib/MWh 106 NRNBCH4 NERC region annual CH4 nonbaseload output emission rate Ib/MWh Technical Support Document for eGRID2018 I P9-96 ------- Field 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 APPENDIX A Name Description Unit NRNBN20 NERC region annual N20 nonbaseload output emission rate Ib/MWh NRNBC2E NERC region annual C02 equivalent nonbaseload output emission rate Ib/MWh NRNBHG NERC region annual Hg nonbaseload output emission rate Ib/MWh NRGENACL NERC region annua coal net generation MWh NRGENAOL NERC region annua oil net generation MWh NRGENAGS NERC region annua gas net generation MWh NRGENANC NERC region annua nuclear net generation MWh NRGENAHY NERC region annua hydro net generation MWh NRGENABM NERC region annua biomass net generation MWh NRGENAWI NERC region annua wind net generation MWh NRGENASO NERC region annua solar net generation MWh NRGENAGT NERC region annua geothermal net generation MWh NRGENAOF NERC region annua other fossil net generation MWh NRGENAOP NERC region annua other unknown/purchased fuel net generation MWh NRGENATN NERC region annua total nonrenewables net generation MWh NRGENATR NERC region annua total renewables net generation MWh NRGENATH NERC region annua total nonhydro renewables net generation MWh NRGENACY NERC region annua total combustion net generation MWh NRGENACN NERC region annual total noncombustion net generation MWh NRCLPR NERC region coal generation percent (resource mix) % NROLPR NERC region oil generation percent (resource mix) % NRGSPR NERC region gas generation percent (resource mix) % NRNCPR NERC region nuclear generation percent (resource mix) % NRHYPR NERC region hydro generation percent (resource mix) % NRBMPR NERC region biomass generation percent (resource mix) % NRWIPR NERC region wind generation percent (resource mix) % NRSOPR NERC region solar generation percent (resource mix) % NRGTPR NERC region geothermal generation percent (resource mix) % NROFPR NERC region other fossil generation percent (resource mix) % NROPPR NERC region other unknown/purchased fuel generation percent (resource mix) % NRTNPR NERC region total nonrenewables generation percent (resource mix) % NRTRPR NERC region total renewables generation percent (resource mix) % NRTHPR NERC region total nonhydro renewables generation percent (resource mix) % NRCYPR NERC region total combustion generation percent (resource mix) % NRCNPR NERC region total noncombustion generation percent (resource mix) % NRNBGNCL NERC region annual total nonbaseload coal generation MWh NRNBGNOL NERC region annual total nonbaseload oil generation MWh NRNBGNGS NERC region annual total nonbaseload gas generation MWh NRNBGNNC NERC region annual total nonbaseload nuclear generation MWh NRNBGNHY NERC region annual total nonbaseload hydro generation MWh NRNBGNBM NERC region annual total nonbaseload biomass generation MWh NRNBGNWI NERC region annual total nonbaseload wind generation MWh NRNBGNSO NERC region annual total nonbaseload solar generation MWh NRNBGNGT NERC region annual total nonbaseload geothermal generation MWh NRNBGNOF NERC region annual total nonbaseload other fossil generation MWh NRNBGNOP NERC region annual total nonbaseload other unknown/purchased fuel generation MWh NRNBCLPR NERC region nonbaseload coal generation percent (resource mix) % NRNBOLPR NERC region nonbaseload oil generation percent (resource mix) % NRNBGSPR NERC region nonbaseload gas generation percent (resource mix) % NRNBNCPR NERC region nonbaseload nuclear generation percent (resource mix) % NRNBHYPR NERC region nonbaseload hydro generation percent (resource mix) % NRNBBMPR NERC region nonbaseload biomass generation percent (resource mix) % NRNBWIPR NERC region nonbaseload wind generation percent (resource mix) % NRNBSOPR NERC region nonbaseload solar generation percent (resource mix) % Technical Support Document for eGRID2018 I pg-97 ------- APPENDIX A Field Name Description Unit 161 NRNBGTPR NERC region nonbaseload geothermal generation percent (resource mix) % 162 NRNBOFPR NERC region nonbaseload other fossil generation percent (resource mix) % 163 NRNBOPPR NERC region nonbaseload other unknown/purchased fuel generation percent (resource mix) % "cc 1 lical Support Document c<,>K D2018 | pg, 98 ------- Field 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 APPENDIX A Table A-8. eGRID File Structure, eGRID2018 U.S. File, United States File Name Description YEAR Data year NAMEPCAP U.S. nameplate capacity USHTIAN U.S. annual heat input from combustion USHTIOZ U.S. ozone season heat input from combustion USHTIANT U.S. total annual heat input USHTIOZT U.S. total ozone season heat input USNGENAN U.S. annual net generation USNGENOZ U.S. ozone season net generation USNOXAN U.S. annual NOx emissions USNOXOZ U.S. ozone season NOx emissions USS02AN U.S. annual S02 emissions USC02AN U.S. annual C02emissions USCH4AN U.S. annual CH4 emissions USN20AN U.S. annual N20 emissions USC02EQA U.S. annual C02 equivalent emissions USHGAN U.S. annual Hg emissions USNOXRTA U.S. annual NOx total output emission rate USNOXRTO U.S. ozone season NOx total output emission rate USS02RTA U.S. annual S02 total output emission rate USC02RTA U.S. annual C02 total output emission rate USCH4RTA U.S. annual CH4 total output emission rate USN20RTA U.S. annual N20 total output emission rate USC2ERTA U.S. annual C02 equivalent total output emission rate USHGRTA U.S. annual Hg total output emission rate USNOXRA U.S. annual NOx input emission rate USNOXRO U.S. ozone season NOx input emission rate USS02RA U.S. annual S02 input emission rate USC02RA U.S. annual C02 input emission rate USCH4RA U.S. annual CH4 input emission rate USN20RA U.S. annual N20 input emission rate USC2ERA U.S. annual C02 equivalent input emission rate USHGRA U.S. annual Hg input emission rate USNOXCRT U.S. annual NOx combustion output emission rate USNOXCRO U.S. ozone season NOx combustion output emission rate USS02CRT U.S. annual S02 combustion output emission rate USC02CRT U.S. annual C02combustion output emission rate USCH4CRT U.S. annual CH4 combustion output emission rate USN20CRT U.S. annual N20 combustion output emission rate USHGCRT U.S. annual Hg combustion output emission rate USCNOXRT U.S. annual NOx coal output emission rate USONOXRT U.S. annual NOx oil output emission rate USGNOXRT U.S. annual NOx gas output emission rate USFSNXRT U.S. annual NOx fossil fuel output emission rate USCNXORT U.S. ozone season NOx coal output emission rate USONXORT U.S. ozone season NOx oil output emission rate USGNXORT U.S. ozone season NOx gas output emission rate USFSNORT U.S. ozone season NOx fossil fuel output emission rate USCS02RT U.S. annual S02 coal output emission rate USOS02RT U.S. annual S02 oil output emission rate USGS02RT U.S. annual S02 gas output emission rate USFSS2RT U.S. annual S02 fossil fuel output emission rate | 99 Technical Support Document for eGR!D2018 ------- APPENDIX A Field Name Description Unit 52 USCC02RT U.S. annual C02 coal output emission rate Ib/MWh 53 US0C02RT U.S. annual C02 oil output emission rate Ib/MWh 54 USGC02RT U.S. annual C02 gas output emission rate Ib/MWh 55 USFSC2RT U.S. annual C02 fossil fuel output emission rate Ib/MWh 56 USCCH4RT U.S. annual CH4 coal output emission rate Ib/MWh 57 US0CH4RT U.S. annual CH4 oil output emission rate Ib/MWh 58 USGCH4RT U. S. annual CH4 gas output emission rate Ib/MWh 59 USFCH4RT U.S. annual CH4 fossil fuel output emission rate Ib/MWh 60 USCN20RT U.S. annual N20 coal output emission rate Ib/MWh 61 US0N20RT U.S. annual N20 oil output emission rate Ib/MWh 62 USGN20RT U.S. annual N20 gas output emission rate Ib/MWh 63 USFN20RT U.S. annual N20 fossil fuel output emission rate Ib/MWh 64 USCC2ERT U.S. annual C02 equivalent coal output emission rate Ib/MWh 65 US0C2ERT U.S. annual C02 equivalent oil output emission rate Ib/MWh 66 USGC2ERT U.S. annual C02 equivalent gas output emission rate Ib/MWh 67 USFSC2ERT U.S. annual C02 equivalent fossil fuel output emission rate Ib/MWh 68 USCHGRT U.S. annual Hg coal output emission rate Ib/MWh 69 USFSHGRT U.S. annual Hg fossil fuel output emission rate Ib/MWh 70 USCNOXR U.S. annual NOx coal input emission rate Ib/MMBtu 71 USONOXR U.S. annual NOx oil input emission rate Ib/MMBtu 72 USGNOXR U.S. annual NOx gas input emission rate Ib/MMBtu 73 USFSNXR U.S. annual NOx fossil fuel input emission rate Ib/MMBtu 74 USCNXOR U.S. ozone season NOx coal input emission rate Ib/MMBtu 75 USONXOR U.S. ozone season NOx oil input emission rate Ib/MMBtu 76 USGNXOR U.S. ozone season NOx gas input emission rate Ib/MMBtu 77 USFSNOR U.S. ozone season NOx fossil fuel input emission rate Ib/MMBtu 78 USCS02R U.S. annual S02 coal input emission rate Ib/MMBtu 79 USOS02R U.S. annual S02 oil input emission rate Ib/MMBtu 80 USGS02R U.S. annual S02 gas input emission rate Ib/MMBtu 81 USFSS2R U.S. annual S02 fossil fuel input emission rate Ib/MMBtu 82 USCC02R U.S. annual C02 coal input emission rate Ib/MMBtu 83 USOC02R U.S. annual C02 oil input emission rate Ib/MMBtu 84 USGC02R U.S. annual C02 gas input emission rate Ib/MMBtu 85 USFSC2R U.S. annual C02 fossil fuel input emission rate Ib/MMBtu 86 USCCH4R U.S. annual CH4 coal input emission rate Ib/MMBtu 87 USOCH4R U.S. annual CH4 oil input emission rate Ib/MMBtu 88 USGCH4R U.S. annual CH4 gas input emission rate Ib/MMBtu 89 USFCH4R U.S. annual CH4 fossil fuel input emission rate Ib/MMBtu 90 USCN20R U.S. annual N20 coal input emission rate Ib/MMBtu 91 USON20R U.S. annual N20 oil input emission rate Ib/MMBtu 92 USGN20R U.S. annual N20 gas input emission rate Ib/MMBtu 93 USFN20R U.S. annual N20 fossil fuel input emission rate Ib/MMBtu 94 USCC2ER U.S. annual C02 equivalent coal input emission rate Ib/MMBtu 95 USOC2ER U.S. annual C02 equivalent oil input emission rate Ib/MMBtu 96 USGC2ER U.S. annual C02 equivalent gas input emission rate Ib/MMBtu 97 USFSC2ER U.S. annual C02 equivalent fossil fuel input emission rate Ib/MMBtu 98 USCHGR U.S. annual Hg coal input emission rate Ib/MMBtu 99 USFSHGR U.S. annual Hg fossil fuel input emission rate Ib/MMBtu 100 USNBNOX U.S. annual NOx nonbaseload output emission rate Ib/MWh 101 USNBNXO U.S. ozone season NOx nonbaseload output emission rate Ib/MWh 102 USNBS02 U.S. annual S02 nonbaseload output emission rate Ib/MWh 103 USNBC02 U.S. annual C02 nonbaseload output emission rate Ib/MWh Technical Support Document for eGRID2018 | pg.100 ------- APPENDIX A Field Name Description Unit 104 USNBCH4 U.S. annual CH4 nonbaseload output emission rate Ib/MWh 105 USNBN20 U.S. annual N20 nonbaseload output emission rate Ib/MWh 106 USNBC2E U.S. annual C02 equivalent nonbaseload output emission rate Ib/MWh 107 USNBHG U.S. annual Hg nonbaseload output emission rate Ib/MWh 108 USGENACL U.S. annual coal net generation MWh 109 USGENAOL U.S. annual oil net generation MWh 110 USGENAGS U.S. annual gas net generation MWh 111 USGENANC U.S. annual nuclear net generation MWh 112 USGENAHY U.S. annual hydro net generation MWh 113 USGENABM U.S. annual biomass net generation MWh 114 USGENAWI U.S. annual wind net generation MWh 115 USGENASO U.S. annual solar net generation MWh 116 USGENAGT U.S. annual geothermal net generation MWh 117 USGENAOF U.S. annual other fossil net generation MWh 118 USGENAOP U.S. annual other unknown/purchased fuel net generation MWh 119 USGENATN U.S. annual total nonrenewables net generation MWh 120 USGENATR U.S. annual total renewables net generation MWh 121 USGENATH U.S. annual total nonhydro renewables net generation MWh 122 USGENACY U.S. annual total combustion net generation MWh 123 USGENACN U.S. annual total noncombustion net generation MWh 124 USCLPR U.S. coal generation percent (resource mix) % 125 USOLPR U.S. oil generation percent (resource mix) % 126 USGSPR U.S. gas generation percent (resource mix) % 127 USNCPR U.S. nuclear generation percent (resource mix) % 128 USHYPR U.S. hydro generation percent (resource mix) % 129 USBMPR U.S. biomass generation percent (resource mix) % 130 USWIPR U.S. wind generation percent (resource mix) % 131 USSOPR U.S. solar generation percent (resource mix) % 132 USGTPR U.S. geothermal generation percent (resource mix) % 133 USOFPR U.S. other fossil generation percent (resource mix) % 134 USOPPR U.S. other unknown/purchased fuel generation percent (resource mix) % 135 USTNPR U.S. total nonrenewables generation percent (resource mix) % 136 USTRPR U.S. total renewables generation percent (resource mix) % 137 USTHPR U.S. total nonhydro renewables generation percent (resource mix) % 138 USCYPR U.S. total combustion generation percent (resource mix) % 139 USCNPR U.S. total noncombustion generation percent (resource mix) % 140 USNBGNCL U. S. annual total nonbaseload coal generation MWh 141 USNBGNOL U.S. annual total nonbaseload oil generation MWh 142 USNBGNGS U.S. annual total nonbaseload gas generation MWh 143 USNBGNNC U.S. annual total nonbaseload nuclear generation MWh 144 USNBGNHY U.S. annual total nonbaseload hydro generation MWh 145 USNBGNBM U.S. annual total nonbaseload biomass generation MWh 146 USNBGNWI U.S. annual total nonbaseload wind generation MWh 147 USNBGNSO U. S. annual total nonbaseload solar generation MWh 148 USNBGNGT U.S. annual total nonbaseload geothermal generation MWh 149 USNBGNOF U.S. annual total nonbaseload other fossil generation MWh 150 USNBGNOP U. S. annual total nonbaseload other unknown/purchased fuel generation MWh 151 USNBCLPR U.S. nonbaseload coal generation percent (resource mix) % 152 USNBOLPR U.S. nonbaseload oil generation percent (resource mix) % 153 USNBGSPR U.S. nonbaseload gas generation percent (resource mix) % 154 USNBNCPR U.S. nonbaseload nuclear generation percent (resource mix) % 155 USNBHYPR U.S. nonbaseload hydro generation percent (resource mix) % Technical Support Document for eGR!D2018 1 .x. 10? ------- APPENDIX A Field Name Description Unit 156 USNBBMPR U.S. nonbaseloadbiomass generation percent (resource mix) % 157 USNBWIPR U.S. nonbaseload wind generation percent (resource mix) % 158 USNBSOPR U.S. nonbaseload solar generation percent (resource mix) % 159 USNBGTPR U.S. nonbaseload geothermal generation percent (resource mix) % 160 USNBOFPR U.S. nonbaseload other fossil generation percent (resource mix) % 161 USNBOPPR U.S. nonbaseload other unknown/purchased fuel generation percent (resource mix) % Technical Support Document for eGR!D2018 1 .x. 102 ------- APPENDIX A Table A-9. eGRID File Structure, eGRID2018 GGL File, Grid Gross Loss (%) File Field Name Description Unit Source(s) 1 YEAR Data year 2 REGION One of the three interconnect power grids in the U.S. (plus Alaska, Hawaii, and the entire U.S.) 3 ESTLOSS The total amount of electricity in the region that is generated but is not sold for resale or wholesale, furnished without charge, or used by the generator or utility MWh EIA State Electricity Profiles, Supply and disposition of electricity, 1990-2018 4 TOTDISP The total amount of electricity in the region that is sold directly to customers, sold for resale, furnished without charge, consumed by the respondent without charge, and lost, without exports included MWh EIA State Electricity Profiles, Supply and disposition of electricity, 1990-2018 5 DIRCTUSE The total amount of electricity used by plants and/or utilities in the region that is not sold for wholesale or resale; direct use electricity is not transmitted through the grid and therefore does not have the potential to be lost MWh EIA State Electricity Profiles, Supply and disposition of electricity, 1990-2018 6 GGRSLOSS The estimated regional grid gross loss as a percent [Estimated losses/(Total disposition - Direct use)]*100 % Technical Support Document for eGR!D2018 1 .x. 103 ------- APPENDIX B Appendix B. eGRID Subregion and NERC Region Representational Maps Figure B-1. eGRID Subregion Representational Map NEWE MROE NWPP NYUP MROW, RFCM "NYLI IYCW RFCW CAMX s-J SPNO SRMW SRTV SRVC SRMVV. (V/> ! 5 ¦*$ ^ J mLP SRSO AZNM FRCC AKMS -o* HIOA CS. HIMS USEPA, eGRID: Februaty 2018 Crosshatching indicates that an area falls within overlapping eGRID subregions due to the presence of multiple electric service providers. Visit Power Profiler to definitively determine the eGRID subregion associated with your location and electric sen/ice provider, http :ifwww. e p a. go v/e n ergy/p owe r-profiler This is a representational map; many of the boundaries shown on this map are approximate because they are based on companies, not on strict geographical boundaries. Technical Support Document for eGRID2018 1 pg.104 ------- APPENDIX B Figure B-2. NERC Region Representational Map WECC This is a representational map; many of the boundaries shown on this map are approximate because they are based on companies, not on strict geographical boundaries. Technical Support Document for eGRID2018 1 P9-105 ------- APPENDIX C Appendix C. Crosswalks and Additional Data Tables This Appendix contains reference tables used in the development of eGRID2018. These include: Emission factors used to estimate emissions (where they are not available from EPA/CAMD); Biomass fuels used in the plant file biomass emissions adjustment; A crosswalk of plant ORISPL IDs that are different between EPA/CAMD and EIA datasets; Geothermal emission factors by geotype and pollutant; and English to Metric conversion factors. Emission Factors - NOx, CO2, SO2, Cm, and N2O For more information regarding the emission factors used and the methodology to estimate emissions, please see Section 3.1. Emission factors that have changed in eGRID2018 are represented in bold in the table. Table C-1. eGRID Emission Factors for CO2, CH4, and N2O Fuel Type EIA Fuel Type Code CO2 EF (ton C02/mmBtu) CH4 EF (lb ChU/mmBtu) N2O EF (lb N20/mmBtu) Source Agricultural Byproducts AB 0.13026 0.07055 0.00926 (EPA, 2009) Anthracite ANT 0.11413 0.02425 0.00353 (EPA, 2009) Blast Furnace Gas BFG 0.30239 0.00005 0.00022 (EPA, 2009) Bituminous BIT 0.10296 0.02425 0.00353 (EPA, 2009) Sulphite lyes (Black Liquor) BLQ 0.11083 0.00698 0.00465 (IPCC, 2007a) Coke Oven Gas COG 0.05164 0.00106 0.00022 (EPA, 2009) Distillate Fuel Oil (avg) DFO 0.08166 0.00661 0.00132 (EPA, 2009) Hydrogen H 0.00000 0.00000 0.00000 No EF Kerosene- Type Jet Fuel JF 0.07961 0.00661 0.00132 (EPA, 2009) Kerosene KER 0.08289 0.00661 0.00132 (EPA, 2009) Landfill Gas LFG 0.06350 0.00233 0.00023 (IPCC, 2007a) Lignite LIG 0.10622 0.02425 0.00353 (EPA, 2009) Municipal Solid Waste (Biomass) MSB 0.09998 0.07055 0.00926 (EPA, 2009) Municipal Solid Waste (Non-Biomass) MSN 0.09998 0.07055 0.00926 (EPA, 2009) Municipal Solid Waste (Biomass) MSW 0.09998 0.07055 0.00926 (EPA, 2009) Technical Support Document for eGRID2018 | pg.106 ------- APPENDIX C Fuel Type EIA Fuel Type Code C02 EF (ton CCVmmBtu) CH4 EF (lb ChU/mmBtu) N2O EF (lb N20/mmBtu) Source Megawatt hours MWH 0.00000 0.00000 0.00000 No EF Pipeline (Weighted U.S. Average) NG 0.05844 0.00220 0.00022 (EPA, 2009) Nuclear NUC 0.00000 0.00000 0.00000 No EF Other Biogas OBG 0.06350 0.00233 0.00023 (IPCC, 2007a) Other Liquid Biofuels OBL 0.09257 0.00698 0.00140 (IPCC, 2007a) Other Primary Solid Biomass OBS 0.11630 0.06978 0.00930 (IPCC, 2007a) Other Gas OG 0.05844 0.00220 0.00022 Use NG EF Petroleum Coke PC 0.11289 0.00661 0.00132 (EPA, 2009) Propane PG 0.06775 0.00661 0.00132 (EPA, 2009) Process Gas PRG 0.05844 0.00220 0.00022 Use NG EF Purchased Steam PUR 0.00000 0.00000 0.00000 No EF Refined Coal RC 0.10529 0.02425 0.00353 (EPA, 2009) Residual Fuel Oil (avg) RFO 0.08159 0.00661 0.00132 (EPA, 2009) Synthetic Gas - Petroleum Coke SGP 0.05844 0.00220 0.00022 Use NG EF Sludge Waste SLW 0.09257 0.00698 0.00140 Use OBL EF Subbituminous SUB 0.10695 0.02425 0.00353 (EPA, 2009) Solar SUN 0.00000 0.00000 0.00000 No EF Tires TDF 0.09477 0.07055 0.00926 (EPA, 2009) Water WAT 0.00000 0.00000 0.00000 No EF Waste Coal WC 0.10529 0.02425 0.00353 (EPA, 2009) Wood, Wood Waste Liquid WDL 0.09257 0.00698 0.00140 Use OBL EF Wood and Wood Residuals WDS 0.10340 0.07055 0.00926 (EPA, 2009) Waste Heat WH 0.00000 0.00000 0.00000 No EF Wind WND 0.00000 0.00000 0.00000 No EF Waste Oils WO 0.08525 0.06978 0.00930 (IPCC, 2007a) Table C-2. eGRID Emission Factors for Nitrogen Oxides (NOx) Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator ST AB N/A 1.2 lb ton Technical Support Document for eGRID2018 I pg-107 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator ST AB STOKER 1.2 lb ton ST BFG N/A 0.0154 lb mcf ST BFG TANGENTIAL 0.0154 lb mcf ST BFG WALL 0.0154 lb mcf ST BIT CYCLONE 33 lb ton ST BIT DRY CYCLONE 33 lb ton ST BIT DRY FLUIDIZED 5 lb ton ST BIT DRY STOKER 11 lb ton ST BIT DRY TANGENTIAL 10 lb ton ST BIT DRY VERTICAL 12 lb ton ST BIT DRY WALL 12 lb ton ST BIT FLUIDIZED 5 lb ton ST BIT N/A 12 lb ton ST BIT OTHER 12 lb ton ST BIT STOKER 11 lb ton ST BIT TANGENTIAL 10 lb ton ST BIT WALL 12 lb ton ST BIT WET CYCLONE 33 lb ton ST BIT WET FLUIDIZED 5 lb ton ST BIT WET OTHER 31 lb ton ST BIT WET TANGENTIAL 14 lb ton ST BIT WET VERTICAL 31 lb ton ST BIT WET WALL 31 lb ton ST BLQ CYCLONE 1.5 lb ton ST BLQ DRY FLUIDIZED 1.5 lb ton ST BLQ DRY TANGENTIAL 1.5 lb ton ST BLQ DRY WALL 1.5 lb ton ST BLQ FLUIDIZED 1.5 lb ton ST BLQ N/A 1.5 lb ton ST BLQ OTHER 1.5 lb ton ST BLQ TANGENTIAL 1.5 lb ton ST BLQ WALL 1.5 lb ton ST COG CYCLONE 0.0154 lb mcf OT COG N/A 0.0154 lb mcf ST COG N/A 0.0154 lb mcf ST COG WALL 0.0154 lb mcf CT DFO CC 5.124 lb barrels GT DFO CT 5.124 lb barrels Technical Support Document for eGRID2018 | pg.108 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator ST DFO DRY TANGENTIAL 1.008 lb barrels ST DFO DRY WALL 1.008 lb barrels CT DFO N/A 5.124 lb barrels ST DFO N/A 1.008 lb barrels CA DFO N/A 5.124 lb barrels CS DFO N/A 5.124 lb barrels CT DFO N/A 5.124 lb barrels GT DFO N/A 5.124 lb barrels IC DFO N/A 18.6396 lb barrels ST DFO N/A 1.008 lb barrels ST DFO OTHER 1.008 lb barrels ST DFO TANGENTIAL 1.008 lb barrels ST DFO WALL 1.008 lb barrels ST DFO WET TANGENTIAL 1.008 lb barrels GT JF CT 4.9896 lb barrels GT JF N/A 4.9896 lb barrels IC JF N/A 18.144 lb barrels ST JF N/A 1.008 lb barrels GT KER CT 4.9896 lb barrels GT KER N/A 4.9896 lb barrels CA LFG N/A 0.087 lb mcf CS LFG N/A 0.087 lb mcf CT LFG N/A 0.087 lb mcf GT LFG N/A 0.087 lb mcf IC LFG N/A 0.725 lb mcf ST LFG N/A 0.042 lb mcf ST LIG DRY FLUIDIZED 3.6 lb ton ST LIG DRY TANGENTIAL 7.1 lb ton ST LIG DRY WALL 6.3 lb ton ST LIG FLUIDIZED 3.6 lb ton ST LIG N/A 6.3 lb ton ST LIG TANGENTIAL 7.1 lb ton ST LIG WET CYCLONE 15 lb ton ST LIG WET FLUIDIZED 3.6 lb ton ST MSB N/A 5 lb ton ST MSW N/A 5 lb ton ST MSW OTHER 5 lb ton CT NG CC 0.32 lb MMBtu Technical Support Document for eGRID2018 | pg.109 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator CT NG CC 0.328 lb mcf GT NG CT 0.328 lb mcf ST NG CYCLONE 0.28 lb mcf ST NG DRY CYCLONE 0.28 lb mcf CA NG DRYDUCTBURNER 0.328 lb mcf ST NG DRYDUCTBURNER 0.17 lb mcf ST NG DRY STOKER 0.28 lb mcf ST NG DRY TANGENTIAL 0.17 lb mcf ST NG DRY VERTICAL 0.28 lb mcf CA NG DRY WALL 0.328 lb mcf ST NG DRY WALL 0.28 lb mcf CA NG DUCTBURNER 0.328 lb mcf CS NG DUCTBURNER 0.328 lb mcf CT NG DUCTBURNER 0.328 lb mcf ST NG DUCTBURNER 0.17 lb mcf ST NG FLUIDIZED 0.28 lb mcf CT NG N/A 0.328 lb mcf ST NG N/A 0.17 lb mcf CA NG N/A 0.32 lb MMBtu CS NG N/A 0.32 lb MMBtu CT NG N/A 0.32 lb MMBtu GT NG N/A 0.32 lb MMBtu IC NG N/A 2.768 lb mcf ST NG N/A 0.17 lb mcf ST NG OTHER 0.17 lb mcf ST NG STOKER 0.28 lb mcf GT NG TANGENTIAL 0.328 lb mcf ST NG TANGENTIAL 0.17 lb mcf ST NG WALL 0.28 lb mcf ST NG WET CYCLONE 0.28 lb mcf CA OBG N/A 0.3136 lb mcf CS OBG N/A 0.3136 lb mcf CT OBG N/A 0.3136 lb mcf GT OBG N/A 0.3136 lb mcf IC OBG N/A 2.64648 lb mcf ST OBG N/A 0.11283 lb mcf GT OBL N/A 4.7166 lb barrels IC OBL N/A 17.1486 lb barrels Technical Support Document for eGRID2018 | pg.110 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator ST OBS N/A 2 lb ton ST OBS STOKER 2 lb ton GT OG CT 0.26382 lb mcf ST OG CYCLONE 0.15282 lb mcf ST OG DRYDUCTBURNER 0.15282 lb mcf ST OG DRY TANGENTIAL 0.15282 lb mcf ST OG DRY WALL 0.15282 lb mcf CA OG DUCTBURNER 0.15282 lb mcf ST OG DUCTBURNER 0.15282 lb mcf ST OG N/A 0.15282 lb mcf CA OG N/A 0.15282 lb mcf GT OG N/A 0.26382 lb mcf IC OG N/A 2.22641 lb mcf ST OG N/A 0.15282 lb mcf ST OG OTHER 0.15282 lb mcf ST OG TANGENTIAL 0.15282 lb mcf CA OG WALL 0.15282 lb mcf ST OG WALL 0.15282 lb mcf CT OTH CC 0.328 lb mcf GT OTH CT 0.328 lb mcf ST OTH CYCLONE 0.28 lb mcf ST OTH DRY CYCLONE 0.28 lb mcf CA OTH DRYDUCTBURNER 0.328 lb mcf ST OTH DRYDUCTBURNER 0.17 lb mcf ST OTH DRY STOKER 0.28 lb mcf ST OTH DRY TANGENTIAL 0.17 lb mcf ST OTH DRY VERTICAL 0.28 lb mcf CA OTH DRY WALL 0.328 lb mcf ST OTH DRY WALL 0.28 lb mcf CA OTH DUCTBURNER 0.328 lb mcf CS OTH DUCTBURNER 0.328 lb mcf CT OTH DUCTBURNER 0.328 lb mcf ST OTH DUCTBURNER 0.17 lb mcf ST OTH FLUIDIZED 0.28 lb mcf CT OTH N/A 0.328 lb mcf ST OTH N/A 0.17 lb mcf CA OTH N/A 0.328 lb mcf CS OTH N/A 0.328 lb mcf Technical Support Document for eGRID2018 | pg.111 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator CT OTH N/A 0.328 lb mcf GT OTH N/A 0.328 lb mcf IC OTH N/A 2.768 lb mcf OT OTH N/A 0.328 lb mcf ST OTH OTHER 0.17 lb mcf ST OTH STOKER 0.28 lb mcf GT OTH TANGENTIAL 0.328 lb mcf GT OTH TANGENTIAL 0.328 lb mcf ST OTH TANGENTIAL 0.17 lb mcf ST OTH WALL 0.28 lb mcf ST OTH WET CYCLONE 0.28 lb mcf ST PC DRY FLUIDIZED 5 lb ton ST PC DRY WALL 21 lb ton ST PC FLUIDIZED 5 lb ton OT PC N/A 21 lb ton ST PC N/A 21 lb ton CA PC OTHER 21 lb ton ST PC OTHER 21 lb ton ST PC WET WALL 21 lb ton CT PG CC 0.80336 lb mcf GT PG N/A 0.80336 lb mcf ST PG TANGENTIAL 0.52226 lb mcf ST PG WALL 0.52226 lb mcf ST PRG DRY WALL 0.28 lb mcf ST PRG DUCTBURNER 0.17 lb mcf ST PRG N/A 0.17 lb mcf GT PRG N/A 0.17 lb mcf ST PRG N/A 0.17 lb mcf ST PRG OTHER 0.17 lb mcf ST PRG TANGENTIAL 0.17 lb mcf ST PRG WALL 0.28 lb mcf ST RC DRY TANGENTIAL 10 lb ton ST RFO DRY TANGENTIAL 1.344 lb barrels ST RFO DRY WALL 1.974 lb barrels CT RFO N/A 5.5314 lb barrels CA RFO N/A 5.5314 lb barrels CS RFO N/A 5.5314 lb barrels GT RFO N/A 5.5314 lb barrels Technical Support Document for eGRID2018 | pg.112 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator IC RFO N/A 20.118 lb barrels ST RFO N/A 1.974 lb barrels ST RFO TANGENTIAL 1.344 lb barrels ST RFO WALL 1.974 lb barrels ST RFO WET WALL 1.974 lb barrels ST SGC N/A 0.28 lb mcf CA SGP N/A 0.28 lb mcf CS SGP N/A 0.28 lb mcf CT SGP N/A 0.28 lb mcf ST SUB CYCLONE 17 lb ton ST SUB DRY FLUIDIZED 5 lb ton ST SUB DRY TANGENTIAL 7.2 lb ton ST SUB DRY WALL 7.4 lb ton ST SUB FLUIDIZED 5 lb ton ST SUB N/A 5 lb ton ST SUB STOKER 8.8 lb ton ST SUB TANGENTIAL 7.2 lb ton ST SUB WALL ST SUB WET CYCLONE 17 lb ton ST SUB WET FLUIDIZED 5 lb ton ST SUB WET TANGENTIAL 7.2 lb ton ST SUB WET WALL 24 lb ton ST TDF STOKER 11 lb ton ST WC DRY FLUIDIZED 3.6 lb ton ST WC FLUIDIZED 3.6 lb ton ST WC N/A 3.6 lb ton ST WDL N/A 0.22806 lb barrels ST WDS DRY FLUIDIZED 2 lb ton ST WDS DRY STOKER 1.5 lb ton ST WDS DRY TANGENTIAL 2.51 lb ton ST WDS DRY WALL 2.51 lb ton ST WDS FLUIDIZED 2 lb ton OT WDS N/A 2 lb ton ST WDS N/A 2 lb ton OT WDS OTHER 2 lb ton ST WDS OTHER 2 lb ton ST WDS STOKER 1.5 lb ton ST WDS TANGENTIAL 2.51 lb ton Technical Support Document for eGRID2018 | pg.113 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerator Emission Factor Denominator ST WDS WALL 2.51 lb ton ST WDS WET STOKER 1.5 lb ton ST WDS WET TANGENTIAL 2.51 lb ton ST WO DRY WALL 0.798 lb barrels CA WO N/A 3.8724 lb barrels CS WO N/A 3.8724 lb barrels CT WO N/A 3.8724 lb barrels GT WO N/A 3.8724 lb barrels IC WO N/A 14.0784 lb barrels ST WO N/A 0.798 lb barrels Source: AP-42 (EPA, 1995). EIA Electric Power Annual (EIA, 2019e). N/A = not applicable Table C-3. Sulfur dioxide (SO2) emission factors Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r ST AB N/A 0.025 lb MMBtu ST AB STOKER 0.025 lb MMBtu ST BFG N/A 0.0006 lb Mcf ST BFG TANGENTIAL 0.0006 lb Mcf ST BFG WALL 0.0006 lb Mcf ST BIT CYCLONE 38*S lb short tons ST BIT DRY CYCLONE 38*S lb short tons ST BIT DRY FLUIDIZED 38*S lb short tons ST BIT DRY STOKER 38*S lb short tons ST BIT DRY TANGENTIAL 38*S lb short tons ST BIT DRY VERTICAL 38*S lb short tons ST BIT DRY WALL 38*S lb short tons ST BIT FLUIDIZED 38*S lb short tons ST BIT N/A 38*S lb short tons ST BIT OTHER 38*S lb short tons ST BIT OTHER 1.971977*S lb MMBtu ST BIT STOKER 38*S lb short tons ST BIT TANGENTIAL 38*S lb short tons ST BIT WALL 38*S lb short tons ST BIT WALL 1.971977*S lb MMBtu Technical Support Document for eGRID2018 | pg.114 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r ST BIT WET CYCLONE 38*S lb short tons ST BIT WET FLUIDIZED 38*S lb short tons ST BIT WET OTHER 38*S lb short tons ST BIT WET TANGENTIAL 38*S lb short tons ST BIT WET VERTICAL 38*S lb short tons ST BIT WET WALL 38*S lb short tons ST BLQ CYCLONE 7 lb short tons ST BLQ DRY FLUIDIZED 0.7 lb short tons ST BLQ DRY TANGENTIAL 7 lb short tons ST BLQ DRY WALL 7 lb short tons ST BLQ FLUIDIZED 0.7 lb short tons ST BLQ N/A 7 lb short tons ST BLQ OTHER 7 lb short tons ST BLQ TANGENTIAL 7 lb short tons ST BLQ WALL 7 lb short tons ST COG CYCLONE 0.0006 lb Mcf OT COG N/A 0.0006 lb Mcf ST COG N/A 0.0006 lb Mcf ST COG WALL 0.0006 lb Mcf CT DFO CC 1.01*S lb MMBtu GT DFO CT 1.01*S lb MMBtu ST DFO DRY TANGENTIAL 6.3*S lb barrels ST DFO DRY WALL 6.3*S lb barrels CT DFO N/A 1.01*S lb MMBtu ST DFO N/A 5.964*S lb barrels CA DFO N/A 1.01*S lb MMBtu CS DFO N/A 1.01*S lb MMBtu CT DFO N/A 1.01*S lb MMBtu GT DFO N/A 1.01*S lb MMBtu IC DFO N/A 0.29 lb MMBtu ST DFO N/A 5.964*S lb barrels ST DFO OTHER 5.964*S lb barrels ST DFO TANGENTIAL 6.3*S lb barrels ST DFO WALL 6.3*S lb barrels ST DFO WET TANGENTIAL 6.3*S lb barrels GT JF CT 0.003021 lb barrels GT JF N/A 0.003021 lb barrels Technical Support Document for eGRID2018 | pg.115 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r IC JF N/A 0.003021 lb barrels ST JF N/A 0.003021 lb barrels GT KER CT 1.01*S lb MMBtu GT KER N/A 1.01*S lb MMBtu CA LFG N/A 0.045 lb MMBtu CS LFG N/A 0.045 lb MMBtu CT LFG N/A 0.045 lb MMBtu GT LFG N/A 0.045 lb MMBtu IC LFG N/A 0.045 lb MMBtu ST LFG N/A 0.0006 lb MCf ST LIG DRY FLUIDIZED 30*S lb short tons ST LIG DRY TANGENTIAL 30*S lb short tons ST LIG DRY WALL 30*S lb short tons ST LIG FLUIDIZED 10*S lb short tons ST LIG N/A 30*S lb short tons ST LIG TANGENTIAL 30*S lb short tons ST LIG WET CYCLONE 30*S lb short tons ST LIG WET FLUIDIZED 10*S lb short tons ST MSB N/A 1.7 lb short tons ST MSW N/A 1.7 lb short tons ST MSW OTHER 1.7 lb short tons CT NG CC 0.003196 lb MMBtu CT NG CC 0.0006 lb Mcf GT NG CT 0.0006 lb Mcf ST NG CYCLONE 0.0006 lb Mcf ST NG DRY CYCLONE 0.0006 lb Mcf CA NG DRYDUCTBURNER 0.0006 lb Mcf ST NG DRYDUCTBURNER 0.0006 lb Mcf ST NG DRY STOKER 0.0006 lb Mcf ST NG DRY TANGENTIAL 0.0006 lb Mcf ST NG DRY VERTICAL 0.0006 lb Mcf CA NG DRY WALL 0.0006 lb Mcf ST NG DRY WALL 0.0006 lb Mcf CA NG DUCTBURNER 0.0006 lb Mcf CS NG DUCTBURNER 0.0006 lb Mcf CT NG DUCTBURNER 0.0006 lb Mcf ST NG DUCTBURNER 0.0006 lb Mcf Technical Support Document for eGRID2018 | pg.116 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r ST NG FLUIDIZED 0.0006 lb Mcf CT NG N/A 0.0006 lb Mcf ST NG N/A 0.0006 lb Mcf CA NG N/A 0.003196 lb MMBtu CS NG N/A 0.003196 lb MMBtu CT NG N/A 0.003196 lb MMBtu GT NG N/A 0.003196 lb MMBtu IC NG N/A 0.003196 lb MMBtu ST NG N/A 0.003196 lb MMBtu ST NG OTHER 0.0006 lb Mcf ST NG OTHER 0.003196 lb MMBtu ST NG STOKER 0.0006 lb Mcf GT NG TANGENTIAL 0.0006 lb Mcf ST NG TANGENTIAL 0.0006 lb Mcf ST NG WALL 0.003196 lb MMBtu ST NG WALL 0.0006 lb Mcf ST NG WET CYCLONE 0.0006 lb Mcf CA OBG N/A 0.0065 lb MMBtu CS OBG N/A 0.0065 lb MMBtu CT OBG N/A 0.0065 lb MMBtu GT OBG N/A 0.0065 lb MMBtu IC OBG N/A 0.0065 lb MMBtu ST OBG N/A 0.0006 lb MCf GT OBL N/A 0.0065 lb MMBtu IC OBL N/A 0.0065 lb MMBtu ST OBS N/A 0.025 lb MMBtu ST OBS STOKER 0.025 lb MMBtu GT OG CT 0.0006 lb MCf ST OG CYCLONE 0.0006 lb Mcf ST OG DRYDUCTBURNER 0.0006 lb Mcf ST OG DRY TANGENTIAL 0.0006 lb Mcf ST OG DRY WALL 0.0006 lb Mcf CA OG DUCTBURNER 0.0006 lb Mcf ST OG DUCTBURNER 0.0006 lb Mcf ST OG N/A 0.0006 lb Mcf CA OG N/A 0.0006 lb Mcf GT OG N/A 0.0006 lb MCf Technical Support Document for eGRID2018 I P9-117 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r IC OG N/A 0.000588 lb MMBtu ST OG N/A 0.0006 lb Mcf ST OG OTHER 0.0006 lb Mcf ST OG TANGENTIAL 0.0006 lb Mcf CA OG WALL 0.0006 lb Mcf ST OG WALL 0.003196 lb MMBtu ST OG WALL 0.0006 lb Mcf CT OTH CC 0.0006 lb Mcf GT OTH CT 0.0006 lb Mcf ST OTH CYCLONE 0.0006 lb Mcf ST OTH DRY CYCLONE 0.0006 lb Mcf CA OTH DRYDUCTBURNER 0.0006 lb Mcf ST OTH DRYDUCTBURNER 0.0006 lb Mcf ST OTH DRY STOKER 2.8 lb ton ST OTH DRY STOKER 0.0006 lb Mcf ST OTH DRY TANGENTIAL 2.8 lb ton ST OTH DRY TANGENTIAL 0.0006 lb Mcf ST OTH DRY VERTICAL 2.8 lb ton ST OTH DRY VERTICAL 0.0006 lb Mcf CA OTH DRY WALL 2.8 lb ton CA OTH DRY WALL 0.0006 lb Mcf ST OTH DRY WALL 2.8 lb ton ST OTH DRY WALL 0.0006 lb Mcf CA OTH DUCTBURNER 2.8 lb ton CA OTH DUCTBURNER 0.0006 lb Mcf CS OTH DUCTBURNER 2.8 lb ton CS OTH DUCTBURNER 0.0006 lb Mcf CT OTH DUCTBURNER 2.8 lb ton CT OTH DUCTBURNER 0.0006 lb Mcf ST OTH DUCTBURNER 2.8 lb ton ST OTH DUCTBURNER 0.0006 lb Mcf ST OTH FLUIDIZED 2.8 lb ton ST OTH FLUIDIZED 0.0006 lb Mcf CT OTH N/A 2.8 lb ton CT OTH N/A 0.0006 lb Mcf ST OTH N/A 2.8 lb ton ST OTH N/A 0.0006 lb Mcf Technical Support Document for eGRID2018 | pg.118 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r CA OTH N/A 2.8 lb ton CA OTH N/A 0.0006 lb Mcf CS OTH N/A 2.8 lb ton CS OTH N/A 0.0006 lb Mcf GT OTH N/A 2.8 lb ton GT OTH N/A 0.0006 lb Mcf IC OTH N/A 2.8 lb ton IC OTH N/A 0.0006 lb Mcf OT OTH N/A 2.8 lb ton OT OTH N/A 0.0006 lb Mcf ST OTH OTHER 2.8 lb ton ST OTH OTHER 0.0006 lb Mcf ST OTH STOKER 2.8 lb ton ST OTH STOKER 0.0006 lb Mcf GT OTH TANGENTIAL 2.8 lb ton GT OTH TANGENTIAL 0.0006 lb Mcf ST OTH TANGENTIAL 2.8 lb ton ST OTH TANGENTIAL 0.0006 lb Mcf ST OTH WALL 2.8 lb ton ST OTH WALL 0.0006 lb Mcf ST OTH WET CYCLONE 2.8 lb ton ST OTH WET CYCLONE 0.0006 lb Mcf ST PC DRY FLUIDIZED 0.362*S lb MMBtu ST PC DRY WALL 0.362*S lb MMBtu ST PC FLUIDIZED 0.362*S lb MMBtu OT PC N/A 0.362*S lb MMBtu ST PC N/A 0.362*S lb MMBtu CA PC OTHER 0.362*S lb MMBtu ST PC OTHER 0.362*S lb MMBtu ST PC WET WALL 0.362*S lb MMBtu CT PG CC 0.0006 lb MCf GT PG N/A 0.0006 lb MCf ST PG TANGENTIAL 0.0006 lb MCf ST PG WALL 0.0006 lb MCf ST PRG DRY WALL 0.0006 lb Mcf ST PRG DUCTBURNER 0.0006 lb Mcf ST PRG N/A 0.0006 lb Mcf Technical Support Document for eGRID2018 | pg.119 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r GT PRG N/A 0.0006 lb Mcf ST PRG N/A 0.0006 lb Mcf ST PRG OTHER 0.0006 lb Mcf ST PRG TANGENTIAL 0.0006 lb Mcf ST PRG WALL 0.003196 lb MMBtu ST PRG WALL 0.0006 lb Mcf ST RC DRY TANGENTIAL 38*S lb short tons ST RFO DRY TANGENTIAL 6.594*S lb barrels ST RFO DRY WALL 6.594*S lb barrels CT RFO N/A 1.01*S lb MMBtu CA RFO N/A 1.01*S lb MMBtu CS RFO N/A 1.01*S lb MMBtu GT RFO N/A 1.01*S lb MMBtu IC RFO N/A 0.29 lb MMBtu ST RFO N/A 6.594*S lb barrels ST RFO TANGENTIAL 6.594*S lb barrels ST RFO WALL 6.594*S lb barrels ST RFO WET WALL 6.594*S lb barrels ST SGC N/A 38*S lb short tons CA SGP N/A 0.362*S lb MMBtu CS SGP N/A 0.362*S lb MMBtu CT SGP N/A 0.362*S lb MMBtu SLW 2.8 lb ton ST SUB CYCLONE 35*S lb short tons ST SUB DRY FLUIDIZED 35*S lb short tons ST SUB DRY TANGENTIAL 35*S lb short tons ST SUB DRY WALL 35*S lb short tons ST SUB FLUIDIZED 35*S lb short tons ST SUB N/A 35*S lb short tons ST SUB STOKER 35*S lb short tons ST SUB TANGENTIAL 35*S lb short tons ST SUB WALL 35*S lb short tons ST SUB WET CYCLONE 35*S lb short tons ST SUB WET FLUIDIZED 35*S lb short tons ST SUB WET TANGENTIAL 35*S lb short tons ST SUB WET WALL 35*S lb short tons ST TDF STOKER 38*S lb short tons Technical Support Document for eGRID2018 | pg.120 ------- APPENDIX C Prime Mover Primary Fuel Type Boiler Firing Type (if applicable) Emission Factor Emission Factor Numerato r Emission Factor Denominato r ST WC DRY FLUIDIZED 30*S lb short tons ST wc FLUIDIZED 30*S lb short tons ST WC N/A 30*S lb short tons ST WDL N/A 0.025 lb MMBtu ST WDS DRY FLUIDIZED 0.025 lb MMBtu ST WDS DRY STOKER 0.025 lb MMBtu ST WDS DRY TANGENTIAL 0.025 lb MMBtu ST WDS DRY WALL 0.025 lb MMBtu ST WDS FLUIDIZED 0.025 lb MMBtu OT WDS N/A 0.025 lb MMBtu ST WDS N/A 0.025 lb MMBtu OT WDS OTHER 0.025 lb MMBtu ST WDS OTHER 0.025 lb MMBtu ST WDS STOKER 0.025 lb MMBtu ST WDS TANGENTIAL 0.025 lb MMBtu ST WDS WALL 0.025 lb MMBtu ST WDS WET STOKER 0.025 lb MMBtu ST WDS WET TANGENTIAL 0.025 lb MMBtu ST WO DRY WALL 6.174*S lb barrels CA WO N/A 1.01*S lb MMBtu CS WO N/A 1.01*S lb MMBtu CT WO N/A 1.01*S lb MMBtu GT WO N/A 1.01*S lb MMBtu IC WO N/A 0.29 lb MMBtu ST WO N/A 6.174*S lb barrels Source: AP-42 (EPA, 1995). EIA Electric Power Annual (EIA, 2019e). N/A = not applicable S = sulfur content of fuel (%) Biomass fuels used in the Plant file biomass emission adjustments For more information regarding the methodology for biomass adjustments to emissions, please see Section 3.1.2.1. Technical Support Document for eGRID2018 I pg-121 ------- APPENDIX C Table C-4. Fuel types and pollutants included in the Plant file biomass emission adjustments Fuel Type EIA Fuel Type Code C02 NOx ch4 N20 Agricultural Byproducts AB X Sulphite lyes (Black Liquor) BLQ X Digester Gas DG X Landfill Gas LFG X X X X Municipal Solid Waste - biomass component MSB X Other Biogas OBG X Other Liquid Biofuels OBL X Other Primary Solid Biomass OBS X Sludge Waste SLW X Wood, Wood Waste Liquid WDL X Wood and Wood Residuals WDS X Plant ORISPL ID Changes For more information regarding the ORISPL ID changes, please see Section 4.1. Table C-5. Crosswalk of EIA ORISPL ID changes to EPA/CAMD ORISPL IDs EIA ORISPL ID EIA Plant Name EPA/CAM D ORISPL ID EPA/CAMD Plant Name 57901 El Segundo Power 330 El Segundo 57068 GenConn Middletown LLC 562 Middletown 7546 Ponca City 762 Ponca 56565 J Lamar Stall Unit 1416 Arsenal Hill Power Plant 58215 Lee Combined Cycle Plant 2709 H F Lee Steam Electric Plant 58697 L V Sutton Combined Cycle 2713 L V Sutton 7512 Arthur Von Rosenberg 3612 V H Braunig Technical Support Document for eGRID2018 I pg- 122 ------- APPENDIX C 7799 West Marinette 34 4076 West Marinette 7294 Central Energy Plant 7254 Reedy Creek 7268 491 E 48th Street 7258 48th Street Peaking Station 55545 Hidalgo Energy Center 7762 Calpine Hidalgo Energy Center 7709 Dahlberg 7765 Dahlberg (Jackson County) 10397 ArcelorMittal Indiana Harbor West 10474 ArcelorMittal USA - Indiana Harbor East 54995 Indiana Harbor E 5 AC Station 10474 ArcelorMittal USA - Indiana Harbor East 7784 Allegany Cogen 10619 Alleghany Station No. 133 1393 R S Nelson 50030 Nelson Industrial Steam Company 10789 Sabine River Works 55120 SRW Cogen Limited Partnership 59338 Sundevil Power Holdings - Gila River 55306 Gila River Power Station 59784 Gila River Power Block 3 55306 Gila River Power Station 57664 Astoria Energy II 55375 Astoria Energy 58557 Mesquite Generating Station Block 1 55481 Mesquite Generating Station 55874 Panoche Peaker 55508 CalPeak Power - Panoche LLC 54538 Hartwell Energy Facility 70454 Hartwell Energy Facility Geothermal Geotype Table C-6. Geothermal Emission Factors by Geotype and Pollutant Geotype Code Geotype Description NOx EF (Ib/MWh) C02 EF (Ib/MWh) S02 EF (Ib/MWh) F Flash 0 60 0.35 S Steam 0.00104 88.8 0.000215 B Binary 0 0 0 B/F Binary/Flash 0 0 0 English to Metric Conversion Factors Table C-7. Conversion Factors English 2.2046 pound (lb) 1 Kilogram (kg) 0.2778 GJ 1 Megawatt-hour (MWh) Technical Support Document for eGRID2018 I pg- 123 ------- APPENDIX D Appendix D. Information on Prior Editions of eGRID Previous releases of eGRID include the following: eGRID1996 was first released in December 1998. eGRID 1997, with 1996 and 1997 data, was first released in December 1999. eGRID1998, with 1998 data, and with 1996 and 1997 data from eGRID97, was released in March and September 2001. eGRID2000, with preliminary 2000 data, was first released as Version 1.0 in December 2002 and with 1996-2000 data as Version 2.0 in April 2003 and Version 2.01 in May 2003. eGRID2004 Version 1.0, with the year 2004 plant spreadsheet file, was first released in December 2006; Version 2.0, which includes one Excel workbook with an updated plant file, as well as the boiler and generator files for year 2004, was released in early April 2007; and Version 2.1, with the complete set of files - boiler, generator, plant, state, electric generating company (EGC) location (operator)- and owner-based, parent company location (operator)- and owner- based, power control area, eGRID subregion, and North American Electric Reliability Corporation (NERC) region - was released in late April 2007 and updated for typos in May 2007. eGRID2005 Version 1.0 was released in October 2008 and Version 1.1 was released in lanuary 2009, both with two Excel workbooks with year 2005 data (plant and aggregation) and one Excel workbook with years 2004 and 2005 data (ImportExport). eGRID2007 Version 1.0 was released on February 23, 2011 and Version 1.1 was released May 20, 2011, including three Excel workbooks with year 2007 data as well as data for years 2004 and 2005 (the same as those included in eGRID2007). Import-export data for years 2007, 2005, and 2004 are also included. eGRID2009 Version 1.0 with year 2009 data was release on May 10, 2012. This edition also includes year 2007, 2005, and 2004 data from the three previously released editions. Import- export data for years 2009, 2007, 2005, and 2004 are also included. eGRID2010 Version 1.0 with year 2010 data was released on February 24, 2014. This edition also includes year 2009, 2007, 2005, and 2004 data from the three previously released editions. Import-export data for years 2010, 2009, 2007, 2005, and 2004 are also included. eGRID2012 Version 1.0 with year 2012 data was released on October 8, 2015. eGRID2014 Version 1.0 with year 2014 data was released on lanuary 13, 2017 and Version 2.0 was released on February 27, 2017. eGRID2016 Version 1.0 with year 2016 data was released on February 15, 2018. Note that the naming convention for eGRID had been changed since the release of eGRID2012 so that the year noted in the title reflects the data year rather than the release year. Technical Support Document for eGR!D2018 1 .x. 124 ------- |