,^t0 sr^, £ < Tl \ & prO^° T> z UJ o The Emissions & Generation Resource Integrated Database Technical Support Document for the 9th Edition of eGRID with Year 2010 Data Radium Consulting Group Contract #EP-D-08-1Q0 Work Assignment No. 4-23 FINAL February 2014 Prepared for: Clean Air Markets Division Office of Atmospheric Programs U.S. Environmental Protection Agency Washington, DC 20460 Submitted by: Abt Associates 4550 Montgomery Avenue Suite 800 North Bethesda, MD 20814 In Partnership with: Radium Consulting Group 12446 Red Patch Ln Fairfax, VA 22033 ------- Technical Support Document Emissions & Generation Resource Integrated Database eGRID U.S. Environmental Protection Agency Office of Atmospheric Programs Prepared by Abt Associates and Radium Consulting Group 9th Edition of eGRID with Year 2010 Data February 2014 ------- 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. This document is available to the public through the EPA eGRID website at http://www.epa.gov/egrid. Abt Associates TSD for the 9th Edition of eGRID | pg. i ------- ACKNOWLEDGMENTS Acknowledgments This edition of eGRID was developed under the leadership of Mr. Art Diem of EPA's Clean Air Markets Division (CAMD), Dr. Jonathan Dorn and Mr. Hardee Mahoney of Abt Associates Inc., and Ms. Cristina Quiroz of Radium Consulting Group. The eGRID concept was originated by Mr. Rick Morgan, former EPA Senior Energy Analyst in EPA's Office of Atmospheric Programs. The cover graphics were supplied by the National Renewable Energy Laboratory. Abt Associates TSD for the 9th Edition of eGRID | pg. ii ------- CONTENTS Notices i Acknowledgments ii Abbreviations and Acronyms v 1. Introduction 1 2. Summary of eGRID Year 2010 Data 3 2.1 eGRID Files 3 2.2 What's New in eGRID 4 2.3 Uses and Users of eGRID 4 2.4 eGRID Sources 7 3. eGRID Methodology 9 3.1 Estimation of Emissions 9 3.1.1 Unadjusted Emission Estimates for Year 2010 10 3.1.2 Annual Emission Estimates for C02, S02, and NOx 10 3.1.3 Annual Emission Estimates for CH4 and N20 11 3.1.4 Annual Emission Estimates for Mercury (Hg) 12 3.1.5 Ozone Season Emission Estimates for NOx 12 3.1.6 Adjusted Emission Estimates 12 3.1.7 Adjustments for Biomass 13 3.1.8 Adj ustments for CHP 14 3.1.9 Emission Rate Estimates 16 3.2 Treatment of Plant Ownership 22 3.3 Determination of Plant Primary Fuel 23 3.4 Estimation of Resource Mix 24 3.5 Determination of Plant Aggregation Links 25 3.5.1 NERC Region 25 3.5.2 eGRID Subregion 26 3.5.3 Power Control Area 27 3.6 Treatment of Aggregation Levels 35 4. Specific eGRID Identifier Codes, Name Changes and Associations 36 4.1 Plant Level 36 4.2 EGC, Company Level 36 5. Description of Data Elements 38 5.1 The BLR (Boiler) File 38 5.2 The GEN (Generator) File 45 5.3 The PLNT (Plant) File 48 5.4 The ST (State) File 65 5.5 The PCAL (PCA) File 71 5.6 The SRL (eGRID Subregion) File 71 5.7 The NRL (NERC Region) File 71 5.8 The US (U.S.) File 71 5.9 The Regional Grid Gross Loss File 72 6. References 74 Appendix A. eGRID File Structure - Variable Descriptions for 2010 Data Year 78 Appendix B. eGRID Subregion and NERC Region Representational Maps 100 Abt Associates TSD for the 9,h Edition of eGRI ^ | -x. 11 ------- CONTENTS Tables Table 3-1. Comparison of 100-Year GWPs 11 Table 3-2. Municipal Solid Waste MSB and MSF Splits 13 Table 3-3. Floors for Power to Heat Ratio and ELCALLOC 16 Table 3-4. eGRID Subregion Acronym and Names for eGRID 18 Table 3-5. eGRID Year 2010 Grid Gross Loss (%) 19 Table 3-6. Plant Primary Fuel 20 Table 3-7. Plant Primary Fuel Generation Category 24 Table 3-8. NERC Region Acronym and Names for eGRID 26 Table 3-9. PCA - NERC Region Relationship 28 Table 3-10. PCA - MISO - eGRID Subregion - NERC Region Relationship 32 Table A-l. eGRID File Structure, Year 2010 BLR Boiler File* 78 Table A-2. eGRID File Structure, Year 2010 GEN Generator File** 79 Table A-3. eGRID File Structure, Year 2010 PLNT Plant File 80 Table A-4. eGRID File Structure, Year 2010 ST State File 84 Table A-5. eGRID File Structure, Year 2010 PCAL File, Power Control Area (PCA) File 87 Table A-6. eGRID File Structure, Year 2010 SRL File, eGRID Subregion File 90 Table A-7. eGRID File Structure, Year 2010 NRL File, NERC Region File 93 Table A-8. eGRID File Structure, Year 2010 U.S. File, United States File 96 Table A-9. eGRID File Structure, Year 2010 GGL File, Grid Gross Loss (%) File 99 Figures Figure 3-1. Examples of Plant Through NERC Linkages 25 Figure B-l. eGRID Subregion Representational Map 100 Figure B-2. eGRID NERC Region Representational Map 101 Abt Associates TSD for the 9,h Edition of eGRI Iv ------- ABBREVIATIONS AND ACRONYMS Abbreviations and Acronyms 40 CFR Part 75 AB 32 AR4 BACT BBtu Btu CAMD CARMA CHP CH4 C02 C02e DOE DVRPC EF eGRID eGRID96 eGRID97 eGRID2000 eGRID2002 eGRID2006 eGRID2007 eGRID2010 Code of Federal Regulations Title 40 Part 75, which specifies the 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 Best Available Control Technology 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) Abt Associates TSD for the 9th Edition of eGRID | pg. v ------- ABBREVIATIONS AND ACRONYMS eGRID2012 EGC EIA ELCALLOC EPA FERC FIPS GHG GWh GWP Hg ICR ID IPCC IPM ISO kWh LAER lb MISO MMBtu MMcf MSW MW MWC MWh NATCARB NEMS NERC NESCAUM NETL NGO NIST Eighth edition of the Emissions & Generation Resource Integrated Database with year 2009 data (2007, 2005, and 2004 data were also reissued without change) Electric generating company Energy Information Administration Electric allocation factor U.S. Environmental Protection Agency Federal Energy Regulatory Commission Federal Information Processing Standards Greenhouse gas Gigawatt-hour Global warming potential Mercury Information collection request Identifier Intergovernmental Panel on Climate Change Integrated Planning Model (developed by ICF International) Independent System Operator Kilowatt-hour Lowest Achievable Emission Rate Pound Midcontinent Independent System Operator Million Btu Million cubic feet Municipal Solid Waste Megawatt Municipal Waste Combustor Megawatt-hour National Carbon Sequestration Database and Geographic Information System National Energy Modeling System North American Electric Reliability Corporation Northeast States for Coordinated Air Use Management National Energy Technology Laboratory Nongovernmental Organization National Institute of Standards and Technology Abt Associates TSD for the 9,h Edition of eGRI ^ | -x. * vi* ------- ABBREVIATIONS AND ACRONYMS NOx Nitrogen oxides NREL National Renewable Energy Laboratory N20 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 OTR Ozone Transport Region PCA Power control area RACT Reasonably Available Control Technology RECs Renewable Energy Credits RGGI Regional Greenhouse Gas Initiative RTO Regional Transmission Organization SAR Second Assessment Report of the Intergovernmental Panel on Climate Change SAS Statistical Analysis System S02 Sulfur dioxide TAR Third Assessment Report of the Intergovernmental Panel on Climate Change VERSA Voluntary Renewable Set-Aside Account Abt Associates TSD for the 9,h Edition of eGRI ^ | "vM ------- ABBREVIATIONS AND ACRONYMS [This page intentionally left blank.] Abt Associates TSD for the 9,h Edition of eGRI ^ | "viil ------- INTRODUCTION 1. Introduction 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, generation in megawatt-hour (MWh); resource mix (for renewable and nonrenewable generation); mass emissions of carbon dioxide (C02), nitrogen oxides (NOx), sulfur dioxide (S02), methane (CH4), and nitrous oxide (N20); emission rates for C02, NOx, S02, CH4, and N20; heat input; and nameplate capacity. eGRID reports this information on an annual basis (as well as by ozone season for NOx emissions and emission rates, net generation and resource mix, and heat input) at different levels of aggregation (plant, companies, and grid regions of the country). The ninth edition of eGRID released in January 2014 includes one Excel workbook with year 2010 data. The eGRID workbook includes the following data files: boiler, generator, plant, state, power control area, eGRID subregion, NERC region, and U.S. ~ and a ninth file that displays the grid gross loss and the variables that are used in its estimation for year 2010. Previous releases of eGRID include the following: • The first edition, eGRID96, was first released in December 1998. • The second edition, eGRID97, with 1996 and 1997 data, was first released in December 1999. • The third edition, eGRID2000, with 1998 data, and with 1996 and 1997 data from eGRID97, was released in March and September 2001. • The fourth edition, eGRID2002, 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. • The fifth edition, eGRID2006 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. • The sixth edition, eGRID2007 Version 1.0 was released in October 2008 and Version 1.1 was released in January 2009, both with two Excel workbooks with year 2005 data (plant and aggregation) and one Excel workbook with years 2004 and 2005 data (ImportExport). • The seventh edition, eGRID2010 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. Abt Associates TSD for the 9th Edition of eGRID | pg. 1 ------- INTRODUCTION • The eighth edition, eGRID2012 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. eGRIDweb version 1.0, a web-based eGRID user friendly application with years 2005 and 2004 eGRID2007 data, was released on April 27, 2009 by the U.S. EPA. For further information about this application, which allows the user to select, view, print, and download eGRID data, read the eGRIDweb Users Manual (TS|Pechan, 2009) that can be downloaded from the eGRID website or the Help tab on the application, which can be accessed either at http://cfpub.epa.gov/egridweb/index.cfm or through the eGRID website, http://www.epa.gov/egrid. This web-based application supplants an earlier one that was downloaded onto a user's PC and displayed data years 1996-2000 for eGRID2002; see that User's Manual for details (TS|Pechan, 2003). Several papers have been written to clarify issues and respond to questions about eGRID. The following provides details on the most recent papers. • 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 January 2013, "Using eGRID Data For Carbon Footprinting Electricity Purchases," (Diem and Quiroz, 2013) was presented at the Energy Utility 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. Although eGRID is based on more than existing Federal data sources, its development required substantial attention to quality control. Accurate matching of entities from different databases required great care, even where identification codes were available. Inconsistencies between data sources, missing data, and ambiguous data necessitated adjustments to values of individual data elements, especially identification data. In general, however, questionable data have not been altered, except with regard to the relationship of plants to the power grid. This document provides a description of the ninth edition of eGRID with year 2010 data elements in the Excel spreadsheet files for each level of aggregation, as well as the grid gross loss file. Section 2 provides a summary of the database; Section 3 is the Methodology Section and presents the methodology for emissions estimations, including adjustments for biomass and combined heat and power (CHP), among other issues; Section 4 includes discussion of eGRID specific identification codes, name changes and associations; and Section 5 describes the data elements in detail. There is a set of Reference citations in Section 6 and two Appendices - Appendix A, which includes the file structure, and Appendix B, which includes the eGRID subregion and NERC region representational maps (which remain unchanged from the previous edition of eGRID) (NERC, 2012). Abt Associates TSD for the 9,h Edition of eGRI ^ | -x. 2 ------- SUMMARY OF eGRID YEAR 2010 DATA 2. Summary of eGRID Year 2010 Data 2.1 eGRID Files The ninth edition of eGRID with year 2010 data contains electric power data at different levels of aggregation. As the database name implies, the focus of the data files is on two areas: generation and emissions. 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). C02, NOx, and S02 emissions are expressed in tons (short tons, not metric tons) and CH4, and N20 emissions are expressed in pounds. Emission rates are expressed in lb/MWh, lb/MMBtu for C02, NOx, and S02; in lb/GWh for CH4 and N20. 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 3.1.9.3 on p. 18 for how to account for line losses when assigning emission rates to 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. The ninth edition of eGRID includes operational data from the year 2010. Previous editions of eGRID are named with a year reflecting the year for which the industry structure (e.g. company named, mergers and acquisitions) was configured and do not correspond to the data year. The naming convention of previous editions of eGRID caused some confusion, which is why the current edition is not named with a year, but rather the ordinal iteration of the eGRID edition. Previously issued Technical Support Documents corresponding to the edition specify the date to which the industry configuration is set. Only certain eGRID files can be linked from year 2009 to years 2007, 2005, or 2004. The files that can be linked include the NERC region (by NERC acronym), eGRID subregion (by eGRID subregion acronym), state (by postal state abbreviation), plant (by eGRID plant sequence number), and U.S. The eGRID year 2010 plant data are linked to the year 2009 plant data by the inclusion of the plant file's year 2009 plant sequence number (SEQPLT09) year 2010 plant file. The year 2010 plant file also includes the plant sequence number from year 2007, year 2005, and year 2004. Although most plants will match on Office of Regulatory Information Systems PLant (ORISPL) code, there are some exceptions, so it is completely accurate to match plants in eGRID from year to year using the plant sequence numbers provided. The year 2010 data are displayed in one workbook. This workbook includes a Table of Contents; the boiler, generator, plant, state, power control area, eGRID subregion, NERC region, and U.S. files; and the new year 2010 grid gross loss file. The workbook can be downloaded from the EPA eGRID web site, http://www.epa.gov/egrid. along with Summary Tables and this document. The data were originally processed using the Statistical Analysis System (SAS) software. Abt Associates TSD for the 9th Edition of eGRID | pg. 3 ------- SUMMARY OF e(, < n \ The eight data aggregation files for the ninth edition of eGRID with year 2010 data are: • BLR (boiler), with 5,579 year 2010 records; • GEN (generator), with 17,699 year 2010 records; • PLNT (plant), with 5,587 year 2010 records with non-zero generation and/or unadjusted heat input; • ST (state), with 51 year 2010 records; • PCAL (power control area), with 119 year 2010 records in the file; • SRL (eGRID subregion), with 26 eGRID subregion year 2010 records in the file; • NRL (NERC region), with 10 NERC region year 2010 records in the file; and • US, with 1 year 2010 U.S. totals record. The number of variables in each of the eight aggregation files varies, with 34 in BLR, 15 in GEN, 165 in PLNT, 111 in ST, 111 in PCAL, 113 in SRL, 111 in NRL, and 109 in US. The first variable in each file is a unique sequence number for that file. The boiler file is sorted by state postal code abbreviation, plant name, plant code, and boiler ID. The generator file is sorted by state postal code abbreviation, plant name, plant code, and generator ID. The plant file is sorted by state postal code abbreviation, plant name, and plant code. The state file is sorted by state postal code abbreviation, the power control area file is sorted by power control area name, the eGRID subregion file is sorted by eGRID subregion name, and the NERC region file is sorted by NERC region acronym. The year 2010 grid gross loss file is also included as the last tab in the workbook. The file structure for each of the files is included in Appendix A. The file structure also includes a description of the variables and the original data sources. 2.2 What's New in eGRID There are no data file changes in this edition of eGRID. Methodological changes in this edition of eGRID with 2010 data include the following: • The methodology used to derive the non-baseload output rates has changed, and is now calculated from unit-level data, rather than from plant-level data. • Some latitude-longitude coordinates have been updated based on independent research. Methodological changes are detailed in Section 3, the Methodology Section. Previous years of eGRID data (2009, 2007, 2005, 2004, 2000-1996) are unchanged with the release of this edition. Please refer to the corresponding Technical Support Documents issued with previous editions for methodologies specific to those years of data. 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 provides constructive direction to companies who are generally seeking Abt Associates TSD for the 9,h Edition of eGRI ------- SUMMARY OF e(, < n \ 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, by various emission calculation tools and applications, by many academic papers, by many consultants, and 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://i oulebug.com/), uses eGRID data and developed a game to save energy as both a web and free iPhone app. In 2010, Executive Order 13514 was issued, requiring Federal agencies to "measure, report, and reduce their greenhouse gas emissions from direct and indirect activities." The Federal GHG Accounting and Reporting Guidance accompanied this order and recommended using eGRID non- baseload emission rates to estimate the scope 2 emission reductions from renewable energy. 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, the California Climate Action Registry, California's Mandatory GHG emissions reporting program (AB 32) (CARB, 2007), and the Greenhouse Gas Protocol Initiative cite eGRID for use in estimating scope 2 (indirect) GHG emissions from electricity purchases in the United States. 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 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 (UCS, 2012) 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. eGRID data are also used for Galvin Electricity Initiative's Perfect Power Seal of Approval program, whose metrics help consumers to evaluate the performance of the electricity grid (Galvin, 2011). EIA's National Energy Modeling System (NEMS)'s electricity market module supply regions are the Abt Associates TSD for the 9,h Edition of eGRI ^ | -x. 5 ------- SUMMARY OF e(, < n \ eGRID subregions; the map used in their 2013 documentation (Figure 6) uses the eGRID subregion map and subregion colors, changing a few names (EIA, 2013). 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 (VERSA) using eGRID factors (Maryland, 2010); and in 2009, the Delaware Valley Regional Planning Commission (DVRPC) ~ a nine county region in Pennsylvania and New lersey ~ 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 PIM Environmental Information Services' Generation Attribute Tracking System utilize eGRID data. ISO New England uses eGRID rates in developing the 2008 New England Electric Generator Air Emissions Report (http://www.iso- ne.com/genrtion resrcs/reports/emission/2008 emissions report.pdf). 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, the Ozone Transport Commission's (OTC) Emission Workbook, the GHG Protocol Initiative, the Rocky Mountain Institute's Community Energy Finder, Leonardo Academy's "Cleaner and Greener Environmental Program," the National Resource Defense Council's Benchmarking Air Emissions, The Berkeley Institute of the Environment, Cool Climate Carbon Footprint Calculator, the Climate and Air Pollution Planning Assistant, Emission Solution's Carbon Footprint Calculator, and the Clean Air software developed by the International Council for Local Environmental Initiatives, the United States Department of Transportation Federal Transit Administration, the Google PowerMeter, a free energy monitoring to calculate your home's energy consumption online, the National Public Radio - U.S. Electric Grid, the International Code Council, the American Society of Heating, Refrigerating and Air-Conditioning Engineers, the Local Energy Efficiency Policy Calculator released by the American Council for an Energy-Efficient Economy, and the World Resource Institute's Carbon Value Analysis Tool. Additionally, Brighter Planet, with its CMi web service, has developed a model to estimated GHG emissions from electricity use that uses both the eGRID subregion GHG emission factors as well as the grid gross loss data for their estimates (Brighter Planet, 2010). Abt Associates TSD for the 9,h Edition of eGRI ^ | -x. 6 ------- SUMMARY OF e(, < n \ 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 (Carbon Visuals, 2012). The University of California, Berkeley's CoolClimate Carbon Footprint Maps use eGRID data (Jones and Kammen, 2013). 2.4 eGRID Sources eGRID is developed from a variety of data collected by the U.S. Environmental Protection Agency (EPA), and the Energy Information Administration (EIA). Federal data sources include: • EPA, Clean Air Markets (EPA/CAMD) Annual and Ozone Season Emissions data collected under 40 CFR Part 75 (EPA, 2012b); • EPA, Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2011 (EPA, 2013); • EIA, EIA-860: Annual Electric Generator Report (EIA, 2012); • EIA, EIA-861: Annual Electric Power Industry Report (EIA, 201 la); • EIA, EIA-923: Power Plant Operations Report (EIA, 201 lb); • FERC, FERC-714: Annual Electric Balancing Authority Area and Planning Area Report (FERC, 2011); and • An additional source of eGRID data, the North American Electric Reliability Corporation (NERC) [formerly the North American Electric Reliability Council] (NERC, 2013 and 2013b), is quasi-governmental since it was certified by FERC in July 2006 as the "electric reliability organization." Data displayed in eGRID are derived from the above data sources; EPA does not collect data directly from electric generators for eGRID. Inconsistencies between data sources, missing data, and ambiguous data occasionally necessitate adjustments to values of individual data elements. When necessary, EPA substitutes data from secondary sources or default values. EPA also updates grid configuration data. In general, however, data are displayed as reported; this may lead to plant file outliers to which users should be alert. Abt Associates TSD for the 9,h Edition of eGRI ^ | -x. 7 ------- SUMMARY OF e(, < n \ [This page intentionally left blank.] Abt Associates TSD for the 9,h Edition of eGRI ^ | -x. 8 ------- eGRID METHODOLOGY 3. eGRID Methodology This section describes eGRID development methodologies that are not transparent. Some methods used for the ninth edition of eGRID are modified or refined from previous editions of eGRID and are so noted in this section. 3.1 Estimation of Emissions Emissions (C02, NOx, S02, Hg, CH4, and N20) in eGRID are estimated using data from a variety of sources from EPA and EIA (see SOURCEM variable in the eGRID plant file). Carbon dioxide (C02) is a product of fossil fuel combustion and is the primary greenhouse gas (GHG) emitted by human activities that is contributing to global climate change; nitrogen oxides (NOx) is a product of fossil fuel combustion and is a precursor to the formation of ozone, or smog, and also contributes to acid rain and other environmental and human health impacts; sulfur dioxide (S02) is an air pollutant emitted primarily by power plants burning fossil fuels, especially coal, which is a precursor to acid rain and is associated with other environmental and human health impacts; and mercury (Hg) is a toxic heavy metal that is a byproduct of the combustion of fossil fuels, especially coal. Methane (CH4) and nitrous oxide (N20), two other GHGs emitted by electric power generators, are included in eGRID for years 2010, 2009, 2007, and 2005, beginning at the plant level. The emissions data for the three GHGs are used as default factors in a variety of climate protocols (including The Climate Registry, The California Climate Action Registry, California's Mandatory GHG emissions reporting program (AB 32), and EPA's Climate Leaders) for indirect emissions estimation calculations. Although many small units, as well as some nonutilities and cogenerators, are not subject to EPA/CAMD's data reporting, the vast majority of emissions reported in eGRID are from EPA/CAMD data. Sources that report to EPA/CAMD for year 2010 data are generally utility and nonutility steam units with at least 25 MW capacity, nonsteam units - gas turbines, combined cycles, internal combustion engines - that came on-line after 1990, and independent power producers/cogenerators that sell a specific amount of electricity. Plant level emissions in eGRID are built by summing its component parts - which could simply be unit level boilers and/or turbines or a combination of boilers and prime movers representing an aggregation of like generating units. In general, eGRID plant level emissions reflect a combination of monitored and estimated data. Emissions and emission rates in eGRID represent emissions and rates at the point(s) of generation. They do account for losses within the generating plants (net generation). However, 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 boiler file are unadjusted, while both adjusted and unadjusted emissions and heat input are displayed in the plant file. Adjusted emissions and heat input as well as generation are used in calculating plant emission rates and for all aggregation emission values. Abt Associates TSD for the 9th Edition of eGRID | pg. 9 ------- eGRID METHODOLOGY 3.1.1 Unadjusted Emission Estimates for Year 2010 Emissions that are reported and estimated for eGRID are initially unadjusted, including biomass GHG values, and are displayed at the plant (and boiler) level. Adjusted emissions (and heat input) are included in the plant file and all subsequent aggregation files. All emission rates in the plant file and all aggregation files are based on adjusted emissions, net generation, and adjusted heat input. Depending on the source of data and the emissions type, component emissions are adjusted for biomass and then summed to the plant level before making the CHP adjustment specific to eGRID. Both the source(s) of emissions data and adjustment flags are provided in the plant file. 3.1.2 Annual Emission Estimates for C02, S02, and NOx Mass emissions in eGRID are estimated using data from a variety of sources. eGRID's primary source for C02, S02, and NOx data is EPA/CAMD's unit-level emissions data. C02 is a greenhouse gas, while S02 and NOx are not. S02 and NOx are acid rain pollutants and have been regulated under the Clean Air Act Amendments for many years. If EPA/CAMD emissions are not reported, the emissions are generally estimated using fuel consumption - on a boiler-fuel level if the data are in the EIA-923 boiler level, and/or on a prime mover-fuel level if the data are only in the EIA-923 prime mover level file. For estimating C02, the Intergovernmental Panel on Climate Change (IPCC) (IPCC, 2007) GHG methodology using fuel consumption, a fuel-specific carbon coefficient, and the fuel-related fraction of carbon oxidized (beginning with year 2005 data, the IPCC's mandated change to a uniform oxidation fraction of 1 is used for all fossil fuels) is implemented. This method is also used in EPA's Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2011 (EPA, 2013, Annex 2 tables). C02 emission factors (EFs), which are actually carbon coefficients, for year 2010 are obtained from two sources: EPA's Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2011 (EPA, 2013, Annex 2 tables), The Climate Registry's lanuary 6, 2012 EF file (TCR, 2012), both of which use the EF from Table C-l from EPA's Final Mandatory Reporting of Greenhouse Gases Rule (EPA, 2009) as the basis for their EF. If C02 emissions are estimated, whether for EPA/CAMD, EIA-923 boiler, or EIA-923 prime mover data, the emission factor is applied to fuel consumption (usually in MMBtu). For S02, EPA-approved uncontrolled EFs based on EPA's AP-42 EF (EPA, 2012a), sulfur content, and control efficiencies (if available), and fuel use are also used in the estimation of these emissions. The following describes how NOx emissions are estimated for cases in which EPA/CAMD emissions data are not reported or cannot be used. For steam boilers originating from the EIA-923, the controlled annual NOx emission rate and heat input are used. For data originating from the EIA-923 prime mover level, for steam prime movers, fuel use and EPA-approved uncontrolled emissions factors (EPA, 2012a) are used; and for EIA-923 nonsteam prime movers, beginning with year 2004 eGRID data, a better method is used to calculate NOx emissions for combined cycles, turbines, and internal combustion engines. NOx EF are developed based on the prime mover technology, size, and location. The location is important due to the differing stringency of air pollution controls in some areas with severe air quality problems. For larger nonsteam generators, the factors are based on data from the EPA Reasonably Available Control Technology/Best Available Control Technology/Lowest Achievable Emission Rate RACT/BACT/LAER) Clearinghouse (EPA, undated2). The methodology also reviews current RACT requirements for large generating facilities in regions with stringent limits in areas such as the Ozone Transport Region (OTR), California, and Texas. For smaller nonsteam Abt Associates TSD for the 9,h Edition of eGRI ^ | *10 ------- eGRID METHODOLOGY generators (including small combustion turbines, microturbines and reciprocating engines), the methodology draws from several sources including the EPA CHP Partnership Catalogue of CHP (EPA, undated 1) and the DOE Gas-Fired Distributed Energy Resource Technology Characterizations (DOE, 2003). Geothermal emissions, albeit minimal, are estimated for C02, S02, and NOx. While C02 is a gas in the geothermal reservoir, S02 and NOx result from hydrogen sulfide combustion. The three pollutants" EFs, 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 (GEA, 2013, plus updates based on internet research). For a binary or flash/binary geothermal plant, there are no C02, S02, or NOx EFs; for a flash geothermal plant, there are no NOx EF and small C02 and S02 EFs; and for a dry steam geothermal plant, there are small C02, S02, and NOx EFs. If a plant has operating (i.e., reported non-zero net generation) generators with different geothermal types, then the methodology is modified. In this case, appropriate geothermal type EFs must be applied to the prime mover net generation for each of the different geothermal types of the plant generators. 3.1.3 Annual Emission Estimates for CH4 and N20 In addition to C02, electric power plants also emit some CH4, and N20 GHG emissions. CH4 and N20 emissions are reported in pounds and are estimated by multiplying the fuel specific heat input in MMBtu by appropriate EFs from Table C-2 of EPA" s Final Mandatory Reporting of Greenhouse Gases Rule (EPA, 2009). 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; NOx is not a GHG. N20 should not be confused with NOx. Global Warming Potential (GWP) 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, C02, which has a GWP of 1. Traditionally, the 100-year GWPs are used when calculating overall C02 equivalent emissions, which is the sum of the products of each GHG emission value and its GWP. Note: be sure when calculating the C02 equivalent that each of the GHG emission values has the same measurement units (either all in short tons or all in pounds) since in eGRID, C02 emissions are expressed in tons while both CH4 and N20 emissions are expressed in pounds. Additionally, in order to compare emissions across previous data years, the GWP for the second (1996) IPCC assessment (SAR), is used, although there have been subsequent third (2001) (TAR) and fourth (2006) (AR4) assessments. A comparison of the three GWPs for the three electric power GHGs is presented in Table 3-1 (EPA, 2013, Table 1-3). Table 3-1. Comparison of 100-Year GWPs Gas SAR TAR AR4 CM O 0 1 1 1 ch4 21 23 25 n2o 310 296 298 Abt Associates TSD for the 9th Edition of eGRID | pg. 11 ------- eGRID METHODOLOGY Beginning with year 2007 data, the C02 equivalent (C02e) emissions (tons) and total output emission rate (in lb/MWh) is calculated (using the SAR GWP) at the plant and aggregation levels; and beginning with year 2009 data, the C02 equivalent non-baseload output emission rate (in lb/MWh) is also calculated, but only at the eGRID subregion level. 3.1.4 Annual Emission Estimates for Mercury (Hg) No mercury emissions are included for year 2010 data since the previously employed estimation methods are likely to produce an overestimate of the emissions for boilers for which we have original 1999/2002 data. It is likely that air pollution control devices that affect Hg emissions have been installed on some of these boilers, but there are no Federal data available to measure their impact. Similarly, there are no currently available Federal monitored emissions data for Hg, nor any suitable Hg emission factors for estimating mercury emissions for all electric power units. EPA staff examined MATS information collection request (ICR) Hg data (ICR No. 2362.01) for potential use in eGRID. However, EPA staff determined that the data were not suitable for use in eGRID due to the variability of emission rates at each unit and the difficulty in relating the 2010 operating conditions with the different Hg emission rates reported in the ICR data for each unit. EPA may develop a new methodology for the estimation of Hg emissions in a future edition of eGRID. 3.1.5 Ozone Season Emission Estimates for NOx The ozone season is the five-month period from May through September when excessive levels of ozone, or smog, are most likely to form in the atmosphere due to a chemical reaction of nitrogen oxides with other pollutants in the presence of sunlight. EPA/CAMD provides ozone season NOx emissions for many units that do not report annual emissions. Otherwise, for steam boilers and sampled plants with prime movers that report to the EIA-923 and are not covered by EPA/CAMD, monthly fuel quantity is provided so that five-month (May through September) ozone season NOx emissions can be estimated; if the plant prime mover reports only annually to the EIA-923, then ozone season estimates are calculated as the annual estimates multiplied by 5/12. 3.1.6 Adjusted Emission Estimates Emissions reported in eGRID represent emissions from fuel utilized only for electricity generation. Thus, for certain plants, there are two possible cases for which eGRID adjusts the emission estimates: if the plant is a CHP facility; and if components of the plant burn biomass, including biogas (such as landfill, methane, and digester [other biomass] gas). A biomass facility's adjusted emissions displayed in eGRID may be different from that reported in other EPA sources such as EPA/CAMD emissions data. There are two EPA Acid Rain Program (ARP) plants whose plant-prime mover EPA/CAMD emissions and heat input are adjusted to zero in eGRID; the unadjusted values are published for reference purposes. The net generation for two of these plant-prime movers is reported as zero even though positive fuel use is reported to the EIA-923. For 74th Street (ORISPL = 2504), the steam turbine prime mover data (the three unit level EPA reported emissions and heat input) are adjusted to zero, but the gas turbine adjusted emissions and heat input remain positive. A second plant, AES Redondo Beach LLC (ORISPL = 356), has five steam units that report positive emissions to EPA, but research revealed that one unit does not put electricity to the grid; this unit was assigned zero adjusted emissions and heat input. Abt Associates TSD for the 9,h Edition of eGRI ^ | ~12 ------- eGRID METHODOLOGY 3.1.7 Adjustments for Biomass 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 materials - biomass such as wood, paper, and food waste - and "other fossil" materials - fossil-based materials such as plastics and tires. Thus, emissions from the biomass component of solid waste are adjusted exactly as non-biogas biomass emissions are adjusted, while emissions from the fossil component of solid waste are not adjusted. Solid waste is split into the two components in eGRID so that adjustments can be made as needed. EPA's methodology for splitting municipal solid waste (MSW) into the two components includes different splits for the MSW types. The MSW percentages for the MSW biomass component (called MSB) and the MSW fossil component (called MSF) are described in Table 3-2 below (EIA, 2007). The type of MSW is obtained from an EPA data file (EPA, 2002). Table 3-2. Municipal Solid Waste MSB and MSF Splits MSW Type Variable(s) MSB Split (%) MSF Split (%) Mass Burn Heat Input, Generation 52.7% 47.3% Mass Burn Fuel Consumption 65.4% 34.6% Refuse Derived Fuel Heat Input, Generation 52.7% 47.3% Refuse Derived Fuel Fuel Consumption 75.1% 24.9% Unknown Heat Input, Generation 52.7% 47.3% Unknown Fuel Consumption 67.7% 32.3% As with all biomass generation, C02 emissions from the biomass portion of solid waste are adjusted, but emissions from the remaining portion of solid waste are reported based on appropriate EFs. The EFs used don't take in consideration any control devices that may be present because there is no readily available nationwide information. Generation from supplemental fossil fuels co-fired with solid waste is identified if known and reflected in emission rates. This methodology has not changed. However, beginning with the year 2007 data, the biomass portion of solid waste combustion is shown in the unadjusted C02 emissions. A flag in the plant file indicates whether there is any biomass adjustment and the type of adjustment. The possible adjustments for C02, NOx, S02, CH4, and N20 emissions (and heat input) are explained below. 3.1.7.1 C02 Biomass is a fuel derived from organic matter such as wood and paper products, agricultural waste, or methane (e.g., from landfills). eGRID assumes that these materials are subject to the natural carbon cycle and, therefore, do not contribute to global warming. eGRID assigns zero C02 emissions to generation from the combustion of all biomass (including biogas) because these organic materials would otherwise release C02 (or other greenhouse gases) to the atmosphere through decomposition. For those adjusted-for-biomass C02 emissions that are estimated, the biomass components are zeroed out in this edition, just as they have been for previous years of eGRID data. However, beginning with Abt Associates TSD for the 9th Edition of eGRID | pg. 13 ------- eGRID METHODOLOGY year 2009 eGRID data, the C02 emissions from biomass are more comprehensively disclosed in the plant unadjusted emissions. The C02 emissions from biomass can be determined at a plant level by comparing the emissions and the unadjusted emissions at plants that have a biomass adjustment flag. If the CHP adjustment flag is also 1, to determine the biomass emissions, first calculate how much of the adjustment is accounted for from CHP using the electric allocation factor (since the CHP plant adjustment is applied last). For the EPA/CAMD units that for a given prime mover whose matching EIA-923 prime mover burns some biomass fuel, the biomass fuel components' C02 CAMD emissions are adjusted by the same biomass fuel component percentage as reported in the EIA-923; prior to year 2007, these emissions, if CAMD-reported, were only zeroed out if the EPA/CAMD primary fuel was a biomass fuel. Beginning with year 2009 data, the biomass fuel components' C02 CAMD emissions are adjusted to zero by the same biomass fuel component percentage as that in the matching EIA-923 unit-level data (or if necessary, the matching EIA-923 prime mover level data). RMBMFLAG, the biomass flag, is assigned a value of 7100 if there is a biomass adjustment to CAMD C02 emissions. Similarly, the biogas fuel components' C02, CH4, N20, S02, and NOx emissions are adjusted by the same biogas fuel component percentage as that in the matching EIA-923 unit-level data (or if necessary, the matching EIA-923 prime mover level data). RMBMFLAG, the biomass flag, is assigned a value of 71 if there are biogas adjustments for CAMD emissions. 3.1.7.2 NOx, S02, CH4, and N20 NOx, S02, CH4, and N20 emissions from generation powered by biogas (landfill gas and digester gas) are also adjusted in eGRID. Landfill gas and digester gas emissions must be flared in most cases if the gas is not consumed as useful energy. Therefore, eGRID assumes that biogas would have been flared if not used to generate electricity, so that eGRID adjusted emissions are the amount of incremental emissions attributable to utilizing biogas to generate electricity. Thus, emissions from these fuels are adjusted by decreasing the uncontrolled EF (used to estimate the emissions) by the emission factor represented by a typical flare. This methodology has not changed. For NOx, the EPA-approved flare emission factor is assumed to be 40 lb per million cubic feet (MMcf) of methane, 20 lb per MMcf of methane for landfill gas, and 26 lb per MMcf of methane for digester gas, and is subtracted from the respective original EPA-approved uncontrolled EF before being applied. For S02, CH4, and N20, the EFs are assumed to be the same as the flares', so there are no incremental S02, CH4, and N20 emissions attributable to utilizing biogas to generate electricity, and values of zero are assigned. In eGRID, there are no fuel adjustments forNOx, S02, CH4, andN20 emissions for biomass other than biogas. Beginning with year 2009 data, the biogas components' CAMD CH4, N20, S02, and NOx emissions are also adjusted by the same biogas fuel component percentage as that in the matching EIA-923 unit-level data (or if necessary, the matching EIA-923 prime mover level data) for the adjusted CH4, N20, S02, and NOx CAMD emissions. RMBMFLAG, the biomass flag, is assigned a value of 71 if there is a biogas adjustment to CAMD emissions. 3.1.8 Adjustments for CHP CHP 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, converts energy more efficiently than facilities that separately produce Abt Associates TSD for the 9,h Edition of eGRI ^ | *14 ------- eGRID METHODOLOGY heat and electricity. The plants labeled as CHP in eGRID are an EPA designation based on a CHP file developed for DOE (EEA, 2011 updated). A flag in the plant file indicates if a plant is considered a CHP for purposes of eGRID. Since emissions reported in eGRID represent electricity generation only, emissions associated with useful thermal output - the amount of heat produced in a CHP facility that is used for purposes other than making electricity - are excluded from the adjusted emissions (and a plant's emissions data reported in eGRID may be different from that reported in other EPA sources). As in eGRID2010, the unadjusted emissions are shown only in the plant file. eGRID's methodology is designed to share CHP's efficiency gains between electricity and useful thermal output. For CHP facilities in the year 2010 data, eGRID allocates emissions between electricity and thermal output using a plant level electric allocation factor that discounts the value of useful thermal output by 25%. If a plant is a CHP plant and has an electric allocation factor, it is applied to the emissions (and heat input) for the entire plant after any biomass adjustment has been made. Specifically, the adjusted value is the product of the electric allocation factor and the original value. The methodology for estimating an electric allocation factor is as follows: The useful thermal output value for year 2010 data can be calculated from EIA-923 data as 0.8 multiplied by (total heat input minus electricity heat input) MMBtu. 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 in MMBtu is the net generation MWh multiplied by 3.413 and steam heat output MMBtu is 0.75 multiplied by useful thermal output If the useful thermal output is unknown, the electric allocation factor (ELCALLOC) is estimated given specific conditions. But, if there are non-zero values for both annual net generation and annual total heat input, an 8,500 Btu per kilowatt-hour (kWh) median plant nominal heat rate is assumed. Since actual heat rate equals (electric allocation factor multiplied by 1000 multiplied by heat input MMBtu) divided by (net generation MWh), then the electric allocation factor for CHP plants without a given useful thermal output is initially calculated as: ELCALLOC = (8.5 * plant net generation MWh) / (unadjusted plant heat input MMBtu). If, however, the plant's CHP prime mover has been designated steam and the heat rate is less than 22,747 Btu/kWh, then the electric allocation factor for the CHP plant is initially calculated as: ELCALLOC = ((12.68 * plant net generation) / (unadjusted plant heat input)) - 0.17444. For calculated electric allocation factors that fall below a specified minimum, additional adjustments are made as summarized in Table 3-3. Abt Associates TSD for the 9,h Edition of eGRI ^ | *15 ------- eGRID METHODOLOGY Table 3-3. Floors for Power to Heat Ratio and ELCALLOC Type of CHP Prime Mover Minimum ELCALLOC Minimum Power to Heat Ratio Coal or MWC Boilers 0.11765 0.10 All Other Boilers 0.06250 0.05 Gas Turbines 0.30556 0.33 Combined Cycles, IGCC 0.47183 0.67 Internal Combustion Engines 0.40000 0.50 The CHP electric allocation "floors" were derived from an analysis of the theoretical power-to-heat ratio of different CHP technologies and the actual operating characteristics of existing CHP systems. The power-to-heat ratio is largely a function of the CHP prime mover, its efficiency, and the amount and temperature of heat available from the system. In addition, the reported operating characteristics of a large number of CHP facilities as reported in the DOE ORNL CHP database (EEA, 2011) were reviewed. The combination of theoretical and reported characteristics was used to establish the minimum values for the electric allocation factors. This methodology has not changed. 3.1.9 Emission Rate Estimates Both output and input emission rates are calculated for eGRID, beginning with the plant level of aggregation. In addition to emission values, annual and ozone season net generation and heat input values (adjusted heat input values if it is a CHP plant) are required for emission rate calculations. 3.1.9.1 Generation Net generation, in MWh, is the amount of electricity produced by the generator and transmitted to the electric grid; it does not include any generation consumed by the plant. If the generation consumed by the plant is greater than the gross generation, negative net generation will occur and be displayed in eGRID; this can further result in negative emission rates. Plant-fuel-prime mover net generation for all prime mover types can be obtained from the EIA-923; (most) steam and nuclear generator unit level net generation can also be obtained from the EIA-923. For sampled plants with EIA-923 net generation, generation is reported monthly and annually so that ozone season generation is calculated by summing up the generation for the five months of May through September. If there are no monthly data, ozone season generation is calculated as 5/12 of the annual generation. Net generation for those plant-prime movers (or entire plants) that did not report data to the EIA-923, but did report emissions to the EPA, is derived from EPA/CAMD data if there also is positive gross load generation in the EPA/CAMD data file. The following methodology was employed for obtaining year 2010 net generation data: Plant Level Net Generation To determine plant level net generation, use EIA-923 plant-prime mover annual and ozone season MWh net generation, if available. Ozone season net generation for those plants/generators that report monthly to the EIA-923 is calculated by summing the May through September net generation; for Abt Associates TSD for the 9th Edition of eGRID | pg. 16 ------- eGRID METHODOLOGY plants/units that report only annually to the EIA-923, the ozone season net generation is calculated as 5/12 of annual net generation. If plant-prime mover net generation is also needed because there is EPA/CAMD non-zero reported emissions without associated EIA-923 net generation, then CAMD's reported annual gross load multiplied by a prime mover-level conversion factor found in Velocity Suite's data (Ventyx, 2007) for the specific unit(s) is used to estimate annual net generation MWh, aggregated to the plant level by prime mover. Similarly, for estimating EPA/CAMD ozone season net generation, CAMD's reported ozone season gross load multiplied by a prime mover-level conversion factor found in Velocity Suite's data (Ventyx, 2007) for the specific unit(s) is used to estimate ozone season net generation MWh, aggregated to the plant level by prime mover. Otherwise, if net generation for that prime mover is zero, then the associated adjusted emissions is assigned a value of zero. Generation can be appropriately attributed to fuel type with the EIA-923 data. With the selected CAMD net generation, the fuel code of the plant primary fuel is assigned (see Sections 3.3 and 3.4 for further information about resource mix). 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. Generator Level Net Generation To determine generator level net generation for some units, use EIA-923 annual and ozone season net generation MWh for plants with one prime mover at a non-nuclear plant operating in year 2010. Additionally, for steam and nuclear generators, use EIA-923 nuclear unit-level reported annual and ozone season net generation. Most non-steam generators will not have a year 2010 value for net generation. 3.1.9.2 Heat Input Heat input, in MMBtu, is the amount of heat energy consumed by a generating unit that combusts fuel. Annual boiler level heat input for eGRID is initially obtained from EPA/CAMD 12 month reported emissions data. Ozone season heat input is also provided with these data. EPA heat input is based either on stack flow and C02/02 monitoring, or fuel flow and heat content of fuel. If these EPA data are unavailable, heat input is obtained from the EIA-923 prime mover level data; its value was calculated internally by EIA by multiplying the reported EIA fuel consumption by the reported heat content (the higher heating value). If monthly data are available, the EIA ozone season heat input is calculated by summing up the data for the five months of May through September; otherwise, the ozone season heat input is calculated as 5/12 of the annual heat input. If a plant reports heat input or data to calculate heat input for the same prime mover to EIA-923 and/or EPA/CAMD, the EPA/CAMD data are used first. If the sources are different for different components of the plant, then the heat input data are summed for the plant. Abt Associates TSD for the 9,h Edition of eGRI ^ | *17 ------- eGRID METHODOLOGY 3.1.9.3 Rates The units for output emission rates are lb/MWh for S02, NOx, and C02, and lb/GWh for Hg, CH4 and N20. These rates are calculated as the emissions divided by the net generation and multiplied by a unit conversion factor. Beginning with year 2009 data, for fuel-based output emissions rates, rather than dividing the total adjusted emissions by the total plant net generation (as done for year 2007 data and earlier), if a plant is partially a combustion plant (i.e., it includes both combustion and non- combustion generators), then the total plant emissions are instead divided by the combustion net generation for that plant. For input emission rates, the units are lb/MMBtu for S02, NOx, and C02, and lb/BBtu for Hg; these rates are calculated as the emissions divided by the heat input and multiplied by a unit conversion factor. 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 electricity consumption within a certain region, divide the consumption by (one minus the grid gross loss as a decimal). If reporting GHG emissions to The Climate Registry (TCR), the emissions without the line losses belong in scope 2, while just the emissions from line losses (the difference between the emissions including line losses and the emissions not including line losses) belong in scope 3. eGRID publishes grid gross loss factors, which can be used to account for line losses, in the eGRID Summary Tables. Beginning with year 2009 data, grid gross loss is derived from FERC-714 power control area/balancing authority interchange data (as well as FERC generation, EIA consumption, U.S. regional interchange, and FERC foreign [Canadian and Mexican] net imports) that are summed to the defined region. The eGRID year 2010 estimated grid gross loss for each U.S. interconnect power grid (EIA, 2000) (see Table 3-4 for eGRID subregion - U.S. interconnect power grid relationships) are included in the tab "GGL10" in the eGRID workbook and are also displayed in Table 3-5. Table 3-4. eGRID Subregion Acronym and Names for eGRID eGRID Subregion eGRID Subregion Name Power Grid FRCC FRCC All Eastern MORE MRO East Eastern MROW MRO West Eastern NEWE NPCC New England Eastern NYCW NPCC NYC/Westchester Eastern NYLI NPCC Long Island Eastern NYUP NPCC Upstate NY Eastern RFCE RFC East Eastern RFCM RFC Michigan Eastern RFCW RFC West Eastern Abt Associates TSD for the 9th Edition of eGRID | pg. 18 ------- eGRID METHODOLOGY eGRID Subregion eGRID Subregion Name Power Grid SRMW SERC Midwest Eastern SRMV SERC Mississippi Valley Eastern SRSO SERC South Eastern SRTV SERC Tennessee Valley Eastern SRVC SERC Virginia/Carolina Eastern SPNO SPP North Eastern SPSO SPP South Eastern CAMX WECC California Western NWPP WECC Northwest Western RMPA WECC Rockies Western AZNM WECC Southwest Western ERCT ERCOT All ERCOT AKGD ASCC Alaska Grid Alaska AKMS ASCC Miscellaneous Alaska HIOA HICC Oahu Hawaii HIMS HICC Miscellaneous Hawaii Table 3-5. eGRID Year 2010 Grid Gross Loss (%) Power Grid Grid Gross Loss (%) Eastern 5.821 Western 6.84 ERCOT 7.12 Alaska 6.89 Hawaii 7.38 U.S. 6.18 1Due to an anomaly with the 2010 source data for the eastern grid that results in an unreasonable 2010 GGL factor, the year 2009 eastern grid gross loss factor is used for year 2010. Fuel-based Emission Rates Beginning at the state level, coal, oil, gas, and fossil fuel output and input emission rates are calculated based on a plant's fossil fuel category, which in turn is based on the plants" primary fuel (see Section 3.3). If a plant's primary fuel is in the coal, oil, gas, or other fossil category, then all of its adjusted emissions and heat input, and combustion net generation are included in the respective aggregation level for that fuel category. For example, all plants with primary fuel in the coal category Abt Associates TSD for the 9th Edition of eGRID | pg. 19 ------- eGRID METHODOLOGY and that are located in Alabama will have their emissions, heat input, and combustion net generation summed and then the appropriate calculations will be applied to determine the fuel-based output and input emission rates for Alabama. See Table 3-6 for a list of primary fuels and fuel categories. The methodology used to determine fuel-based output emissions rates has changed (see Section 2.2, What's New in eGRID). Table 3-6. Plant Primary Fuel Fuel Code Description Fuel Category Fuel Group AB agricultural byproducts biomass solid BG bagasse biomass solid BLQ black liquor biomass solid DG digester gas biomass gas LFG landfill gas biomass gas ME methane biomass gas MSB MSW biomass part biomass solid OBL other biomass liquid biomass liquid OBS other biomass solids biomass solid PP paper pellets biomass solid SLW sludge waste biomass solid WDL wood (waste) liquids biomass liquid WDS wood (waste) solids biomass solid ANT anthracite coal coal solid BIT bituminous coal coal solid LIG lignite coal coal solid SUB subbituminous coal coal solid SC syncoal coal solid RC refined coal coal solid WC waste coal coal solid SGC coal-derived synthetic gas coal gas NG natural gas gas gas PG propane gas/LPG gas gas BU butane gas gas gas DFO distillate/diesel oil oil liquid JF jet fuel oil liquid KER kerosene oil liquid OO other oil oil liquid OTL other liquid oil liquid Abt Associates TSD for the 9th Edition of eGRID | pg. 20 ------- eGRID METHODOLOGY Fuel Code Description Fuel Category Fuel Group PC petroleum coke oil solid RG refinery gas oil gas RFO residual oil oil liquid WO waste oil oil liquid BFG blast furnace gas other fossil gas COG coke oven gas other fossil gas HY hydrogen other fossil gas LB liquid byproduct other fossil liquid MH methanol other fossil liquid MSF MSW other fossil part other fossil solid OG other gas other fossil gas OTS other solid other fossil Solid TDF tire-derived fuel other fossil Solid Non-baseload Emission Rates Beginning at the state level, there are seven annual non-baseload emission rates (for NOx, ozone season NOx, S02, C02, CH4, N20, and Hg), which are sometimes used as a rough estimate to determine how much emissions could be avoided if energy efficiency and/or renewable energy would displace fossil fuel generation. These non-baseload output emission rates are provided as an improved alternative to fossil fuel output emissions rates, which were sometimes used for this purpose, as they factor out baseload generation, which is generally unaffected by measures that affect marginal generation. Capacity factor is used as a surrogate for determining how much non-baseload generation and emissions occur at each facility. Although there are reasons that can influence a particular unit's capacity factor besides dispatch or load order (e.g., repairs), capacity factor is being used as a surrogate for dispatch-order for this calculation. The non-baseload information is published in eGRID just at the aggregate level (state, Power Control Area (PCA), etc.), but not for individual plants. Beginning with year 2010 data, the methodology used to calculate these emission rates has changed. Previously, plant level data were used to calculate non-baseload output emission rates. Beginning with year 2010 data, unit-level and/or prime mover-level emissions and generation are used. For steam units, if unit-level emissions and generation data exists for all of the steam units at a facility, then the unit-level data are used. Otherwise, if unit-level emissions and generation data does not exist for all of the steam units at a facility, then prime mover-level emissions and generation data are used. For nonsteam combustion units (e.g. combustion turbines), prime mover-level emissions and generation are used. The following describes the procedure used to generate these non-baseload emission rates. The emission rates are determined starting with unit or prime mover level data. First, all units and prime movers that do not combust fuel (i.e., hydro, nuclear, wind, solar, and/or geothermal) are removed. Abt Associates TSD for the 9th Edition of eGRID | pg. 21 ------- eGRID METHODOLOGY Next, a capacity factor relationship is used to determine the percent of the generation and emissions from each unit or prime mover to be considered non-baseload generation. All generation and emissions at units or prime movers with low capacity factors (less than 0.2) would be considered non- baseload (a non-baseload factor of 1). No generation or emissions at units or prime movers with high capacity factors (0.8 and greater) would be considered non-baseload (non-baseload factor of 0). A linear relationship would determine the percent of generation and emissions that is non-baseload at units or prime movers with capacity factors between 0.2 and 0.8. For these units or prime movers, the non-baseload factor is -5/3* (capacity factor) + 4/3. The capacity factor is determined for both the year and the ozone season. Finally, the total non-baseload generation and the total non-baseload emissions are summed up at each level of aggregation (state, PCA, eGRID subregion, NERC region, and U.S. Total) and are used to calculate the non-baseload output emission rates. eGRID non-baseload values can be useful when attempting to estimate the emissions benefits of reductions in electricity use. For example, if one is interested in estimating the carbon dioxide emission reductions associated with the reduction of electricity use due to increased energy efficiency, then one could use the eGRID subregion non-baseload C02 output emission rate and the expected or actual energy savings resulting from the installation to estimate the C02 emission reductions. Non-baseload values should not be used for assigning an emission value for electricity use in carbon- footprinting exercises or GHG emissions inventory efforts. eGRID subregion total output emission rates are recommended for scope 2 emissions and the eGRID subregion non-baseload output emission rates are recommended to estimate emission reductions from renewable energy or energy efficiency projects that reduce consumption of grid supplied electricity. Combustion Emission Rates Combustion output emission rates for all pollutants are estimated, beginning at the plant level. Whereas the generation used in the denominator for calculating the traditional total output emission rate is the total net generation, the denominator used for calculating the combustion output emission rate is the net generation associated with emissions, namely, the combustion generation only. Thus, generation from nuclear, hydro, geothermal, solar, and wind will not be included in the calculation of this rate. This methodology has not changed. 3.2 Treatment of Plant Ownership Beginning with year 2009 data, the owner(s) and operator of a plant are taken directly from data provided in the 2009 EIA-860. Since ownership is reported in eGRID only on the plant level, but in the EIA-860 on the generator level, the generators' owner companies and percentages must be aggregated to the plant level, which is accomplished for each plant by MW-weighting each generator's ownership and then summing to the plant level. Although eGRID's methodology for assigning ownership on a plant level has not changed, eGRID is no longer tracking ownership or nonutility front company data as done in the past, and is now taking ownership data directly from the EIA-860 for year 2010 data. Unfortunately, there are some plants for which this plant-level ownership methodology will result in misleading percentages. For example, if one company owns only one of several generators and that one generator is connected to a "clean" boiler that has emissions whose ratio to the entire plant's Abt Associates TSD for the 9,h Edition of eGRI | .xt 22 ------- eGRID METHODOLOGY emissions is much less than its MW's ratio to the entire plant's MW, that one company will, because of its MW-to-plant MW ratio, have a higher plant ownership percentage attributed to it than its actual emissions plant percentage; thus, that company will be associated with greater emissions and generation than it actually has. This situation is not typical since most plants do not have "jointly owned" generators or different owners for all the plant's generators. It affects only some plants and companies and some percentage of emissions and generation associations in this situation. One example demonstrates how this methodology assigns ownership at the plant level and how the emissions at a plant may be associated with the owners at different percentages than the plant owenership percentages. Ohio's Cardinal plant (ORISPL = 2828) has three generators and three boilers, associated on a one-to-one basis. Each generator has about the same nameplate capacity. One generator is owned by Ohio Power, and two by Buckeye Power Inc. The Cardinal plant ownership is approximately 33% Ohio Power and 67% Buckeye, so 67% of the plant emissions would be attributable to Buckeye Power using eGRID methodology. However, the reported S02 emissions for the two boilers associated with Buckeye's two generators combined are over 90% of the Cardinal plant's reported S02 emissions total (the largest boiler has no S02 control), and the reported NOx emissions for the two boilers associated with Buckeye's two generators combined are over 70% of the Cardinal plant's reported NOx emissions total (the largest boiler has an additional NOx control [selective catalytic reduction]). 3.3 Determination of Plant Primary Fuel The primary fuel of a plant that consumes any amount of combustible fuel is determined solely by the fuel that has the maximum heat input for year 2010 data. This methodology has not changed. For plants that do not consume any combustible fuel, the primary "fuel" is determined by the resource associated with the prime mover (nuclear, solar, wind, geothermal, or hydro/pumped storage) with the maximum generation associated with that prime mover. See Section 5 below for lists of all possible boiler, generator, and plant primary fuel codes and descriptions. The possible original fuel codes and fuel categories for the plant primary fuel data variable (PLPRMFL in the eGRID plant file) are as shown in Table 3-6. Note that since solid waste plants are broken down into biomass and fossil components, a solid waste plant will have "MSB" as the primary fuel. Since the plant primary fuel variable is based solely on heat input, a partially combustible fueled plant, i.e., one that burns some combustible fuel but is mainly a nuclear, hydro, or solar plant, the plant primary fuel designation can be misleading. Thus, a new variable, plant primary fuel generation category, was developed for the plant file, beginning with year 2007 data. This new variable is based on the maximum net generation fuel category and can be one of eleven values (the same as the number of plant annual net generation fuel categories) as shown in Table 3-7. Abt Associates TSD for the 9,h Edition of eGRI | .xt 23 ------- eGRID METHODOLOGY Table 3-7. Plant Primary Fuel Generation Category Fuel Category Description CL Coal OL Oil GS Gas NC Nuclear HY Hydro BM Biomass Wl Wind SO Solar GT Geothermal OF Other Fossil OP Other Unknown/Purchased/Waste Heat 3.4 Estimation of Resource Mix Resource mix is a collection of nonrenewable and renewable resources that are used to generate electricity. 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. A percentage is assigned to each resource or group of resources. Resource mix is displayed in eGRID and expressed in both MWh and generation percent. 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 cases in which there are only two fuels and both net generations are negative, both fuels" generation percentages are assigned 0%. For the three grouped aggregate categories - total net generation from nonrenewable, total net generation from all renewables, and total net generation from renewables minus hydro - the sum of the total net generation from renewables and from all nonrenewables equals the total net generation. In cases for which there is both positive and negative fuel generation in the nonrenewables category (it is unlikely to happen in the renewables category), the category percentages may be misleading since only the positive generation components are considered in calculating the generation percentages for total renewables and nonrenewables. Similarly, for the two grouped aggregated categories of combustion net generation and noncombustion net generation, their sum equals the total net generation. For cases in which there is more than one negative nonrenewables (or combustion) net generation value and there is no renewables (or noncombustion) net generation, the total nonrenewables (or combustion) resource mix is assigned 100 %. The methodology for the determination of resource mix has not changed. Abt Associates TSD for the 9th Edition of eGRID | pg. 24 ------- eGRID METHODOLOGY eGRID plant resource mix and net generation are derived from the EIA-923 prime mover level data, which provides the information on a plant-prime mover-fuel level. However, there are some cases for which only the EPA/CAMD-based net generation is available for use in eGRID. In these cases, the primary fuel (based on the maximum heat input value) is assigned 100% of the generation for the resource mix. 3.5 Determination of Plant Aggregation Links The plant's state, operator, and owner(s), as well as the utility service territory EGCs (updated as needed) are already associated with each plant and based on EIA data. A graphic representation of examples of relationships among plants, utility service territories, PCAs, eGRID subregions, and NERC regions is depicted below in Figure 3-1. Figure 3-1. Examples of Plant Through NERC Linkages Plant A Plant B Plant C Plant D Plant E Plant F 3.5.1 NERC Region NERC region refers to a region designated by the North American Electric Reliability Corporation. 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 Abt Associates TSD for the 9th Edition of eGRID | pg. 25 ------- eGRID METHODOLOGY are not part of the formal NERC regions, but are considered so in eGRID). The NERC regions themselves have not changed from those in eGRID2010; the Electric Reliability Council of Texas (ERCOT) NERC region did change its name to the Texas Reliability Entity (TRE) between eGRID years 2006 and 2007 data. Note, however, that some plants operating in each NERC region do change from year to year. The ten NERC region names and their acronyms for eGRID are displayed in Table 3-8. Table 3-8. 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 SPP Southwest Power Pool TRE Texas Regional Entity WECC Western Electricity Coordinating Council 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 United States. A representation of the NERC region map used for eGRID is included in Appendix B. This map, which is a representational one, shows approximate boundaries because they are based on companies, not on strictly geographical boundaries. Since NERC regions are based not on location but on companies, the linkage is between a plant and its transmission/distribution/utility service territory, which in turn is linked to a PCA, which is associated with a NERC region. 3.5.2 eGRID Subregion eGRID subregions are developed as subsets of NERC regions. In eGRID2002 and earlier, these grid regions were similar to EPA's Integrated Planning Model (IPM) subregions (except for the New York and California areas). Many of these older subregions no longer exist since their NERC regions no longer exist. At this juncture, NERC has only defined subregions for the WECC NERC region. Thus, for the WECC NERC region and for those other NERC regions that did not change configuration, the newer eGRID subregions will remain in effect. Definitions of the eGRID subregions were made by EPA after consultation with NERC staff. A representation of the eGRID subregion map used for eGRID is included in Appendix B. This map, which is a representational one, shows approximate boundaries because they are based on companies, not on strictly geographical boundaries. Since plant-associated eGRID subregions are based on companies, the linkage is between a plant and its transmission/distribution/utility service territory, not the plant location. Thus, there is no shape file or subregion layer available for eGRID subregions. Abt Associates TSD for the 9th Edition of eGRID | pg. 26 ------- eGRID METHODOLOGY eGRID subregions are identified and defined by EPA - using the NERC regions and PCAs as a guide. An eGRID subregion is often, but not always, equivalent to an IPM subregion. The 26 eGRID subregions are subsets of the NERC regions as configured on December 2010. The plant's associated PCA determines the plant's associated eGRID subregion, which is defined as a subset of the NERC region, and is composed of entire PCAs - with the exception of PJM Interconnection and New York Independent System Operator PCAs, which are each associated with three eGRID subregions. The eGRID subregions themselves have not changed since eGRID2002 year 2000 data. Note, however, that some plants operating in each eGRID subregion do change from year to year. The 26 eGRID subregion names and their acronyms are displayed in Table 3-4, along with the U.S. interconnect power grid that they are part of. Note that the five eGRID subregions within the SERC NERC region are also known by other names; specifically, SERC Midwest is also called Gateway, SERC Mississippi Valley is also called Delta, SERC Tennessee Valley is also called Central, SERC South is also called Southeastern, and SERC Virginia/Carolina is also called VACAR. 3.5.3 Power Control Area A PCA (or Balancing Authority, as NERC now terms it) is a portion of an integrated power grid for which a single dispatcher has operational control of all electric generators. PCAs range in size from small municipal utilities such as the City of Columbia, MO, to large power pools such as PJM Interconnection. There have been some changes to PCAs from eGRID year 2009 data to eGRID year 2010 data (NERC, 2013). In Alaska, isolated electric utility systems, which are not part of an integrated power grid, have been grouped into a nominal PCA called "Alaska Misc." In Hawaii, isolated electric utility systems, which are not part of an integrated power grid, have been grouped into a nominal PCA called "Hawaii Misc." These two PCAs have dummy (negative) codes since there are none available from EIA: -1 for Alaska Misc and -2 for Hawaii Misc. Otherwise, PCA IDs are assigned based on the EIA-861 (EIA, 201 la) if possible; if the name is essentially the same as an EGC's, then the EIA EGC code from the EIA-860 is used (EIA, 2012). In eGRID, a PCA associated with a plant is determined by the transmission lines connecting the PCA and the plant through a utility entity (previously thought of/known as a utility service area) and now reported to EIA as "the owner of the transmission or distribution facilities to which the plant is interconnected" (EIA, 201 la) and that eGRID terms a utility service territory. PCAs are assigned according to the utility service territory in which the plant is physically located. The PCA associated with a plant is determined by the owner of the transmission/distribution utility/regulated EGC (not parent company) associated with the plant. At present, there is not one Federal file that can be used to link year 2010 utility EGCs with their PCAs, but the PCAs in eGRID have been updated and reported by NERC to reflect an October 2013 configuration (NERC, 2013). The PCA link to the NERC region has been determined by NERC, as has the PCA association with the Midcontinent Independent System Operator (MISO) for 26 PCAs. The plant's associated PCA determines the plant's associated NERC region, except for the PJM Interconnection PCA, which has plants in two NERC regions. NERC provides the linkage used in eGRID between PCAs and NERC regions by publishing the currently registered balancing authorities in the NERC Compliance Registry (NERC, 2013). The NERC acronyms are also assigned by NERC. The possible relationships Abt Associates TSD for the 9,h Edition of eGRI | .xt 27 ------- eGRID METHODOLOGY between the 129 PC As (119 PC As are displayed in eGRID year 2010 data) and 10 NERC regions are shown below in Table 3-9. Table 3-9. PCA - NERC Region Relationship PCA Name NERC Region NERC Name Alaska Misc ASCC Alaska Systems Coordinating Council Anchorage Municipality of ASCC Alaska Systems Coordinating Council Chugach Electric Assn Inc ASCC Alaska Systems Coordinating Council Golden Valley Elec Assn Inc ASCC Alaska Systems Coordinating Council Florida Municipal Power Pool FRCC Florida Reliability Coordinating Council Florida Power & Light Company FRCC Florida Reliability Coordinating Council Gainesville Regional Utilities FRCC Florida Reliability Coordinating Council JEA FRCC Florida Reliability Coordinating Council New Smyrna Beach Utilities Commission of FRCC Florida Reliability Coordinating Council Progress Energy Florida FRCC Florida Reliability Coordinating Council Seminole Electric Cooperative FRCC Florida Reliability Coordinating Council Tallahassee City of FRCC Florida Reliability Coordinating Council Tampa Electric Company FRCC Florida Reliability Coordinating Council Hawaii Electric Light Co Inc HICC Hawaiian Islands Coordinating Council Hawaii Misc HICC Hawaiian Islands Coordinating Council Hawaiian Electric Co Inc HICC Hawaiian Islands Coordinating Council Alliant - East MRO Midwest Reliability Organization Alliant - West MRO Midwest Reliability Organization Dairyland Power Cooperative MRO Midwest Reliability Organization Great River Energy MRO Midwest Reliability Organization Lincoln Electric System MRO Midwest Reliability Organization Madison Gas and Electric Company MRO Midwest Reliability Organization MidAmerican Energy Company MRO Midwest Reliability Organization Minnesota Power MRO Midwest Reliability Organization Muscatine Power and Water MRO Midwest Reliability Organization Nebraska Public Power District MRO Midwest Reliability Organization Northern States Power MRO Midwest Reliability Organization Omaha Public Power District MRO Midwest Reliability Organization Otter Tail Power Company MRO Midwest Reliability Organization Southern Minnesota Municipal Power Agcy MRO Midwest Reliability Organization Abt Associates TSD for the 9th Edition of eGRID | pg. 28 ------- eGRID METHODOLOGY PCA Name NERC Region NERC Name Upper Peninsula Power Company MRO Midwest Reliability Organization WAPA - Upper Great Plains East MRO Midwest Reliability Organization Wisconsin Public Service Corporation MRO Midwest Reliability Organization New Brunswick System Operator NPCC Northeast Power Coordinating Council New England ISO NPCC Northeast Power Coordinating Council New York ISO NPCC Northeast Power Coordinating Council Consumers Energy Company RFC Reliability First Corporation Detroit Edison Company RFC Reliability First Corporation Duke Energy Corporation RFC Reliability First Corporation Hoosier Energy REC RFC Reliability First Corporation Indianapolis Power & Light Company RFC Reliability First Corporation Michigan Electric Coordinated Systems RFC Reliability First Corporation Northern Indiana Public Service Company RFC Reliability First Corporation Ohio Valley Electric Corporation RFC Reliability First Corporation PJM Interconnection RFC Reliability First Corporation Southern Indiana Gas & Electric Company RFC Reliability First Corporation Wisconsin Energy Corporation RFC Reliability First Corporation Alcoa Power - Yadkin Division SERC SERC Rel abil ty Corporation Ameren Services Company SERC SERC Rel abil ty Corporation Associated Electric Cooperative Inc SERC SERC Rel abil ty Corporation Big Rivers Electric Corporation SERC SERC Rel abil ty Corporation CECD - Batesville SERC SERC Rel abil ty Corporation Columbia MO City of SERC SERC Rel abil ty Corporation Duke Energy Carolinas SERC SERC Rel abil ty Corporation East Kentucky Power Cooperative SERC SERC Rel abil ty Corporation Entergy SERC SERC Rel abil ty Corporation LG&E and KU Services Company SERC SERC Rel abil ty Corporation Louisiana Generating SERC SERC Rel abil ty Corporation North Little Rock AR City of SERC SERC Rel abil ty Corporation PJM Interconnection SERC SERC Rel abil ty Corporation Plum Point Energy Associates SERC SERC Rel abil ty Corporation PowerSouth Energy Cooperative SERC SERC Rel abil ty Corporation Progress Energy Carolinas SERC SERC Rel abil ty Corporation Abt Associates TSD for the 9th Edition of eGRID | pg. 29 ------- eGRID METHODOLOGY PCA Name NERC Region NERC Name South Carolina Electric & Gas Company SERC SERC Rel abil ty Corporation South Carolina Public Service Authority SERC SERC Rel abil ty Corporation South Mississippi Electric Power Assn SERC SERC Rel abil ty Corporation Southern Company Services SERC SERC Rel abil ty Corporation Southern Illinois Power Cooperative SERC SERC Rel abil ty Corporation Springfield IL - CWLP City of SERC SERC Rel abil ty Corporation Tennessee Valley Authority SERC SERC Rel abil ty Corporation Union Power Partners SERC SERC Rel abil ty Corporation AEP - PSO/SWEPCO SPP Southwest Power Pool Cleco Corporation SPP Southwest Power Pool Empire District Electric Company SPP Southwest Power Pool Grand River Dam Authority SPP Southwest Power Pool Independence MO City of SPP Southwest Power Pool Kansas City Board of Public Utilities SPP Southwest Power Pool Kansas City Power & Light Co-GMO SPP Southwest Power Pool Kansas City Power & Light Company SPP Southwest Power Pool Lafayette Utilities System SPP Southwest Power Pool Louisiana Energy & Power Authority SPP Southwest Power Pool Oklahoma Gas and Electric Company SPP Southwest Power Pool Southwestern Power Administration SPP Southwest Power Pool Southwestern Public Service Company SPP Southwest Power Pool Sunflower Electric Power Corporation SPP Southwest Power Pool Westar Energy SPP Southwest Power Pool Western Farmers Electric Cooperative SPP Southwest Power Pool ERCOT ISO TRE Texas Regional Entity Arizona Public Service Company WECC Western Electricity Coordinating Council Arlington Valley WECC Western Electricity Coordinating Council Avista Corporation WECC Western Electricity Coordinating Council Balancing Authority of Northern California WECC Western Electricity Coordinating Council Bonneville Power Administration WECC Western Electricity Coordinating Council California ISO WECC Western Electricity Coordinating Council El Paso Electric Company WECC Western Electricity Coordinating Council Gila River Power WECC Western Electricity Coordinating Council Griffith Energy WECC Western Electricity Coordinating Council Abt Associates TSD for the 9th Edition of eGRID | pg. 30 ------- eGRID METHODOLOGY PCA Name NERC Region NERC Name Idaho Power Company WECC Western Electricity Coordinating Council Imperial Irrigation District WECC Western Electricity Coordinating Council Los Angeles Department of Water and Power WECC Western Electricity Coordinating Council NaturEner Power Watch WECC Western Electric ty Coord nating Council Nevada Power Company WECC Western Electric ty Coord nating Council New Harquahala Generating Company WECC Western Electric ty Coord nating Council Northwestern Corporation WECC Western Electric ty Coord nating Council PUD No. 1 of Chelan County WECC Western Electric ty Coord nating Council PUD No. 1 of Douglas County WECC Western Electric ty Coord nating Council PUD No. 2 of Grant County WECC Western Electric ty Coord nating Council PacifiCorp WECC Western Electric ty Coord nating Council Portland General Electric Company WECC Western Electric ty Coord nating Council Public Service Company of Colorado WECC Western Electric ty Coord nating Council Public Service Company of New Mexico WECC Western Electric ty Coord nating Council Puget Sound Energy WECC Western Electric ty Coord nating Council Salt River Project WECC Western Electric ty Coord nating Council Seattle City Light WECC Western Electric ty Coord nating Council Sierra Pacific Power Company WECC Western Electric ty Coord nating Council Tacoma Power WECC Western Electric ty Coord nating Council Tucson Electric Power WECC Western Electric ty Coord nating Council Turlock Irrigation District WECC Western Electric ty Coord nating Council WAPA - Desert Southwest Region WECC Western Electric ty Coord nating Council WAPA - Rocky Mountain Region WECC Western Electric ty Coord nating Council The 2010 EIA-860 (EIA, 2012) specifies each plant's owner of the transmission/distribution utility /regulated EGC (also called utility service territory), but there appear to be many that are incorrect. Beginning with year 2009 data, a WECC document, "Existing Generation and Significant Additions and Changes to System Facilities Data as of January 1, 2007" (WECC, 2007) and independent research are also used to identify PCAs and eGRID subregions (then the WECC plants" utility service territories are updated as needed) for each plant. The other nine NERC regions" utility service territories are also reviewed and updated as needed, as are the PCAs, eGRID subregions, and NERC regions. Since PCAs are not strictly geographically based, there are no shape files available for mapping them. Several years ago, the NERC website, www.nerc.com. had a PCA "bubble map" available to show the relationship between the PCAs and their approximate relationship to NERC regions, but it was simply an approximation. A recent PCA bubble map does not seem to be available from NERC Abt Associates TSD for the 9th Edition of eGRID | pg. 31 ------- eGRID METHODOLOGY The relationship among PCAs, eGRID subregions, and NERC regions, as well as the PCA-MISO association is depicted in Table 3-10 below. Table 3-10. PCA - MISO - eGRID Subregion - NERC Region Relationship PCA Name MISO? eGRID Subregion Name NERC Region AEP - PSO/SWEPCO SPSO SPP Alaska Misc AKMS ASCC Alcoa Power - Yadkin Division SRVC SERC Alliant - East Y MROE MRO Alliant - West Y MROW MRO Ameren Services Company Y SRMW SERC Anchorage Municipality of AKGD ASCC Arizona Public Service Company AZNM WECC Arlington Valley AZNM WECC Associated Electric Cooperative Inc SRMW SERC Avista Corporation NWPP WECC Balancing Authority of Northern California CAMX WECC Big Rivers Electric Corporation Y SRTV SERC Bonneville Power Administration NWPP WECC CECD - Batesville SRMV SERC California ISO CAMX WECC Chugach Electric Assn Inc AKGD ASCC Cleco Corporation SPSO SPP Columbia MO City of Y SRMW SERC Consumers Energy Company Y RFCM RFC Dairyland Power Cooperative Y MROW MRO Detroit Edison Company Y RFCM RFC Duke Energy Carolinas SRVC SERC Duke Energy Corporation Y RFCW RFC ERCOT ISO ERCT TRE East Kentucky Power Cooperative SRTV SERC El Paso Electric Company AZNM WECC Empire District Electric Company SPNO SPP Entergy SRMV SERC Florida Municipal Power Pool FRCC FRCC Florida Power & Light Company FRCC FRCC Abt Associates TSD for the 9th Edition of eGRID | pg. 32 ------- eGRID METHODOLOGY PCA Name MISO? eGRID Subregion Name NERC Region Gainesville Regional Utilities FRCC FRCC Gila River Power AZNM WECC Golden Valley Elec Assn Inc AKGD ASCC Grand River Dam Authority SPSO SPP Great River Energy Y MROW MRO Griffith Energy AZNM WECC Hawaii Electric Light Co Inc HIMS HICC Hawaii Misc HIMS HICC Hawaiian Electric Co Inc HIOA HICC Hoosier Energy REC Y RFCW RFC Idaho Power Company NWPP WECC Imperial Irrigation District AZNM WECC Independence MO City of SPNO SPP Indianapolis Power & Light Company Y RFCW RFC JEA FRCC FRCC Kansas City Board of Public Utilities SPNO SPP Kansas City Power & Light Co-GMO SPNO SPP Kansas City Power & Light Company SPNO SPP LG&E and KU Services Company SRTV SERC Lafayette Utilities System SPSO SPP Lincoln Electric System MROW MRO Los Angeles Department of Water and Power CAMX WECC Louisiana Energy & Power Authority SPSO SPP Louisiana Generating SRMV SERC Madison Gas and Electric Company Y MROE MRO Michigan Electric Coordinated Systems Y RFCM RFC MidAmerican Energy Company Y MROW MRO Minnesota Power Y MROW MRO Muscatine Power and Water Y MROW MRO NaturEner Power Watch NWPP WECC Nebraska Public Power District MROW MRO Nevada Power Company AZNM WECC New Brunswick System Operator NEWE NPCC New England ISO NEWE NPCC Abt Associates TSD for the 9th Edition of eGRID | pg. 33 ------- eGRID METHODOLOGY PCA Name MISO? eGRID Subregion Name NERC Region New Harquahala Generating Company AZNM WECC New Smyrna Beach Utilities Commission of FRCC FRCC New York ISO NYCW NPCC New York ISO NYLI NPCC New York ISO NYUP NPCC North Little Rock AR City of SRMV SERC Northwestern Corporation NWPP WECC Northern Indiana Public Service Company Y RFCW RFC Northern States Power Y MROW MRO Ohio Valley Electric Corporation RFCW RFC Oklahoma Gas and Electric Company SPSO SPP Omaha Public Power District MROW MRO Otter Tail Power Company Y MROW MRO PJM Interconnection RFCE RFC PJM Interconnection RFCW RFC PJM Interconnection SRVC SERC PUD No. 1 of Chelan County NWPP WECC PUD No. 1 of Douglas County NWPP WECC PUD No. 2 of Grant County NWPP WECC PacifiCorp NWPP WECC Plum Point Energy Associates SRMV SERC Portland General Electric Company NWPP WECC PowerSouth Energy Cooperative SRSO SERC Progress Energy Carolinas SRVC SERC Progress Energy Florida FRCC FRCC Public Service Company of Colorado RMPA WECC Public Service Company of New Mexico AZNM WECC Puget Sound Energy NWPP WECC Salt River Project AZNM WECC Seattle City Light NWPP WECC Seminole Electric Cooperative FRCC FRCC Sierra Pacific Power Company NWPP WECC South Carolina Electric & Gas Company SRVC SERC South Carolina Public Service Authority SRVC SERC Abt Associates TSD for the 9th Edition of eGRID | pg. 34 ------- eGRID METHODOLOGY PCA Name MISO? eGRID Subregion Name NERC Region South Mississippi Electric Power Assn SRSO SERC Southern Company Services SRSO SERC Southern Illinois Power Cooperative Y SRMW SERC Southern Indiana Gas & Electric Company Y RFCW RFC Southern Minnesota Municipal Power Agcy Y MROW MRO Southwestern Power Administration SPSO SPP Southwestern Public Service Company SPSO SPP Springfield IL - CWLP City of Y SRMW SERC Sunflower Electric Power Corporation SPNO SPP Tacoma Power NWPP WECC Tallahassee City of FRCC FRCC Tampa Electric Company FRCC FRCC Tennessee Valley Authority SRTV SERC Tucson Electric Power AZNM WECC Turlock Irrigation District CAMX WECC Union Power Partners SRMV SERC Upper Peninsula Power Company Y MROE MRO WAPA - Desert Southwest Region AZNM WECC WAPA - Rocky Mountain Region RMPA WECC WAPA - Upper Great Plains East MROW MRO Westar Energy SPNO SPP Western Farmers Electric Cooperative SPSO SPP Wsconsin Energy Corporation Y RFCW RFC Wsconsin Public Service Corporation Y MROE MRO 3.6 Treatment of Aggregation Levels All aggregation levels are based on the plant file. The state file data are developed by summing up the plant 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 non- baseload emission rates), based on the state in which the plant is located. The PCA, eGRID subregion, and NERC region files are developed by summing up the plant data for each of the values for each aggregation level. This methodology has not changed. The totals from the plant, state, PCA, eGRID subregion, NERC region, and U.S. files" adjusted heat input, adjusted emissions, adjusted fuel-based emissions, net generation, fuel-based net generation, and nameplate capacity data should be the same, after accounting for rounding. Abt Associates TSD for the 9th Edition of eGRID | pg. 35 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS 4. Specific eGRID Identifier Codes, Name Changes and Associations The ninth edition of eGRID, as well as eGRID2012, generally uses identifier (ID) codes (for plants, companies, etc.) assigned by EIA. However, IDs and certain corresponding names were changed in eGRID2012 and retained in the ninth edition of eGRID to minimize confusion. If needed, entities that do not have an EIA designated ID are assigned values in eGRID. The specifics are delineated below. 4.1 Plant Level One plant, Laramie River Station (ORISPL = 6204) in Wyoming, has three boilers and generators that supply power to two different power grids. Consequently, the first boiler (1) is treated as a separate plant with a dummy ORISPL = 6204.1 because it is operated within a PCA that is in the Eastern grid; while the second and third boilers are treated as a separate plant with a dummy ORISPL = 6204.2 because they are operated within a PCA that is in the Western grid. This plant representation occurs in all editions of eGRID. 4.2 EGC, Company Level EGCs, for purposes of eGRID files, are operators, owners, and utility service territories of power plants for the given year. Each EGC has a unique code assigned by EIA. Several other companies, as utility service territories, are broken up and given dummy IDs because the company operates in more than one power control area or does not have an EIA company code in any published EIA electric power survey data. These include: • Basin Electric Power Coop EGC (ID = 1307), which is broken up into two divisions: Basin Electric Power Coop-East EGC (ID = 1307.1) and Basin Electric Power Coop-West EGC (ID = 1307.2); and • PacifiCorp EGC (ID = 14354), which is broken up into two divisions: PacifiCorp-Rocky Mtn EGC (ID = 14354.1) and PacifiCorp-Pacific EGC (ID = 14354.2. Abt Associates TSD for the 9th Edition of eGRID | pg. 36 ------- SPECIFIC eGRID IDENTIFIER CODES, NAME CHANGES AND ASSOCIATIONS [This page intentionally left blank.] Abt Associates TSD for the 9,h Edition of eGRI | .xt 37 ------- DESCRIPTION OF DATA ELEMENTS 5. Description of Data Elements For year 2010 data, eGRID has 8 aggregation files named BLR (boiler), GEN (generator), PLNT (plant), ST (state), PCAL (PCA), SRL (eGRID subregion), NRL (NERC region), and US (United States total). The regional grid gross loss factor data are also included. Appendix A provides the file structure for the eGRID year 2010 data, which include variable descriptions and original data sources. Definitions for like 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, nnNGENAN (where nn is ST, PC, SR, NR, or US) is not described in Appendix A; it is simply the sum of PLNGENAN attributed to the aggregation entity. 5.1 The BLR (Boiler) File There are 34 variables in the first file, BLR, which contains unit-level data. The one new variable for this data year is the first one. The one replacement variable (previously NBPFLAG) is PRGCODE, which displays all - not just one ~ of the EPA programs to which the unit is subjected. Note that summing the boiler unadjusted emissions to the plant level may not result in the same values as the plant unadjusted emissions since additional emissions from prime movers not covered by the EPA/CAMD boiler level data may be included in the plant emissions values. 1. eGRID year 2010 File Boiler Sequence Number (SEQBLR10) - The boiler records in this year 2010 data file are sorted by state postal code abbreviation, plant name, plant code, and boiler 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 year 2009 eGRID file for the same entity. This is a new field for year 2010 eGRID data. 2. Plant State Abbreviation (PSTATABB) - This field contains the two character postal code abbreviation of the state in which the plant is located. Source: EIA-860 3. Plant Name (PNAME) - This field is the name associated with each plant. Source: EIA-860 + updates 4. 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. One plant code, that for Laramie River, has been altered. See Section 4 for details. Source: EIA-860 + updates Abt Associates TSD for the 9th Edition of eGRID | pg. 38 ------- DESCRIPTION OF DATA ELEMENTS 5. Boiler ID (BLRID) - This field identifies the unit ID for the unit that produces the emissions. The unit may be a steam boiler, combustion turbine, or engine. Sources: EPA/CAMD, EIA-923 6. Acid Rain Program Flag (ARPFLAG) - This field indicates if the unit reports EPA/CAMD emissions data annually under Title IV of the Clean Air Act Amendments of 1990 as part of the Acid Rain Program (l=Yes). Source: EPA/CAMD 7. Program Codes (PRGCODE) - This field lists, as reported to EPA/CAMD, the programs that the unit is subject to. Values may be combined and separated by commas. The individual values possible are: ARP =Acid Rain Program CAIRNOX =Clean Air Interstate Rule for NOx (annual) CAIRO S =Clean Air Interstate Rule for NOx (ozone season) CAIRS02 =Clean Air Interstate Rule for S02 NHNOX =New Hampshire's special NOx program RGGI =Regional Greenhouse Gas Initiative (C02) SIPNOX =NOx SIP Call See http://epa.gOv/airmarkets/progsregs/index.html#current for additional information. This field, beginning with year 2009 data, replaces the more limiting field, NBPFLAG, from earlier eGRID data years. Source: EPA/CAMD 8. Boiler Bottom and Firing Type (BOTFIRTY) - This field displays the boiler bottom type followed by the firing type. This field is based on the "best" data source display in field #24. Possible values are: For bottom type: = Blank DRY = Dry bottom WET = Wet bottom For firing type: ARCH CELL CONCEN/TANG CYCLONE DUCTBURNER FLUIDIZED = Blank = Arch firing = Cell = Concentric (tangentially-fired) = Cyclone firing = Duct burner = Fluidized bed firing Abt Associates TSD for the 9,h Edition of eGRI | .xt 39 ------- DESCRIPTION OF DATA ELEMENTS FRONT/WALL N/A OPPOS/WALL OTHER REAR/WALL SIDE/WALL STOKER TANGENTIAL TURBO VERTICAL WALL = Front firing (wall-fired) = Not available = Opposite firing (wall-fired) = Other = Rear firing (wall-firedO = Side firing (wall-fired) = Stoker (spreader) = Tangential firing = Turbo = Vertical firing = Wall firing Source: EPA/CAMD, EIA-860 9. Number of Associated Generators (NUMGEN) - This field provides the number of generators associated with each EIA-860 boiler in the file. Source: EIA-860 10. Boiler Primary Fuel (FUELB1) - This field specifies the primary fuel determined from EIA-923 boiler reported data or the primary fuel reported to EPA/CAMD. This field is based on the "best" data source display in field #24. Possible values are: AB = Agricultural byproduct BFG = Blast furnace gas BG = Butane gas BIT = Bituminous coal BLQ = Black liquor COG = Coke oven gas DFO = Distillate fuel oil, light fuel oil, F02, diesel oil DG = Digester gas (other biomass gas) HY = Hydrogen JF = Jet fuel KER = Kerosene LFG = Landfill gas LIG = Lignite coal MSB = Municipal solid waste biomass component NG = Natural gas OBS = Other biomass solid OG = Other gas 00 = Other oil OTH = Other PC = Petroleum coke PRG = Process gas RFO = Residual fuel oil, heavy fuel oil, petroleum RG = Refinery gas SC = Synthetic coal (syncoal) SLW = Sludge waste Abt Associates TSD for the 9,h Edition of eGRI | .xt 40 ------- DESCRIPTION OF DATA ELEMENTS SUB = Subbituminous coal TDF = Tire-derived fuel WC = Waste coal WDL = Wood, wood waste liquid WDS = Wood, wood waste solid WH = Waste heat WO = Waste oil Source: EPA/CAMD, EIA-923 11. Unit Operating Hours (HRSOP) - This field is the number of hours that an EPA/CAMD unit reported operating during the year. Source: EPA/CAMD 12. Boiler Unadjusted Annual EPA/CAMD Heat Input (HTIEAN) - This field, in MMBtu, is the unit's unadjusted annual total heat input assigned by EPA/CAMD, based on the values reported to EPA/CAMD. When not available, it is zero. Source: EPA/CAMD 13. Boiler Unadjusted Ozone Season EPA/CAMD Heat Input (HTIEOZ) - This field, in MMBtu, is the unit's unadjusted ozone season (May through September) heat input, based on the values reported to EPA/CAMD. When not available, it is zero. Source: EPA/CAMD 14. Boiler Unadjusted Annual Total EIA-Based Calculated Heat Input (HTIFAN) - This field, in MMBtu, provides the boiler's unadjusted annual total heat input, calculated using EIA-923 boiler data, when available. When not available, it is zero. Source: EIA-923 15. Boiler Unadjusted Ozone Season EIA-Based Calculated Heat Input (HTIFOZ) - This field, in MMBtu, provides the boiler's unadjusted ozone season (May through September) heat input, calculated using EIA-923 boiler data, when available. If EIA- 923 boiler ozone season data are not available, but EIA-923 boiler annual data are, then the value in this field is calculated as 5/12 of the annual value. Otherwise, the value is zero. Source: EIA-923 16. Boiler Unadjusted Annual EPA/CAMD NOx Emissions (NOXEAN) - This field, in short tons, is the unit's unadjusted NOx emissions assigned by EPA/CAMD based on the values reported to EPA/CAMD. When not available, it is zero. Source: EPA/CAMD Abt Associates TSD for the 9,h Edition of eGRI | .xt 41 ------- DESCRIPTION OF DATA ELEMENTS 17. Boiler Unadjusted Ozone Season EPA/CAMD NOx Emissions (NOXEOZ) - This field, in short tons, is the unit's unadjusted ozone season (May through September) NOx emissions based on values reported to EPA/CAMD. When not available, it is zero. Source: EPA/CAMD 18. Boiler Unadjusted Annual EIA-Based Calculated NOx Emissions (NOXFAN) - This field, in short tons, is the boiler's unadjusted annual NOx emissions calculated using EIA-923 boiler reported data, when available, and the EPA-approved EF. When not available, it is zero. Source: EIA-923 19. Boiler Unadjusted Ozone Season EIA-Based Calculated NOx Emissions (NOXFOZ) - This field, in short tons, is the boiler's unadjusted ozone season (May through September) NOx emissions calculated from EIA-923 boiler reported data and EPA- approved EF. If EIA-923 boiler ozone season data are not available, but EIA-923 annual data are, then the value in this field is calculated as 5/12 of the annual value. Otherwise, the value is zero. Source: EIA-923 20. Boiler Unadjusted Annual EPA/CAMD S02 Emissions (S02EAN) - This field, in short tons, is the unit's unadjusted annual S02 emissions assigned by EPA/CAMD and based on the values reported to EPA/CAMD. When not available, it is zero. Units that are NBP and not ARP do not report annual S02 emissions, so the emissions were estimated using fuel quantity (back calculated from reported EPA/CAMD heat input and average hear content) and the appropriate EPA-approved emission factor. Source: EPA/CAMD 21. Boiler Unadjusted Annual EIA-Based Calculated S02 Emissions (S02FAN) - This field, in short tons, is the boiler's unadjusted annual S02 emissions calculated using EIA-923 boiler reported data, when available, and the EPA-approved EF. When not available, it is zero. Source: EIA-923 22. Boiler Unadjusted Annual EPA/CAMD C02 Emissions (C02EAN) - This field, in short tons, is the unit's unadjusted annual C02 emissions assigned by EPA/CAMD based on the values reported to EPA/CAMD. Units that are NBP and not ARP do not report annual C02 emissions, so the emissions were estimated using reported EPA/CAMD heat input and the appropriate IPCC GHG carbon coefficient. When not available, it is zero. If the fuel for this boiler is biomass, the C02 emissions are assigned a zero value (see the Methodology Section for the rationale for biomass adjustments for C02). Source: EPA/CAMD Abt Associates TSD for the 9,h Edition of eGRI ^ | *42 ------- DESCRIPTION OF DATA ELEMENTS 23. Boiler Unadjusted Annual EIA-Based Calculated C02 Emissions (C02FAN) - This field, in short tons, is the boiler's unadjusted annual C02 emissions calculated using EIA-923 boiler reported data, when available, and IPCC GHG carbon coefficients. When not available, it is zero. If the fuel for this boiler is biomass, the C02 emissions are assigned a zero value (see the Methodology Section). Source: EIA-923 24. Source of "Best" Data from EPA/CAMD or EIA-923 Boiler Level (SRCBEST) - This field describes the one source of the "best" variables (HTIBAN, NOXBAN, S02BAN, C02BAN, HTIBOZ, NOXBOZ) - either EPA CAMD or EIA-923. 25. Boiler Unadjusted Annual Best Heat Input (HTIBAN) - This field, in MMBtu, contains the "best" unadjusted annual heat input value by taking HTIEAN as its value, if it exists; otherwise, HTIFAN's value is used. 26. Boiler Unadjusted Ozone Season Best Heat Input (HTIBOZ) - This field, in MMBtu, contains the "best" unadjusted ozone season (May through September) heat input value by taking HTIEOZ as its value, if it exists; otherwise, HTIFOZ's value is used. 27. Boiler Unadjusted Annual Best NOx Emissions (NOXBAN) - This field, in short tons, contains the "best" unadjusted annual NOx value by taking NOXEAN as its value, if it exists; otherwise NOXFAN's value is used. 28. Boiler Unadjusted Ozone Season Best NOx Emissions (NOXBOZ) - This field, in short tons, contains the "best" unadjusted ozone season (May through September) NOx value by taking NOXEOZ as its value, if it exists; otherwise NOXFOZ's value is used. 29. Boiler Unadjusted Annual Best S02 Emissions (S02BAN) - This field, in short tons, contains the "best" unadjusted annual S02 value by taking S02EAN as its value, if it exists; otherwise S02FAN's value is used. 30. Boiler Unadjusted Annual Best C02 Emissions (C02BAN) - This field, in short tons, contains the "best" unadjusted annual C02 value by taking C02EAN as its value, if it exists; otherwise C02FAN's value is used. 31. Boiler S02 (Scrubber) First Control Device (S02CTLDV) - This field contains the first reported S02 control device. Values may be combined and separated by commas. This field is based on the "best" data source display in field #24. Possible values are: = blank BR = Jet bubbling reactor CD = Circulating dry scrubber DA = Dual alkali Abt Associates TSD for the 9,h Edition of eGRI ^ | *43 ------- DESCRIPTION OF DATA ELEMENTS DL FGD = Dry lime flue gas desulfurization unit DSI = Dry sorbant injection DP = Dry powder injection type FBL = Fluidized bed MA = Mechanically aided type MO = Magnesium oxide OT = Other PA = Packed type SB = Sodium based SD = Spray dryer type SP = Spray type TR = Tray type VE = Venturi type WL FGD = Wet lime flue gas desulfurization unit WLS = Wet limestone Sources: EPA/CAMD, EIA-860 32. Boiler NOx First Control Device (NOXCTLDV) - This field contains the first reported NOx control device. Values may be combined and separated by commas. This field is based on the "best" data source display in field #24. Possible values are: = Blank AA = Advanced overfire air BF = Biased firing CF = Fluidized bed combustor CM = Combustion modification/fuel reburning DLNB = Dry low NOx premixed technology FR = Flue gas recirculation FU = Fuel reburning H20 = Water injection LA = Low excess air LNB or LN = 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 OFA LNC3 = Low NOx burner technology with close-coupled and separated overfire air LNCB = Low NOx burner technology for cell burners NA = Not applicable NH3 = Ammonia injection OFA or OV = Overfire air OT = Other SC = Slagging SCR or SR = Selective catalytic reduction SNCR or SN = Selective noncatalytic reduction ST or STM = Steam injection Sources: EPA/CAMD, EIA-860 Abt Associates TSD for the 9,h Edition of eGRI | .xt 44 ------- DESCRIPTION OF DATA ELEMENTS 33. Boiler Hg Activated Carbon Injected System Flag (HGCTLDV) - This field contains an activated carbon injection mercury control flag (l=Yes), based on EIA data. Source: EIA-860 34. Boiler Year On-Line (BLRYRONL) - The field provides the four digit boiler year on-line. This field is based on the "best" data source display in field #24. Source: EPA/CAMD, EIA-860 5.2 The GEN (Generator) File There are 15 variables in the second file, GEN, which contains generator level data. Note that summing the generator generation to the plant level may not result in the same values as the plant generation. This file includes generation from steam boilers and nuclear units in the EIA-923 and from those plant-prime movers in the EIA-923 that have only one generator in the EIA-860. The one new variable for this data year is the first one. 1. eGRID year 2010 File Generator Sequence Number (SEQGEN10) - The generator records in this year 2010 data file are sorted by state postal code 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 year 2009 eGRID file for the same entity. This is a new field for year 2010 eGRID data. 2. Plant State Abbreviation (PSTATABB) - This field contains the two character postal code abbreviation of the state in which the plant is located. Source: EIA-860 Plant Name (PNAME) - This field is the name associated with each plant. Source: EIA-860 + updates 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. One plant code, that for Laramie River, has been altered. See Section 4 for details. Source: EIA-860 + updates 5. Generator ID (GENID) - This field identifies the electrical generation unit (generator). In the majority of cases, there is a 1-to-l correspondence with the boiler ID if it is a steam generator. Sources: EIA-860 Abt Associates TSD for the 9,h Edition of eGRI | .xt 45 ------- DESCRIPTION OF DATA ELEMENTS 6. Number of Associated Boilers (NUMBLR) - This field provides the number of EIA-860 boilers associated with each generator in the file. Sources: EIA-860 7. Generator Status (GENSTAT) - This field indicates the reported generator status at the end of the given year. Possible values are: BU = Back-up 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) RE = Retired - no longer in service SB = Stand-by (long-term storage) TS = Testing, construction complete, but not yet in commercial operation V = Under constructions, 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 the data year or later). Source: EIA-860 8. Generator Prime Mover Type (PRMVR) - This field indicates 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 CS = Combined cycle - single shaft CT = Combined cycle combustion turbine FC = Fuel cell GT = Combustion (gas) turbine HY = Hydraulic turbine IC = Internal combustion (diesel) IG = Integrated gasification combustion turbine OT = Other turbine PS = Hydraulic turbine - reversible (pumped storage) PV = Photovoltaic ST = Steam turbine (boiler, nuclear, geothermal, and solar steam) WT = Wind turbine Source: EIA-860 Abt Associates TSD for the 9,h Edition of eGRI | .xt 46 ------- DESCRIPTION OF DATA ELEMENTS 9. Generator Primary Fuel (FUELG1) - This field indicates the potential primary fuel reported for the generator. Possible values are: AB = Agricultural byproduct BFG = Blast furnace gas BIT = Bituminous coal BLQ = Black liquor DFO = Distillate fuel oil, light fuel oil, F02, diesel DG = Digester gas (other biomass gas) GEO = Geothermal JF = Jet fuel KER = Kerosene LFG = Landfill gas LIG = Lignite coal MSB = Municipal solid waste biomass component MWH =Electricity NG = Natural gas NUC = Nuclear materiel OBL = Other biomass liquid OBS = Other biomass solid OG = Other gas OTH = Other unknown PC = Petroleum coke PUR = Purchased steam RFO = Residual fuel oil, heavy fuel oil, petroleum SC = Synthetic coal (syncoal) SGC =Syngas (coal derived) 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 WH = Waste heat WND = Wind WO = Waste oil Source: EIA-860 10. Generator Nameplate Capacity (NAMEPCAP) - This field indicates the nameplate capacity, in MW, of the generator. Source: EIA-860 11. Generator Capacity Factor (CFACT) - This field is calculated at the generator level: CFACT = (GENNTAN) / (NAMEPCAP * 8760). The value should be between 0 and 1 exclusive. However, there are outliers. Abt Associates TSD for the 9,h Edition of eGRI | .xt 47 ------- DESCRIPTION OF DATA ELEMENTS 12. Generator Annual Net Generation (GENNTAN) - This field is the reported net generation in MWh. Note that summing the net generation of the generators in a plant may not provide a value that is the same as the plant generation value, PLNGENAN, since the data sources are often different. Sources: EIA-923 13. Generator Ozone Season Net Generation (GENNTOZ) - This field is the generator five month ozone season (May through September) net generation in MWh. For plants that reported monthly data, it is based on monthly generator generation data. Otherwise, it is calculated as 5/12 of the annual value. Sources: EIA-923 14. Generation Data Source (GENERSRC) - This field describes the data source of the generator net generation data. The values are as follows: = Blank: no generator level data F923NK = EIA-923 nuclear unit F923NONK = EIA-923 only generator at that plant's prime mover F923 ST = EIA-923 ST unit 15. Generator Year On-Line (GENYRONL) - This field provides the four digit generator year on-line. Source: EIA-860 5.3 The PLNT (Plant) File There are 165 variables in PLNT. Some data may be outliers and should be viewed with caution. 1. eGRID year 2010 File Plant Sequence Number (SEQPLT10) - The plant records in this year 2010 data file are sorted by state postal code abbreviation, plant name, and boiler 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 year 2009 eGRID2012 file for the same entity. This is a new field for year 2010 eGRID data. 2. Plant State Abbreviation (PSTATABB) - This field contains the two character postal code abbreviation of the state in which the plant is located. Source: EIA-860 3. Plant Name (PNAME) - This field is the name associated with each plant. Source: EIA-860 + updates Abt Associates TSD for the 9th Edition of eGRID | pg. 48 ------- DESCRIPTION OF DATA ELEMENTS 4. 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. One plant code, that for Laramie River, has been altered. See Section 4 for details. Source: EIA-860 + updates 5. Plant EPA Facility Registry System FRS Identification Code (FRSID) - This field is the EPA Facility Registry System (FRS) code associated with the ORISPL. This field is blank for year 2010 data because of data inconsistencies. Source: EPA FRS 6. Plant Operator Name (OPRNAME) - The name associated with each operating company (EGC) is contained in this field. Source: EIA-860 7. Plant Operator ID (OPRCODE) - This field contains the operating company ID. Each operating company has a unique company code assigned by EIA, with some exceptions. Some operator names do not have associated codes assigned by EIA and are EPA-assigned. See Section 4 for details. Source: EIA-860 8. Utility Service Territory Name (UTLSRVNM) - This field contains the name of the owner of the transmission/distribution company/EGC, also known as the utility service territory (a utility company or EGC) [and previously known as the utility service area] in which the plant is located. See Section 4 for further details. Source: EIA-860 + updates 9. Utility Service Territory ID (UTLSRVID) - This field contains the unique ID code associated with the utility service territory name. Source: EIA-860 + updates 10. ID of the Operator's Parent Company (OPPRNUM) - This field contains the ID of the plant's operator's parent company, if it exists. It is zero otherwise. EIA did not assign IDs for most parent companies; thus, EPA assigned unique negative integer IDs beginning with -7001 as parent company IDs. It is zero for year 2010 data. 11. Name of the Operator's Parent Company (OPPRNAME) - This field contains the name of the plant's operator's parent company, if it exists. It is blank otherwise. It is blank for year 2010 data. Abt Associates TSD for the 9,h Edition of eGRI | .xt 49 ------- DESCRIPTION OF DATA ELEMENTS 12. Power Control Area Name (PCANAME) - This field contains the name of the power control area for the plant. The PCA is associated with the plant's eGRID subregion and NERC region. See the Methodology Section for further information about PCAs. Sources: NERC, EIA-861 + updates 13. Power Control Area ID (PCAID) - This field contains the ID of the power control area for the plant. See the Methodology Section for further information about PCAs. Sources: NERC, EIA-861 + updates 14. NERC Region Acronym (NERC) - This field contains the acronym for the NERC region in which the plant is located. The NERC region is associated with the plant's PCA and eGRID subregion. See the Methodology Section for further information about NERC regions. A representation of the eGRID NERC region map is included in Appendix B. Source: NERC 15. eGRID Subregion Acronym (SUBRGN) - This field contains the acronym for the eGRID subregion in which the plant is located. The eGRID subregion is associated with the plant's PCA and NERC region. See the Methodology Section for further information about eGRID subregions. A representation of the eGRID subregion map is included in Appendix B. Source: EPA 16. eGRID Subregion Name (SRNAME) - This field contains the name of the eGRID subregion in which the plant is located. See the Methodology Section for further information about eGRID subregions. Source: EPA 17. Plant associated ISO/RTO Territory (ISORTO) - This field contains 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, PIM, SPP, OTHER, or blank. Source: EIA-860 (2010) + updates 18. Plant FIPS State Code (FIPSST) - This field contains 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 (NIST, undated). Source: NIST based Abt Associates TSD for the 9,h Edition of eGRI | .xt 50 ------- DESCRIPTION OF DATA ELEMENTS 19. Plant FIPS County Code (FIPSCNTY) - This field contains 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 (NIST, undated). Source: NIST based 20. Plant County Name (CNTYNAME) - This field corresponds to FIPSST and contains the name of the county in which the plant is located. Source: EIA-860, EPA/CAMD 21. Plant Latitude (LAT) - This field contains the latitude, in degrees to four decimal places, associated with the plant. When not available, the plant's county centroid's y-coordinate is used. Source: EPA/CAMD, EIA + updates 22. Plant Longitude (LON) - This field contains the longitude, in degrees to four decimal places, associated with the plant. When not available, the plant's county centroid's x-coordinate is used. Source: EPA/CAMD, EIA + updates 23. County Centroid Flag (CCFLAG) - This field indicates if the plant's latitude and longitude (fields # 20 and #21) are based on the county centroid (1= county centroid used). 24. Number of Boilers (NUMBLR) - This field contains the number of operating boilers or turbines within a plant. Note that the meaning and sources of these data are different from the data element of the same name in the generator file. Source: EPA/CAMD, EIA-860 calculated 25. Number of Generators (NUMGEN) - This field contains the number of potentially operating generators within a plant. Note that the meaning and source of these data are different from the data element of the same name in the boiler file. Source: EIA-860 calculated 26. Plant combustion status (COMBUST) - This field contains the plant combustion status: Possible values are: 1= Combusts, 0 = No combustion, 0.5 = Partial combustion. 27. Plant Emissions Source(s) (SOURCEM) - This field describes the source(s) of emissions data for the plant. Values may be combined and separated by commas. Abt Associates TSD for the 9,h Edition of eGRI ^ | ~5T ------- DESCRIPTION OF DATA ELEMENTS Possible values are: = Blank: no emissions data EPA CAMD = NOx, S02, and C02 emissions reported to EPA's Emissions Tracking System/Continuous Emissions Monitoring System (EPA/CAMD) if in the ARP program; otherwise estimated by applying EPA-approved EF to EPA/CAMD data. CH4 and N20 emission estimated by applying EPA-approved EF to EPA/CAMD data. EIA-923 = NOx, S02, C02, CH4, and N20 emissions estimated by applying EPA-approved EF to EIA-923 boiler-level data. = NOx, S02, C02, CH4, and N20 emissions estimated by applying EIA-906 EPA-approved EF to EIA-923 plant-prime mover-level data. 28. Plant Primary Fuel (PLPRMFL) - This field contains the plant's primary fuel based on maximum heat input if the plant combusts any fuel or assignment if the plant does not combust any fuel. Possible values are: AB = Agricultural byproduct BFG = Blast furnace gas BG = Bagasse BIT = Bituminous coal BLQ = Black liquor COG = Coke oven gas DFO = Distillate fuel oil, light fuel oil, F02, diesel oil DG = Digester gas (other biomass gas) GEO = Geothermal steam HY = Hydrogen JF = Jet fuel KER = Kerosene LFG = Landfill gas LIG = Lignite coal MSB = Municipal solid waste biomass component NG = Natural gas NUC = Nuclear materiel OBL = Other biomass liquid OBS = Other biomass solid OG = Other gas 00 = Other oil check that it is not OOL OTH = Other (unknown) OTL = Other liquid OTS =Other solid PC = Petroleum coke PG = Propane gas/LPG PP = Paper pellets PRG = Process gas PUR = Purchased fuel (unknown) RFO = Residual fuel oil, heavy fuel oil, petroleum Abt Associates TSD for the 9,h Edition of eGRI ^ | ~52 ------- DESCRIPTION OF DATA ELEMENTS RG = Refinery gas SC = Synthetic coal (syncoal) SLW = Sludge waste SUB = Subbituminous coal SUN = Sun TDF = Tire-derived fuel WAT = Water WC = Waste coal WDL = Wood, wood waste liquid WDS = Wood, wood waste solid WH =Waste heat WND = Wind WO = Waste oil 29. Plant Primary Coal/Oil/Gas/Other Fossil Fuel Category (PLFUELCT) - The value of this field is "COAL" if PLPRMFL is derived from coal, "OIL" if it is derived from oil, "GAS" if it is derived from gas, or "OFSL" if it is other fossil. Fossil fuel refers to any naturally occurring organic fuel, such as petroleum, coal, and natural gas. See the Methodology Section for a complete list of fuel codes and categories. 30. Plant Primary Fuel Generation Category (PLPFGNCT) - This field contains the plant's primary fuel based on maximum net generation if the plant generates. Possible values are based on the 11 that are used for resource mix: COAL, OIL, GAS, NUCLEAR, HYDRO, BIOMASS, WIND, SOLAR, GEOTHERMAL, OTHRFOSL, and WSTHTOTP R (Other Unknown/Purchased/Waste Heat). 31. Flag indicating if the plant burned or generated any amount of coal (COALFLAG) - This field contains a flag to indicate if the plant burned or, if it has positive heat input and generated electricity from coal (1= Yes). If a plant has negative coal generation and no coal heat input for a given year, the coal flag does not have the value of 1; this condition is new for year 2010 data. 32. Plant Capacity Factor (CAPFAC) - This field contains 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 inclusive, there are outliers. 33. Plant Nameplate Capacity (NAMEPCAP) - This field contains the nameplate capacity of the plant, in MW. Source: EIA-860 summed Abt Associates TSD for the 9,h Edition of eGRI | .xt 53 ------- DESCRIPTION OF DATA ELEMENTS 34. Biogas/Biomass Plant Adjustment Flag (RMBMFLAG) - This field contains the biogas (landfill gas, digester gas)/biomass adjustment flag. A biomass facility's emissions reported in eGRID may be different from that reported in other EPA sources such as EPA/CAMD's emissions data. Possible values are: 7100 = Biomass adjustment for CAMD C02 See the Methodology Section for details.. 35. Combined Heat and Power (CHP) Plant Adjustment Flag (CHPFLAG) - This field contains a flag to indicate if the plant is a CHP facility (l=Yes). 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. For details, see the Methodology Section. Source: eGRID CHP list 36. CHP Plant Useful Thermal Output (USETHRMO) - This field, in MMBtu, contains the useful thermal output estimated for a CHP facility. Source: EIA-923 calculated 37. CHP Plant Power to Heat Ratio (PWRTOHT) - This field contains 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. There are outliers. 38. CHP Plant Electric Allocation Factor (ELCALLOC) - This field contains the CHP plant's decimal fraction of the emissions that is 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. See the Methodology Section for further information. 39. Plant Pumped Storage Flag (PSFLAG) - This field indicates if the plant has at least one pumped storage generator (1= Yes). Source: EIA-860 100 71 0 1 No biomass Biogas included Other biomass included Biogas adjustments for CAMD emissions Abt Associates TSD for the 9,h Edition of eGRI | .xt 54 ------- DESCRIPTION OF DATA ELEMENTS 40. Plant Annual Heat Input (PLHTIAN) - This field is the total annual heat input, in MMBtu, for the plant. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 41. Plant Ozone Season Heat Input (PLHTIOZ) - This field is the five month ozone season (May through September) heat input, in MWh, for the plant. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 42. Plant Annual Net Generation (PLNGENAN) - This field is the total reported annual net generation, in MWh, for the plant. Sources: EIA-923, EPA/CAMD calculated 43. Plant Ozone Season Net Generation (PLNGENOZ) - This field, in MWh, is the five month ozone season (May through September) net generation for the plant. Sources: EIA-923, EPA/CAMD calculated 44. Plant Annual NOx Emissions (PLNOXAN) - This field, in short tons, is the total annual NOx emissions for the plant. Biogas components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 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). See the Methodology Section for details. 45. Plant Ozone Season NOx Emissions (PLNOXOZ) - This field, in short tons, is the five month ozone season (May through September) NOx emissions for the plant. Biogas components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 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). See the Methodology Section for details. 46. Plant Annual S02 Emissions (PLS02AN) - This field, in short tons, is the total annual S02 emissions for the plant. Biogas components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 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). See the Methodology Section for details. Abt Associates TSD for the 9,h Edition of eGRI ^ | "SI* ------- DESCRIPTION OF DATA ELEMENTS 47. Plant Annual C02 Emissions (PLC02AN) - This field, in short tons, is the total annual C02 emissions for the plant. All estimated C02 emissions from biomass fuels are adjusted to zero. The biomass fuel components' C02 CAMD emissions are excluded (adjusted to zero) by the same biomass fuel component percentage as that in the EIA-923 for the adjusted C02 CAMD emissions; prior to year 2007, these emissions, if CAMD-reported, were only zeroed out if the primary fuel was a biomass fuel. 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). See the Methodology Section for details. 48. Plant Annual CH4 Emissions (PLCH4AN) - This field, in lbs, is the total annual CH4 emissions for the plant. Biogas biomass components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 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). See the Methodology Section for details. 49. Plant Annual N20 Emissions (PLN20AN) - This field, in lbs, is the total annual N20 emissions for the plant. Biogas biomass components are adjusted. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 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). See the Methodology Section for details. 50. Plant Annual C02 Equivalent Emissions (PLC02EQA) - This field, inshort tons, is the annual C02 equivalent emissions for the plant. This value is a universal standard of measurement. The GWPs from the second IPCC assessment are used per EPA for the calculation; the formula used is as follows: PLC02EQA = ((1* PLC02AN) + (21* PLCH4AN / 2000) + (310 * PLN20AN / 2000)). This value can be converted to metric tonnes by dividing by 1.1023. See the Methodology Section for details. 51. Plant Annual Hg Emissions (PLHGAN) - This field, in lbs, is the total annual Hg emissions for the plant. For CHP plants, the value is adjusted by the electric allocation factor. See the Methodology Section for details. 52. Plant Annual NOx Total Output Emission Rate (PLNOXRTA) - This field, in lb/MWh, is calculated as follows: PLNOXRTA = 2000 * (PLNOXAN / PLNGENAN). Abt Associates TSD for the 9,h Edition of eGRI | .xt 56 ------- 53, 54, 55, 56, 57, 58, 59, 60, 61, 62, 63, DESCRIPTION OF DATA ELEMENTS Plant Ozone Season NOx Total Output Emission Rate (PLNOXRTO) - This field, in lb/MWh, is calculated as follows: PLNOXRTO = 2000 * (PLNOXOZ / PLNGENOZ). Plant Annual S02 Total Output Emission Rate (PLS02RTA) - This field, in lb/MWh, is calculated as follows: PLS02RTA = 2000 * (PLS02AN / PLNGENAN). Plant Annual C02 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/GWh, is calculated as follows: PLCH4RTA = PLCH4AN / (PLNGENAN / 1000). Plant Annual N20 Total Output Emission Rate (PLN20RTA) - This field, in lb/GWh, is calculated as follows: PLN20RTA = PLN20AN / (PLNGENAN / 1000). Plant Annual C02 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) - This field, in lb/GWh, is calculated as follows: PLHGRTA = PLHGAN / (PLNGENAN / 1000). 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). Plant Annual S02 Input Emission Rate (PLS02RA) - This field, in lb/MMBtu, is calculated as follows: PLS02RA = 2000 * (PLS02AN / PLHTIAN). Plant Annual C02 Input Emission Rate (PLC02RA) - This field, in lb/MMBtu, is calculated as follows: PLC02RA = (2000 * (PLC02AN / PLHTIAN). TSD for the 9,h Edition of eGRI | .xt 57 ------- DESCRIPTION OF DATA ELEMENTS 64. Plant Annual Hg Input Emission Rate (PLHGRA) - This field, in lb/BBtu, is calculated as follows: PLHGRA = PLHGAN / (PLHTIAN / 1000). 65. Plant Annual NOx Combustion Output Emission Rate (PLNOXCRT) - This field, in lb/MWh, is calculated as follows: PLNOXCRT = 2000 * (PLNOXAN / PLGENACY). 66. Plant Ozone Season NOx Combustion Output Emission Rate (PLNOXCRO) - This field, in lb/MWh, is calculated as follows: PLNOXCRO = 2000 * (PLNOXOZ / ((PLGENACY * PLNGENOZ) / PLNGENAN)). 67. Plant Annual S02 Combustion Output Emission Rate (PLS02CRT) - This field, in lb/MWh, is calculated as follows: PLS02CRT = 2000 * (PLS02AN / PLGENACY). 68. Plant Annual C02 Combustion Output Emission Rate (PLC02CRT) - This field, in lb/MWh, is calculated as follows: PLC02CRT = 2000 * (PLC02AN / PLGENACY). 69. Plant Annual CH4 Combustion Output Emission Rate (PLCH4CRT) - This field, in lb/GWh, is calculated as follows: PLCH4CRT = PLCH4AN / (PLGENACY / 1000). 70. Plant Annual N20 Combustion Output Emission Rate (PLN20CRT) - This field, in lb/GWh, is calculated as follows: PLN20CRT = PLN20AN / (PLGENACY / 1000). 71. Plant Annual Hg Combustion Output Emission Rate (PLHGCRT) - This field, in lb/GWh, is calculated as follows: PLHGCRT = PLHGAN / (PLGENACY / 1000). 72. Plant Unadjusted Annual NOx Emissions (UNNOX) - This field, in short tons, is the total plant level unadjusted annual NOx emissions. See the Methodology Section for details. 73. Plant Unadjusted Ozone Season NOx Emissions (UNNOXOZ) - This field, in short tons, is the unadjusted five month ozone season (May through September) NOx emissions for the plant. See the Methodology Section for details. 74. Plant Unadjusted Annual S02 Emissions (UNS02) - This field, in short tons, is the total plant level unadjusted annual S02 emissions. See the Methodology Section for details. Abt Associates TSD for the 9,h Edition of eGRI | .xt 58 ------- DESCRIPTION OF DATA ELEMENTS 75. Plant Unadjusted Annual C02 Emissions (UNC02) - This field, in short tons, is the total plant level unadjusted annual C02 emissions. Beginning in year 2007, the biomass fuel components' C02 emissions will be included in the unadjusted C02 plant emissions. See the Methodology Section for details. 76. Plant Unadjusted Annual CH4 Emissions (UNCH4) - This field, in lbs, is the total plant level unadjusted annual CH4 emissions. See the Methodology Section for details. 77. Plant Unadjusted Annual N20 Emissions (UNN20) - This field, in lbs, is the total plant level unadjusted annual N20 emissions. See the Methodology Section for details. 78. Plant Unadjusted Annual Hg Emissions (UNHG) - This field, in lbs, is the total plant level unadjusted annual Hg emissions. Mercury emissions are reported for year 2002 for coal plants and for year 2000 for large municipal waste combustors, and for eGRID, are estimated for year 2005. See the Methodology Section for details. 79. Plant Unadjusted Annual Heat Input (UNHTI) - This field, in MMBtu, is the total plant level unadjusted annual heat input. See the Methodology Section for details. Sources: EPA/CAMD, EIA-923 80. Plant Unadjusted Ozone Season Heat Input (UNHTIOZ) - This field, in MMBtu, is the five month ozone season (May through September) heat input for the plant. See the Methodology Section for details. Sources: EPA/CAMD, EIA-923 81. Plant Nominal Heat Rate (PLHTRT) - This field, in Btu/kWh, contains the plant nominal heat rate for at least partially combusted plants. It is calculated as follows: PLHTRT = 1000 * (PLHTIAN / PLNGENAN) for combustion plants; and PLHTRT = 1000 * (PLHTIAN / PLGENACY) for partial combustion plants. For CHP plants, the value is, in effect, adjusted by the electric allocation factor, since the heat input has been adjusted. This field's definition was modified for eGRID2012 and retained in the ninth edition of eGRID. 82. Plant Annual Coal Net Generation (PLGENACL) - This field, in MWh, contains the plant annual net generation for coal. Fuel codes that are included in coal are BIT, SUB, LIG, WC, and SC. Abt Associates TSD for the 9,h Edition of eGRI | .xt 59 ------- DESCRIPTION OF DATA ELEMENTS 83. Plant Annual Oil Net Generation (PLGENAOL) - This field, in MWh, contains the plant annual net generation for oil. Fuel codes included in oil are DFO, JF, KER, 00, PC, RFO, RG, and WO. 84. Plant Annual Gas Net Generation (PLGENAGS) - This field, in MWh, contains the plant annual net generation for natural gas. Fuel codes included in gas are NG and PG. 85. Plant Annual Nuclear Net Generation (PLGENANC) - This field, in MWh, contains the plant annual net generation for nuclear if the fuel code is NUC. Note that one plant, North Anna, has both nuclear and hydro prime movers, but the greater generation is associated with nuclear 86. Plant Annual Hydro Net Generation (PLGENAHY) - This field, in MWh, contains the plant annual net generation for hydro if the fuel code is WAT. 87. Plant Annual Biomass Net Generation (PLGENABM) - This field, in MWh, contains the plant annual net generation 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. See the Methodology Section for more information. 88. Plant Annual Wind Net Generation (PLGENAWI) - This field, in MWh, contains the plant annual net generation for wind if the fuel code is WND. 89. Plant Annual Solar Net Generation (PLGENASO) - This field, in MWh, contains the plant annual net generation for solar if the fuel code is SUN. 90. Plant Annual Geothermal Net Generation (PLGENAGT) - This field, in MWh, contains the plant annual net generation for geothermal if the fuel code is GEO. 91. Plant Annual Other Fossil Net Generation (PLGENAOF) - This field, in MWh, contains the plant annual net generation 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. 92. Plant Annual Other Unknown/ Purchased Fuel Net Generation (PLGENAOP) - This field, in MWh, contains the plant annual net generation for other unknown/purchased if the fuel code is OTH or PUR or WH. Abt Associates TSD for the 9,h Edition of eGRI | .xt 60 ------- DESCRIPTION OF DATA ELEMENTS 93. Plant Annual Total Nonrenewables Net Generation (PLGENATN) - This field, in MWh, contains the annual total nonrenewables net generation 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. 94. Plant Annual Total Renewables Net Generation (PLGENATR) - This field, in MWh, contains the annual total renewables net generation 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. 95. Plant Annual Total Nonhydro Renewables Net Generation (PLGENATH) - This field, in MWh, contains the annual total nonhydro renewables net generation for the plant. This field is the sum of PLGENABM, PLGENAWI, PLGENASO, and PLGENAGT. 96. Plant Annual Total Combustion Net Generation (PLGENACY) - This field, in MWh, contains the annual total combustion net generation for the plant. This field is the sum of PLGENACL, PLGENAOL, PLGENAGS, PLGENAOF, PLGENABM, and PLGENAOP. 97. Plant Annual Total Noncombustion Net Generation (PLGENACN) - This field, in MWh, contains the annual total noncombustion net generation for the plant. This field is the sum of PLGENANC, PLGENAHY, PLGENAWI, PLGENASO, and PLGENAGT. 98. Plant Coal Generation Percent (PLCLPR) - This field, the coal resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLCLPR = 100 * (PLGENACL / PLNGENAN). 99. Plant Oil Generation Percent (PLOLPR) - This field, the oil resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLOLPR = 100 * (PLGENAOL / PLNGENAN). 100. Plant Gas Generation Percent (PLGSPR) - This field, the gas resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLGSPR = 100 * (PLGENAGS / PLNGENAN). Abt Associates TSD for the 9,h Edition of eGRI ^ | ~61 ------- DESCRIPTION OF DATA ELEMENTS 101. Plant Nuclear Generation Percent (PLNCPR) - This field, the nuclear resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLNCPR = 100 * (PLGENANC / PLNGENAN). 102. Plant Hydro Generation Percent (PLHYPR) - This field, the hydro resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLHYPR = 100 * (PLGENAHY / PLNGENAN). 103. Plant Biomass Generation Percent (PLBMPR) - This field, the biomass resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLBMPR = 100 * (PLGENABM / PLNGENAN). 104. Plant Wind Generation Percent (PLWIPR) - This field, the wind resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLWIPR = 100 * (PLGENAWI / PLNGENAN). 105. Plant Solar Generation Percent (PLSOPR) - This field, the solar resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLSOPR = 100 * (PLGENASO / PLNGENAN). 106. Plant Geothermal Generation Percent (PLGTPR) - This field, the geothermal resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLGTPR = 100 * (PLGENAGT / PLNGENAN). 107. Plant Other Fossil Generation Percent (PLOFPR) - This field, the other fossil resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLOFPR = 100 * (PLGENAOF / PLNGENAN). 108. Plant Other Unknown/Purchased Fuel Generation Percent (PLOPPR) - This field, the other unknown/purchased fuel/waste heat resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLOPPR = 100 * (PLGENAOP / PLNGENAN). 109. Plant Total Nonrenewables Generation Percent (PLTNPR) - This field, the total nonrenewables resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLTNPR = 100 * (PLGENATN / PLNGENAN). Abt Associates TSD for the 9,h Edition of eGRI ^ | ~62 ------- DESCRIPTION OF DATA ELEMENTS 110. Plant Total Renewables Generation Percent (PLTRPR) - This field, the total renewables resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLTRPR = 100 * (PLGENATR / PLNGENAN). 111. Plant Total Nonhydro Renewables Generation Percent (PLTHPR) - This field, the total nonhydro renewables resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLTHPR = 100 * (PLGENATH/PLNGENAN). 112. Plant Total Combustion Generation Percent (PLCYPR) - This field, the total combustion resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLCYPR = 100 * (PLGENACY / PLNGENAN). 113. Plant Total Noncombustion Generation Percent (PLCNPR) - This field, the total noncombustion resource mix expressed as a percent of plant annual net generation, is calculated as follows: PLCNPR = 100 * (PLGENACN / PLNGENAN). 114. Plant Owner Name (First) (OWNRNM01) - This field contains the name of the first plant owner, a company or EGC. Sources: EIA-860 115. Plant Owner Code (First) (OWNRUC01) - This field contains the unique company code associated with OWNRNMO1 and assigned by EIA, with some exceptions. Some owner names do not have associated codes assigned by EIA and are EPA-assigned. If no information on ownership is provided, then it is assumed that the operator has 100% ownership. See the Methodology Section and Section 4 for details. Source: EIA-860 116. Plant Owner Percent (First) (OWNRPR01) - This field contains the percent of the plant that is owned by OWNRNMO 1. It is calculated based on reported generator ownership data. If no information on ownership is provided, then it is assumed that the operator has 100% ownership. See the Methodology Section and Section 4 for details. Source: EIA-860 117. Plant Owner Name (Second) (OWNRNM02) - This field contains the name of the second plant owner. Source: EIA-860 Abt Associates TSD for the 9,h Edition of eGRI | .xt 63 ------- DESCRIPTION OF DATA ELEMENTS 118. Plant Owner Code (Second) (OWNRUC02) - This field contains the unique EIA-assigned number associated with OWNRNM02. Some owner names do not have associated codes assigned by EIA and are EPA- assigned. If no information on ownership is provided, then it is assumed that the operator has 100% ownership. See the Methodology Section and Section 4 for details. Source: EIA-860 119. Plant Owner Percent (Second) (OWNRPR02) - This field contains the percent of the plant that is owned by OWNRNM02. It is calculated based on reported generator ownership data. Some owner names do not have associated codes assigned by EIA and are EPA- assigned. If no information on ownership is provided, then it is assumed that the operator has 100% ownership. See the Methodology Section and Section 4 for details. Source: EIA-860. 120. - Plant Owner Name, Plant Owner Code, and Plant Owner Percent (Third - 161. Sixteenth) - The description of these fields contains the information for the third through sixteenth plant owners. See the descriptions in fields #113 through #115 above. Source: EIA-860 162. eGRID2006 year 2004 File Plant Sequence Number (SEQPLT04) - This field contains the sequence number of the plant in the year 2004 data, if one exists. This sequence number is unlikely to be the same as the sequence number in the year 2005 eGRID2007 file for the same plant. 163. eGRID2007 year 2005 File Plant Sequence Number (SEQPLT05) - This field contains the sequence number of the plant in the year 2005 data, if one exists. This sequence number is unlikely to be the same as the sequence number in the year 2007 eGRID2010 file for the same plant. 164. eGRID2010 year 2007 File Plant Sequence Number (SEQPLT07) - This field contains the sequence number of the plant in the year 2007 data, if one exists. This sequence number is unlikely to be the same as the sequence number in the year 2009 eGRID2012 file for the same plant. 165. eGRID2012 year 2009 File Plant Sequence Number (SEQPLT09) - This field contains the sequence number of the plant in the year 2009 data, if one exists. This sequence number is unlikely to be the same as the year 2010 sequence number (SEQPLT10) for the same plant. Abt Associates TSD for the 9,h Edition of eGRI | .xt 64 ------- DESCRIPTION OF DATA ELEMENTS 5.4 The ST (State) File There are 111 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. 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-described. Aggregated variable names generally begin with "ST." The one new variable for this data year is the first one. 1. eGRID year 2010 File State Sequence Number (SEQST10) - The state records in this year 2010 data file are sorted by state postal code abbreviation and are assigned a unique sequential number beginning with 1. This is a new field for year 2010 eGRID data. 2. State Abbreviation (PSTATABB) - 3. FIPS State Code (FIPSST) - 4. State Nameplate Capacity (NAMEPCAP) - 5. State Annual Heat Input (STHTIAN) - 6. State Ozone Season Heat Input (STHTIOZ) - 7. State Annual Net Generation (STNGENAN) - 8. State Ozone Season Net Generation (STNGENOZ) - 9. State Annual NOx Emissions (STNOXAN) - 10. State Ozone Season NOx Emissions (STNOXOZ) - 11. State Annual S02 Emissions (STS02AN) - 12. State Annual C02 Emissions (STC02AN) - 13. State Annual CH4 Emissions (STCH4AN) - 14. State Annual N20 Emissions (STN20AN) - 15. State Annual C02 Equivalent Emissions (STC02EQA) - This field, in short tons, is the sum of each state's plants' PLC02EQA. 16. State Annual Hg Emissions (STHGAN) - Abt Associates TSD for the 9,h Edition of eGRI ^ | ~65 ------- 17, 18, 19, 20, 21, 22, 23, 24, 25, 26, 27, DESCRIPTION OF DATA ELEMENTS 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 S02 Total Output Emission Rate (STS02RTA) - This field, in lb/MWh, is calculated as follows: STS02RTA = 2000 * (STS02AN / STNGENAN). State Annual C02 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/GWh, is calculated as follows: STHCH4RTA = STCH4AN / (STNGENAN / 1000). State Annual N20 Total Output Emission Rate (STN20RTA) - This field, in lb/GWh, is calculated as follows: STN20RTA = STN20AN / (STNGENAN / 1000). State Annual C02 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) - This field, in lb/GWh, is calculated as follows: STHGRTA = STHGAN / (STNGENAN / 1000). 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 S02 Input Emission Rate (STS02RA) - This field, in lb/MMBtu, is calculated as follows: STS02RA = 2000 * (STS02AN / STHTIAN). TSD for the 9,h Edition of eGRI | .xt 66 ------- DESCRIPTION OF DATA ELEMENTS 28. State Annual C02 Input Emission Rate (STC02RA) - This field, in lb/MMBtu, is calculated as follows: STC02RA = 2000 * (STC02AN / STHTIAN). 29. State Annual Hg Input Emission Rate (STHGRA) - This field, in lb/BBtu, is calculated as follows: STHGRA = STHGAN / (STHTIAN / 1000). 30. State Annual NOx Combustion Output Emission Rate (STNOXCRT) - This field, in lb/MMBtu, is calculated as follows: STNOXCRT =2000 * (STNOXAN / STGENACY). 31. State Ozone Season NOx Combustion Output Emission Rate (STNOXCRO) - This field, in lb/MMBtu, is calculated as follows: STNOXCRO = 2000 * (STNOXOZ / ((STGENACY* STNGENOZ)/STNGENAN)). 32. State Annual S02 Combustion Output Emission Rate (STS02CRT) - This field, in lb/MMBtu, is calculated as follows: STS02CRT = 2000 * (STS02AN / STGENACY). 33. State Annual C02 Combustion Output Emission Rate (STC02CRT) - This field, in lb/MMBtu, is calculated as follows: STC02CRT = 2000 * (STC02AN / STGENACY). 34. State Annual CH4 Combustion Output Emission Rate (STCH4CRT) - This field, in lb/BBtu, is calculated as follows: STCH4CRT = STCH4AN / (STGENACY / 1000). 35. State Annual N20 Combustion Output Emission Rate (STN20CRT) - This field, in lb/BBtu, is calculated as follows: STN20CRT = STN20AN / (STGENACY / 1000). 36. State Annual Hg Combustion Output Emission Rate (STHGCRT) - This field, in lb/BBtu, is calculated as follows: STHGCRT = STHGAN / (STGENACY / 1000). 37. State Annual NOx Coal Output Emission Rate (STCNOXRT) - This field, in lb/MWh, is calculated as the sum of the annual NOx emissions from all plants in the state that have coal as its 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. The methodology is new, beginning with year 2009 data, for all the fuel-based output emission rates. Abt Associates TSD for the 9,h Edition of eGRI | .xt 67 ------- DESCRIPTION OF DATA ELEMENTS 38. State Annual NOx Oil Output Emission Rate (STONOXRT) - This field, in lb/MWh, is calculated as the sum of the annual NOx emissions from all plants in the state that have oil as its 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. The methodology is new, beginning with year 2009 data, for all the fuel-based output emission rates. 39. State Annual NOx Gas Output Emission Rate (STGNOXRT) - This field, in lb/MWh, is calculated as the sum of the annual NOx emissions from all plants in the state that have natural gas as its 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. The methodology is new, beginning with year 2009 data, for all the fuel-based output emission rates. 40. State Annual NOx Fossil Fuel Output Emission Rate (STFSNXRT) - This field, in lb/MWh, is calculated as the sum of the annual NOx emissions from all plants in the state that have a fossil fuel (coal, oil, gas, or other fossil) as its 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. The methodology is new, beginning with year 2009 data, for all the fuel-based output emission rates. 41. - State Ozone Season NOx Coal, Oil, Gas, and Fossil Fuel Output Emission Rates- 44. The descriptions of these fields, in lb/MWh, contain the same information for ozone season NOx as fields #37 through #40, respectively, do for annual NOx. The state ozone season combustion net generation, used in the denominator of the equations used to calculate these state fuel-based output emission rates is calculated as the ratio of the state annual to ozone season net generation for that fuel times the state annual combustion net generation. The methodology is new, beginning with year 2009 data, for all the fuel-based output emission rates. 45. - State Annual S02 Coal, Oil, Gas, and Fossil Fuel Output Emission Rates - 48. The descriptions of these fields, in lb/MWh, contain the same information for annual S02 as fields #37 through #40, respectively, do for annual NOx. 49. - State Annual C02 Coal, Oil, Gas, and Fossil Fuel Output Emission Rates - 52. The descriptions of these fields, in lb/MWh, contain the same information for annual C02 as fields #37 through #40, respectively, do for annual NOx. 53. - State Annual Hg Coal and Fossil Fuel Output Emission Rates - 54. The descriptions of these fields, in lb/GWh, contain the same information for annual Hg as fields #37 and #40, respectively, do for annual NOx. Abt Associates TSD for the 9,h Edition of eGRI ^ | **68 ------- DESCRIPTION OF DATA ELEMENTS 55. - State Annual NOx, Ozone Season NOx, Annual S02, Annual C02 Coal, Oil, Gas, 72. and Fossil Fuel Input Emission Rates; and Annual Hg Coal and Fossil Fuel Input Emission Rates - The description of these fields, primary fuel-specific input emission rates, contains the same information that fields #37 through #54 do for primary fuel-specific output emission rates - except that the calculations include heat input, rather than net generation. Note that for Hg input emission rates, the units are lb/BBtu, not lb/MMBtu. These values are calculated in the same manner as are any input emission rates. 73. State Annual NOx Non-baseload Output Emission Rate (STNBNOX) - This field, in lb/MWh, is the sum of the annual non-baseload NOx emissions divided by the sum of annual non-baseload net generation in the state and then multiplied by a unit conversion factor. This field is intended to provide a more refined estimate of avoided emissions than the fossil-fuel average output emission rate. The non- baseload 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 the Methodology Section. 74. State Ozone Season NOx Non-baseload Output Emission Rate (STNBNXO) - The description of this field, in lb/MWh, contains the same information as field #73 does, but for the ozone season. 75. State Annual S02 Non-baseload Output Emission Rate (STNBS02) - The description of this field, as well as fields #76 through #79, in lb/MWh, contain the same information as field #73 does, but for the appropriate pollutant. 76. State Annual C02 Non-baseload Output Emission Rate (STNBC02) - 77. State Annual CH4 Non-baseload Output Emission Rate (STNBCH4) - 78. State Annual N20 Non-baseload Output Emission Rate (STNBN20) - 79. State Annual Hg Non-baseload Output Emission Rate (STNBHG) - 80. State Annual Coal Net Generation (STGENACL) - 81. State Annual Oil Net Generation (STGENAOL) - 82. State Annual Gas Net Generation (STGENAGS) - 83. State Annual Nuclear Net Generation (STGENANC) - 84. State Annual Hydro Net Generation (STGENAHY) - Abt Associates TSD for the 9,h Edition of eGRI ^ | ~69 ------- DESCRIPTION OF DATA ELEMENTS 85. State Annual Biomass Net Generation (STGENABM) - 86. State Annual Wind Net Generation (STGENAWI) - 87. State Annual Solar Net Generation (STGENASO) - 88. State Annual Geothermal Net Generation (STGENAGT) - 89. State Annual Other Fossil Net Generation (STGENAOF) - 90. State Annual Other Unknown/Purchased Fuel Net Generation (STGENAOP) - 91. State Annual Total Nonrenewables Net Generation (STGENATN) - 92. State Annual Total Renewables Net Generation (STGENATR) - 93. State Annual Total Nonhydro Renewables Net Generation (STGENATH) - 94. State Annual Total Combustion Net Generation (STGENACY) - 95. State Annual Total Noncombustion Net Generation (STGENACN) - 96. State Coal Generation Percent (STCLPR) - 97. State Oil Generation Percent (STOLPR) - 98. State Gas Generation Percent (STGSPR) - 99. State Nuclear Generation Percent (STNCPR) - 100. State Hydro Generation Percent (STHYPR) - 101. State Biomass Generation Percent (STBMPR) - 102. State Wind Generation Percent (STWIPR) - 103. State Solar Generation Percent (STSOPR) - 104. State Geothermal Generation Percent (STGTPR) - 105. State Other Fossil Generation Percent (STOFPR) - 106. State Other Unknown/Purchased Fuel Generation Percent (STOPPR) - 107. State Total Nonrenewables Generation Percent (STTNPR) - Abt Associates TSD for the 9,h Edition of eGRif | .xt 70 ------- DESCRIPTION OF DATA ELEMENTS 108. State Total Renewables Generation Percent (STTRPR) - 109. State Total Nonhydro Renewables Generation Percent (STTHPR) - 110. State Total Combustion Generation Percent (STCYPR) - 111. State Total Noncombustion Generation Percent (STCNPR) - 5.5 The PCAL (PCA) File There are 111 variables in the fifth file, PCAL, which contains location (operator)-based power control area (PCA) data. All generation and emission values are derived by aggregating from the plant level based on the associated PCA. The one new variable for this data year is the year 2010 sequence number. All other variables have been described in previous file variable descriptions. Aggregated variable names generally begin with "PC" 5.6 The SRL (eGRID Subregion) File There are 113 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. The one new variable for this data year is the year 2010 sequence number. All other variables have been described in previous file variable descriptions. Aggregated variable names generally begin with "SR." 5.7 The NRL (NERC Region) File There are 111 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 3.5.1). The other new variable for this data year is the year 2010 sequence number. Aggregated variable names generally begin with "NR." 5.8 The US (U.S.) File There are 109 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. The one new variable for this data year is the year 2010 sequence number. All other variables have been described in previous file variable descriptions. Aggregated variable names generally begin with "US." Abt Associates TSD for the 9,h Edition of eGRI | .xt 71 ------- DESCRIPTION OF DATA ELEMENTS 5.9 The Regional Grid Gross Loss File There are seven variables in this newly added ninth file, GGL, for year 2010 data. 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 = GHG emis rate = Consumption = Ggl% a specified GHG emission associated with a certain amount of electricity consumption (generation and line losses) 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. 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: GHG emis 11 = GHG emis rate * Consumption * (ggl%/100) / (l-ggl%/100)/2000; where GHG emis 11 = a specified GHG emission associated with the line losses of a certain amount of electricity consumption 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. The variables in the regional grid gross loss file are as follows: 1. REGION- This field is one of the three interconnect power grids in the U.S. (plus Alaska, Hawaii, and the entire U.S.) 2. GENERAT - The field is the regional total net generation in MWh. These data originally are at the PCA level plus MISO and are subsequently summed to the power grid region. Source: 2010 FERC-714, eGRID year 2010 net generation (for Alaska and Hawaii) Abt Associates TSD for the 9,h Edition of eGRI | .xt 72 ------- DESCRIPTION OF DATA ELEMENTS 3. FRGNINTC - This field is the regional total net interchange in MWh with Canada and Mexico. These data originally are at the PCA level plus MISO and are subsequently summed to the power grid region. Note that imports will have a positive value. Source: 2010 FERC-714 updated by EIA 4. INTRCHNG - This field is the regional total net interchange (= generation imported - generation exported) in MWh with a different U.S. region. These data originally are at the PCA level plus MISO and are subsequently summed to the power grid region. Note that imports will have a positive value. Source: 2010 FERC-714 + updates 5 CONSUMP - This field is the regional total consumption in MWh. Consumption is the sum of total retail sales to ultimate customers, energy furnished without charge, and energy consumed by the respondent without charge. These data, originally at the utility service territory level, are subsequently summed to the power grid region. Source: 2010 EIA-861 Files 1 and 2 + updates 6. GGRSLOSS - This field is the estimated grid gross loss as a percent. The algorithm used is GGRLOSS = (100 * (GENERAT + FRGNINTC + INTRCHNG - CONSUMP) / GENERAT). The grid gross loss values are also included in Table 3-5. 7. YEAR- This field is the year of data. Abt Associates TSD for the 9,h Edition of eGRI | .xt 73 ------- REFERENCES 6. References Brighter Planet, 2010: Brighter Planet, Electricity Use carbon model, 2010. http://impact.brighterplanet.com/?r= 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, 2012: Carbon Visuals, Carbon Footprint Visualizations, October, 2012. http://www.carbonvisuals.com/media/item/348/310/A-set-of-US-reference-images-methodology- v2.pdf 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, 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/session3/adiem.pdf http://www.epa.gOv/ttn/chief/conference/ei20/index.html#ses-3 DVRPC, 2010: Delaware Valley Regional Planning Commission, Regional Greenhouse Gas Emissions Inventory, revised December 2010. http://www.dvrpc.org/reports/09038A.pdf DOE, 2003: U.S. Department of Energy, Gas-Fired Distributed Energy Resource Technology Characterizations, November 2003. http: //www .nrel. gov/docs/fV04osti/34783 .pdf EEA, 2011 updated: Energy and Environmental Analysis, an ICF International Company, "Combined Heat and Power Installation Database, maintained for DOE ORNL.' Washington, DC, 2011, updated. http://www.eea-inc.com/chpdata/index.html EIA, 2000: Energy Information Administration, The Main Interconnections of the U.S. Electric Power Grid and the 10 North American Electric Reliability Council Regions in "The Changing Structure of the Electric Power Industry 2000: An Update (Figure 7)", October 2000. http://www.eia.gov/electricitv/archive/05620Q.pdf EIA, 2007: Energy Information Administration. Methodology for Allocating Municipal Solid Waste to Biogenic and Non-Biogenic Energy, Tables B1 and B2. Tables and updates based on EIA-EPA email exchanges from October 23, 2007 through November 15, 2007. http://www.eia.gov/totalenergv/data/monthlv/pdf/historical/msw.pdf Abt Associates TSD for the 9th Edition of eGRID | pg. 74 ------- REFERENCES EIA, 201 la: Energy Information Administration, "2010 Annual Electric Power Industry Report," Form EIA-861, Washington, DC, 2011. http://www.eia.gov/cneaf/electricitv/page/eia861 .html EIA, 201 lb: Energy Information Administration, "2010 Power Plant Operations Report," Form EIA- 923, Washington, DC, 2011. http://www.eia.gov/cneaf/electricitv/page/eia906 920.html EIA, 2012: Energy Information Administration, "2010 Annual Electric Generator Report," Form EIA-860, Washington, DC, 2012. http://www.eia.gov/cneaf/electricitv/page/eia860.html EIA, 2013: Energy Information Administration - Assumptions to the Annual Energy Outlook 2013, Electricity Market Module Supply Regions of the Electricity Market Module Report (Figure 6), Washington, DC, 2013. http://www.eia.gov/forecasts/aeo/assumptions/pdf/electricitv.pdf EPA, 2002: U.S. Environmental Protection Agency, "Large Municipal Waste Combustor 2000 Database," 2002. EPA, 2009: U.S. Environmental Protection Agency, Final Mandatory Reporting of Greenhouse Gases Rule (Table C-l, Default C02 Emission Factors and High Heat Values for Various Types of Fuel and Table C-2, Default CH4 and N20 Emission Factors for Various Types of Fuel), Washington, D C., October 30, 2009. http://www.epa.gov/ghgreporting/documents/pdf/2009/GHG-MRR-FinalRule.pdf EPA, 2011: U.S. Environmental Protection Agency, Apps for the Environment, November 2011. http://www.epa.gov/appsfortheenvironment/ EPA, 2012a: U.S. Environmental Protection Agency, Compilation of Air Pollutant Emission Factors, AP-42 - uncontrolled criteria pollutant emission factors (EF) with EPA-approved updates, February 2012. EPA, 2012b: U.S. Environmental Protection Agency, 2010 Annual and Ozone Season EPA/CAMD database, Washington, DC, downloaded December 31, 2012 from http: //ampd. epa. gov/ampd/ EPA, 2013: U.S. Environmental Protection Agency, Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2011, Washington, D.C., April 2013. http://epa.gov/climatechange/emissions/usinventorvreport.html EPA, undatedl: U.S. Environmental Protection Agency's EPA CHP Partnership, Catalogue of CHP Technologies. http://www.epa.gov/chp/documents/catalog chptech full.pdf (updated link) EPA, undated2: U.S. Environmental Protection Agency, RACT/BACT/LAER Clearinghouse. Washington, DC. http://cfbub 1 .epa.gov/RBLC/ Abt Associates TSD for the 9,h Edition of eGRI ^ | *75 ------- REFERENCES FERC, 2011: Federal Energy Regulatory Commission, Form FERC-714 year 2010 data. Obtained from FERC's website. Galvin, 2011: Galvin Electricity Initiative, Perfect Power Seal of Approval: Metrics and Scoring System (beta version), http://www.galvinpower.org/sealofapproval. April 20, 2011. 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, 2013: Geothermal Energy Association, geothermal generator type from state-plant information displayed on the website, http://www.geo-energy.org/. Washington, D.C., August 2013. IPCC, 2007: 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 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 C02 Budget Training Program, Baltimore, MD, October 25, 2010. http: //www .mde. state ,md .us/aboutmde/AboutMDEHome/Documents/RGGI-VERSA TSD. PDF NERC, 2012: North American Electric Reliability Corporation, NERC Regions map, http: //buildingsdatabook. eren. doe. gov/T able View. aspx?table=6.2.8 NERC, 2013: "NERC Active Compliance Registry Matrix as of 10/30/2013" Excel spreadsheet. Downloaded NERC_Compliance_Registry_Matrix_Excel20131030.xls from http://www.nerc.com/pa/comp/Pages/Registration-and-Certification.aspx. NIST, undated: National Institute of Standards and Technology, Federal Information Processing Standards Publications. http://www.itl.nist.gov/fipspubs/index.htm. TCR, 2012: The Climate Registry updated emission factor file, January 6, 2012. TS|Pechan, 2003: TranSystems|E.H. Pechan, "The Emissions & Generation Resource Integrated Database for 2002 (eGRID2002) Version 2.1 Users Manual," prepared for the U.S. Environmental Protection Agency, Acid Rain Division, Washington, DC, April 2003. TS|Pechan, 2009: TranSystems|E.H. Pechan, "The Emissions & Generation Resource Integrated Database eGRIDweb Version 1.0 Users Manual," prepared for U.S. Environmental Protection Agency, Washington, DC, April 2009. Abt Associates TSD for the 9,h Edition of eGRI | .xt 76 ------- REFERENCES 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 Ventyx, 2007: Ventyx' Global Energy Decisions' Velocity Suites 2006 data, downloaded on atrial basis with company permission, October-November 2007. WECC, 2007: "Existing Generation and Significant Additions and Changes to System Facilities (2006 -2016) Data as of January 1, 2007," prepared by WECC staff, downloaded as SIGADD07Final.pdf on May 18, 2010 at http://www.wecc.biz/committees/StandingCommittees/PCC/LRS/Shared%20Documents/LRS%2 OReports/Y ear%202007/SIGADD07Final.pdf. Wheeler, 2007: David Wheeler, Senior Fellow, Center for Global Development, CARMA developer, personal communication, November 30, 2007. Abt Associates TSD for the 9,h Edition of eGRI | .xt 77 ------- APPENDIX A Appendix A. eGRID File Structure - Variable Descriptions for 2010 Data Year The eGRID year 2010 data are initially in database format and are then transformed into Excel spreadsheets. The structure of the nine database 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. Table A-1. eGRID File Structure, Year 2010 BLR Boiler File* Field Name Description Unit Source(s) 1 SEQBLR10 eGRID year 2010 file boiler sequence number 2 PSTATABB Plant state abbreviation EIA-860 3 PNAME Plant name EIA-860 + updates 4 ORISPL DOE/EIA ORIS plant or facility code EIA-860 + updates 5 BLRID Boiler ID EPA/CAMD, EIA-923 6 ARPFLAG Acid Rain Program flag: 1 = Yes EPA/CAMD 7 PRGCODE Program code(s) EPA/CAMD 8 BOTFIRTY Boiler bottom and firing type EPA/CAMD, EIA-860 9 NUMGEN Number of associated generators EIA-860 10 FUELB1 Boiler primary fuel EPA/CAMD, EIA-923 11 HRSOP Unit operating hours hours EPA/CAMD 12 HTIEAN Boiler unadjusted annual EPA/CAMD heat input MMBtu EPA/CAMD 13 HTIEOZ Boiler unadjusted ozone season EPA/CAMD heat input MMBtu EPA/CAMD 14 HTIFAN Boiler unadjusted annual total ElA-based calculated heat input MMBtu EIA-923 15 HTIFOZ Boiler unadjusted ozone season ElA-based calculated heat input MMBtu EIA-923 16 NOXEAN Boiler unadjusted annual EPA/CAMD NOx emissions tons EPA/CAMD 17 NOXEOZ Boiler unadjusted ozone season EPA/CAMD NOx emissions tons EPA/CAMD 18 NOXFAN Boiler unadjusted annual ElA-based calculated NOx emissions tons EIA-923 19 NOXFOZ Boiler unadjusted ozone season ElA-based calculated NOx emissions tons EIA-923 20 S02EAN Boiler unadjusted annual EPA/CAMD S02 emissions tons EPA/CAMD 21 S02FAN Boiler unadjusted annual ElA-based calculated S02 emissions tons EIA-923 22 C02EAN Boiler unadjusted annual EPA/CAMD C02 emissions tons EPA/CAMD 23 C02FAN Boiler unadjusted annual ElA-based calculated C02 emissions tons EIA-923 24 SRCBEST Source of "best" data from EPA/CAMD or EIA-923 boiler level 25 HTIBAN Boiler unadjusted annual best heat input MMBtu 26 HTIBOZ Boiler unadjusted ozone season best heat input MMBtu 27 NOXBAN Boiler unadjusted annual best NOx emissions tons 28 NOXBOZ Boiler unadjusted ozone season best NOx emissions tons 29 S02BAN Boiler unadjusted annual best S02 emissions tons 30 C02BAN Boiler unadjusted annual best C02 emissions tons 31 S02CTLDV Boiler S02 (scrubber) first control device EPA/CAMD, EIA-860 32 NOXCTLDV Boiler NOx first control device EPA/CAMD, EIA-860 33 HGCTLDV Boiler Hg activated carbon injection system flag: 1 = Yes EIA-860 34 BLRYRONL Boiler year on-line EPA/CAMD, EIA-860 *Note that summing the boiler unadjusted emissions to the plant level may not result in the same values as the plant unadjusted emissions since additional emissions from prime movers not covered by the EPA/CAMD or EIA-923 boiler level data may be included in the plant emissions values. Abt Associates TSD for the 9th Edition of eGRID | pg. 78 ------- APPENDIX A Table A-2. eGRID File Structure, Year 2010 GEN Generator File** Field Name Description Unit Source(s) 1 SEQGEN10 eGRID year 2010 file generator sequence number 2 PSTATABB Plant state abbreviation EIA-860 3 PNAME Plant name EIA-860 + updates 4 ORISPL DOE/EIA ORIS plant or facility code EIA-860 + updates 5 GENID Generator ID EIA-860 6 NUMBLR Number of associated boilers EIA-860 7 GENSTAT Generator status EIA-860 8 PRMVR Generator prime mover type EIA-860 9 FUELG1 Generator primary fuel EIA-860 10 NAMEPCAP Generator nameplate capacity MW EIA-860 11 CFACT Generator capacity factor 12 GENNTAN Generator annual net generation MWh EIA-923 13 GENNTOZ Generator ozone season net generation MWh EIA-923 14 GENERSRC Generation data source 15 GENYRONL Generator year on-line EIA-860 "Note that summing the generator generation to the plant level may not result in the same values as the plant generation. This file includes generation from nuclear units in the EIA-923, steam generators in the unit-level EIA-923, and those plant-prime movers in the EIA-923 that have only one generator in the EIA-860. Abt Associates TSD for the 9,h Edition of eGRI | .xt 79 ------- APPENDIX A Table A-3. eGRID File Structure, Year 2010 PLNT Plant File Field Name Description Unit Source(s) 1 SEQPLT10 eGRID year 2010 file plant sequence number 2 PSTATABB Plant state abbreviation EIA-860 3 PNAME Plant name EIA-860 + updates 4 ORISPL DOE/EIA ORIS plant or facility code EIA-860 + updates 5 FRSID Plant EPA Facility Registry System (FRS) identification code EPA FRS 6 OPRNAME Plant operator name EIA-860 7 OPRCODE Plant operator ID EIA-860 8 UTLSRVNM Utility service territory name EIA-860 + updates 9 UTLSRVID Utility service territory ID EIA-860 + updates 10 OPPRNUM ID of the operator's parent company 11 OPPRNAME Name of the operator's parent company 12 PCANAME Power control area name NERC, EIA-861 + updates 13 PCAID Power control area ID NERC, EIA-861 + updates 14 NERC NERC region acronym NERC 15 SUBRGN eGRID subregion acronym EPA 16 SRNAME eGRID subregion name EPA 17 ISORTO Plant associated ISO/RTO Territory EIA-860 (2010) + updates 18 FIPSST Plant FIPS state code NIST based 19 FIPSCNTY Plant FIPS county code NIST based 20 CNTYNAME Plant county name EIA-860, EPA/CAMD 21 LAT Plant latitude EPA/CAMD, EIA + updates 22 LON Plant longitude EPA/CAMD, EIA + updates 23 CCFLAG County centroid flag: 1 = County centroid used 24 NUMBLR Number of boilers EPA/CAMD, EIA-860 calculated 25 NUMGEN Number of generators EIA-860 calculated 26 COMBUST Plant combustion status: 1 = Combusts, 0 = No combustion, 0.5 = Partial combustion 27 SOURCEM Plant emissions source(s): EPA or EIA-923 28 PLPRMFL Plant primary fuel 29 PLFUELCT Plant primary coal/oil/gas/other fossil fuel category 30 PLPFGNCT Plant primary fuel generation category 31 COALFLAG Flag indicating if the plant burned or generated any amount of coal: 1 = Yes 32 CAPFAC Plant capacity factor 33 NAMEPCAP Plant nameplate capacity MW EIA-860 summed 34 RMBMFLAG Biogas/biomass plant adjustment flag: 0 = No biomass; 1 = Biogas included; 100 = Other biomass included; 71 = CAMD emissions biogas adjustments; 7100 = CAMD C02 biomass adjustment 35 CHPFLAG Combined heat and power (CHP) plant adjustment flag: 1 = Yes eGRID CHP List 36 USETHRMO CHP plant useful thermal output MMBtu EIA-923 calculated 37 PWRTOHT CHP plant power to heat ratio 38 ELCALLOC CHP plant electric allocation factor 39 PSFLAG Plant pumped storage flag: 1 = Yes EIA-860 40 PLHTIAN Plant annual heat input MMBtu 41 PLHTIOZ Plant ozone season heat input MMBtu 42 PLNGENAN Plant annual net generation MWh EIA-923, EPA/CAMD calculated 43 PLNGENOZ Plant ozone season net generation MWh EIA-923, EPA/CAMD calculated 44 PLNOXAN Plant annual NOx emissions tons 45 PLNOXOZ Plant ozone season NOx emissions tons Abt Associates TSD for the 9,h Edition of eGRI | .xt 80 ------- APPENDIX A Field Name Description Unit Source(s) 46 PLS02AN Plant annual S02 emissions tons 47 PLC02AN Plant annual C02 emissions tons 48 PLCH4AN Plant annual CH4 emissions lbs 49 PLN20AN Plant annual N20 emissions lbs 50 PLC02EQA Plant annual C02 equivalent emissions ((1 * PLC02AN ) + (21 * PLCH4AN/2000) + (310 * PLN20AN/2000)) tons 51 PLHGAN Plant annual Hg emissions lbs 52 PLNOXRTA Plant annual NOx total output emission rate Ib/MWh 53 PLNOXRTO Plant ozone season NOx total output emission rate Ib/MWh 54 PLS02RTA Plant annual S02 total output emission rate Ib/MWh 55 PLC02RTA Plant annual C02 total output emission rate Ib/MWh 56 PLCH4RTA Plant annual CH4 total output emission rate Ib/GWh 57 PLN20RTA Plant annual N20 total output emission rate Ib/GWh 58 PLC2ERTA Plant annual C02 equivalent total output emission rate Ib/MWh 59 PLHGRTA Plant annual Hg total output emission rate Ib/GWh 60 PLNOXRA Plant annual NOx input emission rate Ib/MMBtu 61 PLNOXRO Plant ozone season NOx input emission rate Ib/MMBtu 62 PLS02RA Plant annual S02 input emission rate Ib/MMBtu 63 PLC02RA Plant annual C02 input emission rate Ib/MMBtu 64 PLHGRA Plant annual Hg input emission rate Ib/BBtu 65 PLNOXCRT Plant annual NOx combustion output emission rate Ib/MWh 66 PLNOXCRO Plant ozone season NOx combustion output emission rate Ib/MWh 67 PLS02CRT Plant annual S02 combustion output emission rate Ib/MWh 68 PLC02CRT Plant annual C02 combustion output emission rate Ib/MWh 69 PLCH4CRT Plant annual CH4 combustion output emission rate Ib/GWh 70 PLN20CRT Plant annual N20 combustion output emission rate Ib/GWh 71 PLHGCRT Plant annual Hg combustion output emission rate Ib/GWh 72 UNNOX Plant unadjusted annual NOx emissions tons 73 UNNOXOZ Plant unadjusted ozone season NOx emissions tons 74 UNS02 Plant unadjusted annual S02 emissions tons 75 UNC02 Plant unadjusted annual C02 emissions tons 76 UNCH4 Plant unadjusted annual CH4 emissions lbs 77 UNN20 Plant unadjusted annual N20 emissions lbs 78 UNHG Plant unadjusted annual Hg emissions lbs 79 UNHTI Plant unadjusted annual heat input MMBtu EPA/CAMD, EIA-923 80 UNHTIOZ Plant unadjusted ozone season heat input MMBtu EPA/CAMD, EIA-923 81 PLHTRT Plant nominal heat rate Btu/kWh 82 PLGENACL Plant annual coal net generation MWh 83 PLGENAOL Plant annual oil net generation MWh 84 PLGENAGS Plant annual gas net generation MWh 85 PLGENANC Plant annual nuclear net generation MWh 86 PLGENAHY Plant annual hydro net generation MWh 87 PLGENABM Plant annual biomass net generation MWh 88 PLGENAWI Plant annual wind net generation MWh 89 PLGENASO Plant annual solar net generation MWh 90 PLGENAGT Plant annual geothermal net generation MWh 91 PLGENAOF Plant annual other fossil net generation MWh 92 PLGENAOP Plant annual other unknown/purchased fuel net generation MWh 93 PLGENATN Plant annual total nonrenewables net generation MWh 94 PLGENATR Plant annual total renewables net generation MWh 95 PLGENATH Plant annual total nonhydro renewables net generation MWh 96 PLGENACY Plant annual total combustion net generation MWh 97 PLGENACN Plant annual total noncombustion net generation MWh Abt Associates TSD for the 9,h Edition of eGRI ^ | "57 ------- APPENDIX A Field Name Description Unit Source(s) 98 PLCLPR Plant coal generation percent (resource mix) 99 PLOLPR Plant oil generation percent (resource mix) 100 PLGSPR Plant gas generation percent (resource mix) 101 PLNCPR Plant nuclear generation percent (resource mix) 102 PLHYPR Plant hydro generation percent (resource mix) 103 PLBMPR Plant biomass generation percent (resource mix) 104 PLWIPR Plant wind generation percent (resource mix) 105 PLSOPR Plant solar generation percent (resource mix) 106 PLGTPR Plant geothermal generation percent (resource mix) 107 PLOFPR Plant other fossil generation percent (resource mix) 108 PLOPPR Plant other unknown/purchased fuel generation percent (resource mix) 109 PLTNPR Plant total nonrenewables generation percent (resource mix) 110 PLTRPR Plant total renewables generation percent (resource mix) 111 PLTHPR Plant total nonhydro renewables generation percent (resource mix) 112 PLCYPR Plant total combustion generation percent (resource mix) 113 PLCNPR Plant total noncombustion generation percent (resource mix) 114 OWNRNM01 Plant owner name (first) EIA-860 115 OWNRUC01 Plant owner code (first) EIA-860 116 OWNRPR01 Plant owner percent (first) EIA-860 117 OWNRNM02 Plant owner name (second) EIA-860 118 OWNRUC02 Plant owner code (second) EIA-860 119 OWNRPR02 Plant owner percent (second) EIA-860 120 OWNRNM03 Plant owner name (third) EIA-860 121 OWNRUC03 Plant owner code (third) EIA-860 122 OWNRPR03 Plant owner percent (third) EIA-860 123 OWNRNM04 Plant owner name (fourth) EIA-860 124 OWNRUC04 Plant owner code (fourth) EIA-860 125 OWNRPR04 Plant owner percent (fourth) EIA-860 126 OWNRNM05 Plant owner name (fifth) EIA-860 127 OWNRUC05 Plant owner code (fifth) EIA-860 128 OWNRPR05 Plant owner percent (fifth) EIA-860 129 OWNRNM06 Plant owner name (sixth) EIA-860 130 OWNRUC06 Plant owner code (sixth) EIA-860 131 OWNRPR06 Plant owner percent (sixth) EIA-860 132 OWNRNM07 Plant owner name (seventh) EIA-860 133 OWNRUC07 Plant owner code (seventh) EIA-860 134 OWNRPR07 Plant owner percent (seventh) EIA-860 135 OWNRNM08 Plant owner name (eighth) EIA-860 136 OWNRUC08 Plant owner code (eighth) EIA-860 137 OWNRPR08 Plant owner percent (eighth) EIA-860 138 OWNRNM09 Plant owner name (ninth) EIA-860 139 OWNRUC09 Plant owner code (ninth) EIA-860 140 OWNRPR09 Plant owner percent (ninth) EIA-860 141 OWNRNM10 Plant owner name (tenth) EIA-860 142 OWNRUC10 Plant owner code (tenth) EIA-860 143 OWNRPR10 Plant owner percent (tenth) EIA-860 144 OWNRNM11 Plant owner name (eleventh) EIA-860 145 OWNRUC11 Plant owner code (eleventh) EIA-860 146 OWNRPR11 Plant owner percent (eleventh) EIA-860 147 OWNRNM12 Plant owner name (twelfth) EIA-860 148 OWNRUC12 Plant owner code (twelfth) EIA-860 Abt Associates TSD for the 9,h Edition of eGRI | .xt 82 ------- APPENDIX A Field Name Description Unit Source(s) 149 OWNRPR12 Plant owner percent (twelfth) EIA-860 150 OWNRNM13 Plant owner name (thirteenth) EIA-860 151 OWNRUC13 Plant owner code (thirteenth) EIA-860 152 OWNRPR13 Plant owner percent (thirteenth) EIA-860 153 OWNRNM14 Plant owner name (fourteenth) EIA-860 154 OWNRUC14 Plant owner code (fourteenth) EIA-860 155 OWNRPR14 Plant owner percent (fourteenth) EIA-860 156 OWNRNM15 Plant owner name (fifteenth) EIA-860 157 OWNRUC15 Plant owner code (fifteenth) EIA-860 158 OWNRPR15 Plant owner percent (fifteenth) EIA-860 159 OWNRNM16 Plant owner name (sixteenth) EIA-860 160 OWNRUC16 Plant owner code (sixteenth) EIA-860 161 OWNRPR16 Plant owner percent (sixteenth) EIA-860 + updates EIA-860 162 SEQPLT04 eGRID2006 year 2004 file plant sequence number 163 SEQPLT05 eGRID2007 year 2005 file plant sequence number 164 SEQPLT07 eGRID2010 year 2007 file plant sequence number 165 SEQPLT09 eGRID2012 year 2009 file plant sequence number Abt Associates TSD for the 9,h Edition of eGRI | .xt 83 ------- APPENDIX A Table A-4. eGRID File Structure, Year 2010 ST State File Field Name Description Unit 1 SEQST10 eGRID year 2010 file state sequence number 2 PSTATABB State abbreviation 3 FIPSST FIPS state code 4 NAMEPCAP State nameplate capacity MW 5 STHTIAN State annual heat input MMBtu 6 STHTIOZ State ozone season heat input MMBtu 7 STNGENAN State annual net generation MWh 8 STNGENOZ State ozone season net generation MWh 9 STNOXAN State annual NOx emissions tons 10 STNOXOZ State ozone season NOx emissions tons 11 STS02AN State annual S02 emissions tons 12 STC02AN State annual C02 emissions tons 13 STCH4AN State annual CH4 emissions lbs 14 STN20AN State annual N20 emissions lbs 15 STC02EQA State annual C02 equivalent emissions tons 16 STHGAN State annual Hg emissions lbs 17 STNOXRTA State annual NOx total output emission rate Ib/MWh 18 STNOXRTO State ozone season NOx total output emission rate Ib/MWh 19 STS02RTA State annual S02 total output emission rate Ib/MWh 20 STC02RTA State annual C02 total output emission rate Ib/MWh 21 STCH4RTA State annual CH4 total output emission rate Ib/GWh 22 STN20RTA State annual N20 total output emission rate Ib/GWh 23 STC2ERTA State annual C02 equivalent total output emission rate Ib/MWh 24 STHGRTA State annual Hg total output emission rate Ib/GWh 25 STNOXRA State annual NOx input emission rate Ib/MMBtu 26 STNOXRO State ozone season NOx input emission rate Ib/MMBtu 27 STS02RA State annual S02 input emission rate Ib/MMBtu 28 STC02RA State annual C02 input emission rate Ib/MMBtu 29 STHGRA State annual Hg input emission rate Ib/BBtu 30 STNOXCRT State annual NOx combustion output emission rate Ib/MWh 31 STNOXCRO State ozone season NOx combustion output emission rate Ib/MWh 32 STS02CRT State annual S02 combustion output emission rate Ib/MWh 33 STC02CRT State annual C02 combustion output emission rate Ib/MWh 34 STCH4CRT State annual CH4 combustion output emission rate Ib/GWh 35 STN20CRT State annual N20 combustion output emission rate Ib/GWh 36 STHGCRT State annual Hg combustion output emission rate Ib/GWh 37 STCNOXRT State annual NOx coal output emission rate Ib/MWh 38 STONOXRT State annual NOx oil output emission rate Ib/MWh 39 STGNOXRT State annual NOx gas output emission rate Ib/MWh 40 STFSNXRT State annual NOx fossil fuel output emission rate Ib/MWh 41 STCNXORT State ozone season NOxcoal output emission rate Ib/MWh 42 STONXORT State ozone season NOx oil output emission rate Ib/MWh 43 STGNXORT State ozone season NOx gas output emission rate Ib/MWh 44 STFSNORT State ozone season NOx fossil fuel output emission rate Ib/MWh 45 STCS02RT State annual S02 coal output emission rate Ib/MWh 46 STOS02RT State annual S02 oil output emission rate Ib/MWh 47 STGS02RT State annual S02 gas output emission rate Ib/MWh 48 STFSS2RT State annual S02 fossil fuel output emission rate Ib/MWh 49 STCC02RT State annual C02 coal output emission rate Ib/MWh 50 STOC02RT State annual C02 oil output emission rate Ib/MWh 51 STGC02RT State annual C02 gas output emission rate Ib/MWh 52 STFSC2RT State annual C02 fossil fuel output emission rate Ib/MWh Abt Associates TSD for the 9,h Edition of eGRI | .xt 84 ------- APPENDIX A Field Name Description Unit 53 STCHGRT State annual Hg coal output emission rate Ib/GWh 54 STFSHGRT State annual Hg fossil fuel output emission rate Ib/GWh 55 STCNOXR State annual NOx coal input emission rate Ib/MMBtu 56 STONOXR State annual NOx oil input emission rate Ib/MMBtu 57 STGNOXR State annual NOx gas input emission rate Ib/MMBtu 58 STFSNXR State annual NOx fossil fuel input emission rate Ib/MMBtu 59 STCNXOR State ozone season NOx coal input emission rate Ib/MMBtu 60 STONXOR State ozone season NOx oil input emission rate Ib/MMBtu 61 STGNXOR State ozone season NOx gas input emission rate Ib/MMBtu 62 STFSNOR State ozone season NOx fossil fuel input emission rate Ib/MMBtu 63 STCS02R State annual S02 coal input emission rate Ib/MMBtu 64 STOS02R State annual S02 oil input emission rate Ib/MMBtu 65 STGS02R State annual S02 gas input emission rate Ib/MMBtu 66 STFSS2R State annual S02 fossil fuel input emission rate Ib/MMBtu 67 STCC02R State annual C02 coal input emission rate Ib/MMBtu 68 STOC02R State annual C02 oil input emission rate Ib/MMBtu 69 STGC02R State annual C02 gas input emission rate Ib/MMBtu 70 STFSC2R State annual C02 fossil fuel input emission rate Ib/MMBtu 71 STCHGR State annual Hg coal input emission rate Ib/BBtu 72 STFSHGR State annual Hg fossil fuel input emission rate Ib/BBtu 73 STNBNOX State annual NOx non-baseload output emission rate Ib/MWh 74 STNBNXO State ozone season NOx non-baseload output emission rate Ib/MWh 75 STNBS02 State annual S02 non-baseload output emission rate Ib/MWh 76 STNBC02 State annual C02 non-baseload output emission rate Ib/MWh 77 STNBCH4 State annual CH4 non-baseload output emission rate Ib/GWh 78 STNBN20 State annual N20 non-baseload output emission rate Ib/GWh 79 STNBHG State annual Hg non-baseload output emission rate Ib/GWh 80 STGENACL State annual coal net generation MWh 81 STGENAOL State annual oil net generation MWh 82 STGENAGS State annual gas net generation MWh 83 STGENANC State annual nuclear net generation MWh 84 STGENAHY State annual hydro net generation MWh 85 STGENABM State annual biomass net generation MWh 86 STGENAWI State annual wind net generation MWh 87 STGENASO State annual solar net generation MWh 88 STGENAGT State annual geothermal net generation MWh 89 STGENAOF State annual other fossil net generation MWh 90 STGENAOP State annual other unknown/purchased fuel net generation MWh 91 STGENATN State annual total nonrenewables net generation MWh 92 STGENATR State annual total renewables net generation MWh 93 STGENATH State annual total nonhydro renewables net generation MWh 94 STGENACY State annual total combustion net generation MWh 95 STGENACN State annual total noncombustion net generation MWh 96 STCLPR State coal generation percent (resource mix) 97 STOLPR State oil generation percent (resource mix) 98 STGSPR State gas generation percent (resource mix) 99 STNCPR State nuclear generation percent (resource mix) 100 STHYPR State hydro generation percent (resource mix) 101 STBMPR State biomass generation percent (resource mix) 102 STWIPR State wind generation percent (resource mix) 103 STSOPR State solar generation percent (resource mix) 104 STGTPR State geothermal generation percent (resource mix) 105 STOFPR State other fossil generation percent (resource mix) 106 STOPPR State other unknown/purchased fuel generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI ^ | ~85 ------- APPENDIX A Field Name Description Unit 107 STTNPR State total nonrenewables generation percent (resource mix) 108 STTRPR State total renewables generation percent (resource mix) 109 STTHPR State total nonhydro renewables generation percent (resource mix) 110 STCYPR State total combustion generation percent (resource mix) 111 STCNPR State total noncombustion generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 86 ------- APPENDIX A Table A-5. eGRID File Structure, Year 2010 PCAL File, Power Control Area (PCA) File Field Name Description Unit 1 SEQPCL10 eGRID year 2010 file PCA sequence number 2 PCAID PCA ID 3 PCANAME PCA name 4 NAMEPCAP PCA nameplate capacity MW 5 PCHTIAN PCA annual heat input MMBtu 6 PCHTIOZ PCA ozone season heat input MMBtu 7 PCNGENAN PCA annual net generation MWh 8 PCNGENOZ PCA ozone season net generation MWh 9 PCNOXAN PCA annual NOx emissions tons 10 PCNOXOZ PCA ozone season NOx emissions tons 11 PCS02AN PCA annual S02 emissions tons 12 PCC02AN PCA annual C02 emissions tons 13 PCCH4AN PCA annual CH4 emissions lbs 14 PCN20AN PCA annual N20 emissions lbs 15 PCC02EQA PCA annual C02 equivalent emissions tons 16 PCHGAN PCA annual Hg emissions lbs 17 PCNOXRTA PCA annual NOx total output emission rate Ib/MWh 18 PCNOXRTO PCA ozone season NOx total output emission rate Ib/MWh 19 PCS02RTA PCA annual S02 total output emission rate Ib/MWh 20 PCC02RTA PCA annual C02 total output emission rate Ib/MWh 21 PCCH4RTA PCA annual CH4 total output emission rate Ib/GWh 22 PCN20RTA PCA annual N20 total output emission rate Ib/GWh 23 PCC2ERTA PCA annual C02 equivalent total output emission rate Ib/MWh 24 PCHGRTA PCA annual Hg total output emission rate Ib/GWh 25 PCNOXRA PCA annual NOx input emission rate Ib/MMBtu 26 PCNOXRO PCA ozone season NOx input emission rate Ib/MMBtu 27 PCS02RA PCA annual S02 input emission rate Ib/MMBtu 28 PCC02RA PCA annual C02 input emission rate Ib/MMBtu 29 PCHGRA PCA annual Hg input emission rate Ib/BBtu 30 PCNOXCRT PCA annual NOx combustion output emission rate Ib/MWh 31 PCNOXCRO PCA ozone season NOx combustion output emission rate Ib/MWh 32 PCS02CRT PCA annual S02 combustion output emission rate Ib/MWh 33 PCC02CRT PCA annual C02 combustion output emission rate Ib/MWh 34 PCCH4CRT PCA annual CH4 combustion output emission rate Ib/GWh 35 PCN20CRT PCA annual N20 combustion output emission rate Ib/GWh 36 PCHGCRT PCA annual Hg combustion output emission rate Ib/GWh 37 PCCNOXRT PCA annual NOx coal output emission rate Ib/MWh 38 PCONOXRT PCA annual NOx oil output emission rate Ib/MWh 39 PCGNOXRT PCA annual NOx gas output emission rate Ib/MWh 40 PCFSNXRT PCA annual NOx fossil fuel output emission rate Ib/MWh 41 PCCNXORT PCA ozone season NOx coal output emission rate Ib/MWh 42 PCONXORT PCA ozone season NOx oil output emission rate Ib/MWh 43 PCGNXORT PCA ozone season NOx gas output emission rate Ib/MWh 44 PCFSNORT PCA ozone season NOx fossil fuel output emission rate Ib/MWh 45 PCCS02RT PCA annual S02 coal output emission rate Ib/MWh 46 PCOS02RT PCA annual S02 oil output emission rate Ib/MWh 47 PCGS02RT PCA annual S02 gas output emission rate Ib/MWh 48 PCFSS2RT PCA annual S02 fossil fuel output emission rate Ib/MWh 49 PCCC02RT PCA annual C02 coal output emission rate Ib/MWh 50 PCOC02RT PCA annual C02 oil output emission rate Ib/MWh 51 PCGC02RT PCA annual C02 gas output emission rate Ib/MWh 52 PCFSC2RT PCA annual C02 fossil fuel output emission rate Ib/MWh Abt Associates TSD for the 9,h Edition of eGRI | .xt 87 ------- APPENDIX A Field Name Description Unit 53 PCCHGRT PCA annual Hg coal output emission rate Ib/GWh 54 PCFSHGRT PCA annual Hg fossil fuel output emission rate Ib/GWh 55 PCCNOXR PCA annual NOx coal input emission rate Ib/MMBtu 56 PCONOXR PCA annual NOx oil input emission rate Ib/MMBtu 57 PCGNOXR PCA annual NOx gas input emission rate Ib/MMBtu 58 PCFSNXR PCA annual NOx fossil fuel input emission rate Ib/MMBtu 59 PCCNXOR PCA ozone season NOx coal input emission rate Ib/MMBtu 60 PCONXOR PCA ozone season NOx oil input emission rate Ib/MMBtu 61 PCGNXOR PCA ozone season NOx gas input emission rate Ib/MMBtu 62 PCFSNOR PCA ozone season NOx fossil fuel input emission rate Ib/MMBtu 63 PCCS02R PCA annual S02 coal input emission rate Ib/MMBtu 64 PCOS02R PCA annual S02 oil input emission rate Ib/MMBtu 65 PCGS02R PCA annual S02 gas input emission rate Ib/MMBtu 66 PCFSS2R PCA annual S02 fossil fuel input emission rate Ib/MMBtu 67 PCCC02R PCA annual C02 coal input emission rate Ib/MMBtu 68 PCOC02R PCA annual C02 oil input emission rate Ib/MMBtu 69 PCGC02R PCA annual C02 gas input emission rate Ib/MMBtu 70 PCFSC2R PCA annual C02 fossil fuel input emission rate Ib/MMBtu 71 PCCHGR PCA annual Hg coal input emission rate Ib/BBtu 72 PCFSHGR PCA annual Hg fossil fuel input emission rate Ib/BBtu 73 PCNBNOX PCA annual NOx non-baseload output emission rate Ib/MWh 74 PCNBNXO PCA ozone season NOx non-baseload output emission rate Ib/MWh 75 PCNBS02 PCA annual S02 non-baseload output emission rate Ib/MWh 76 PCNBC02 PCA annual C02 non-baseload output emission rate Ib/MWh 77 PCNBCH4 PCA annual CH4 non-baseload output emission rate Ib/GWh 78 PCNBN20 PCA annual N20 non-baseload output emission rate Ib/GWh 79 PCNBHG PCA annual Hg non-baseload output emission rate Ib/GWh 80 PCGENACL PCA annual coal net generation MWh 81 PCGENAOL PCA annual oil net generation MWh 82 PCGENAGS PCA annual gas net generation MWh 83 PCGENANC PCA annual nuclear net generation MWh 84 PCGENAHY PCA annual hydro net generation MWh 85 PCGENABM PCA annual biomass net generation MWh 86 PCGENAWI PCA annual wind net generation MWh 87 PCGENASO PCA annual solar net generation MWh 88 PCGENAGT PCA annual geothermal net generation MWh 89 PCGENAOF PCA annual other fossil net generation MWh 90 PCGENAOP PCA annual other unknown/purchased fuel net generation MWh 91 PCGENATN PCA annual total nonrenewables net generation MWh 92 PCGENATR PCA annual total renewables net generation MWh 93 PCGENATH PCA annual total nonhydro renewables net generation MWh 94 PCGENACY PCA annual total combustion net generation MWh 95 PCGENACN PCA annual total noncombustion net generation MWh 96 PCCLPR PCA coal generation percent (resource mix) 97 PCOLPR PCA oil generation percent (resource mix) 98 PCGSPR PCA gas generation percent (resource mix) 99 PCNCPR PCA nuclear generation percent (resource mix) 100 PCHYPR PCA hydro generation percent (resource mix) 101 PCBMPR PCA biomass generation percent (resource mix) 102 PCWIPR PCA wind generation percent (resource mix) 103 PCSOPR PCA solar generation percent (resource mix) 104 PCGTPR PCA geothermal generation percent (resource mix) 105 PCOFPR PCA other fossil generation percent (resource mix) 106 PCOPPR PCA other unknown/purchased fuel generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 88 ------- APPENDIX A Field Name Description Unit 107 PCTNPR PCA total nonrenewables generation percent (resource mix) 108 PCTRPR PCA total renewables generation percent (resource mix) 109 PCTHPR PCA total nonhydro renewables generation percent (resource mix) 110 PCCYPR PCA total combustion generation percent (resource mix) 111 PCCNPR PCA total noncombustion generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 89 ------- APPENDIX A Table A-6. eGRID File Structure, Year 2010 SRL File, eGRID Subregion File Field Name Description Unit 1 SEQSRL10 eGRID year 2010 file eGRID subregion sequence number 2 SUBRGN eGRID subregion acronym 3 SRNAME eGRID subregion name 4 NERC NERC region acronym associated with the eGRID subregion acronym 5 NAMEPCAP eGRID subregion nameplate capacity MW 6 SRHTIAN eGRID subregion annual heat input MMBtu 7 SRHTIOZ eGRID subregion ozone season heat input MMBtu 8 SRNGENAN eGRID subregion annual net generation MWh 9 SRNGENOZ eGRID subregion ozone season net generation MWh 10 SRNOXAN eGRID subregion annual NOx emissions tons 11 SRNOXOZ eGRID subregion ozone season NOx emissions tons 12 SRS02AN eGRID subregion annual S02 emissions tons 13 SRC02AN eGRID subregion annual C02 emissions tons 14 SRCH4AN eGRID subregion annual CH4 emissions lbs 15 SRN20AN eGRID subregion annual N20 emissions lbs 16 SRC02EQA eGRID subregion annual C02 equivalent emissions tons 17 SRHGAN eGRID subregion annual Hg emissions lbs 18 SRNOXRTA eGRID subregion annual NOx total output emission rate Ib/MWh 19 SRNOXRTO eGRID subregion ozone season NOx total output emission rate Ib/MWh 20 SRS02RTA eGRID subregion annual S02 total output emission rate Ib/MWh 21 SRC02RTA eGRID subregion annual C02 total output emission rate Ib/MWh 22 SRCH4RTA eGRID subregion annual CH4 total output emission rate Ib/GWh 23 SRN20RTA eGRID subregion annual N20 total output emission rate Ib/GWh 24 SRC2ERTA eGRID subregion annual C02 equivalent total output emission rate Ib/MWh 25 SRHGRTA eGRID subregion annual Hg total output emission rate Ib/GWh 26 SRNOXRA eGRID subregion annual NOx input emission rate Ib/MMBtu 27 SRNOXRO eGRID subregion ozone season NOx input emission rate Ib/MMBtu 28 SRS02RA eGRID subregion annual S02 input emission rate Ib/MMBtu 29 SRC02RA eGRID subregion annual C02 input emission rate Ib/MMBtu 30 SRHGRA eGRID subregion annual Hg input emission rate Ib/BBtu 31 SRNOXCRT eGRID subregion annual NOx combustion output emission rate Ib/MWh 32 SRNOXCRO eGRID subregion ozone season NOx combustion output emission rate Ib/MWh 33 SRS02CRT eGRID subregion annual S02 combustion output emission rate Ib/MWh 34 SRC02CRT eGRID subregion annual C02 combustion output emission rate Ib/MWh 35 SRCH4CRT eGRID subregion annual CH4 combustion output emission rate Ib/GWh 36 SRN20CRT eGRID subregion annual N20 combustion output emission rate Ib/GWh 37 SRHGCRT eGRID subregion annual Hg combustion output emission rate Ib/GWh 38 SRCNOXRT eGRID subregion annual NOx coal output emission rate Ib/MWh 39 SRONOXRT eGRID subregion annual NOx oil output emission rate Ib/MWh 40 SRGNOXRT eGRID subregion annual NOx gas output emission rate Ib/MWh 41 SRFSNXRT eGRID subregion annual NOx fossil fuel output emission rate Ib/MWh 42 SRCNXORT eGRID subregion ozone season NOxcoal output emission rate Ib/MWh 43 SRONXORT eGRID subregion ozone season NOx oil output emission rate Ib/MWh 44 SRGNXORT eGRID subregion ozone season NOx gas output emission rate Ib/MWh 45 SRFSNORT eGRID subregion ozone season NOx fossil fuel output emission rate Ib/MWh 46 SRCS02RT eGRID subregion annual S02 coal output emission rate Ib/MWh 47 SROS02RT eGRID subregion annual S02 oil output emission rate Ib/MWh 48 SRGS02RT eGRID subregion annual S02 gas output emission rate Ib/MWh 49 SRFSS2RT eGRID subregion annual S02 fossil fuel output emission rate Ib/MWh 50 SRCC02RT eGRID subregion annual C02 coal output emission rate Ib/MWh 51 SROC02RT eGRID subregion annual C02 oil output emission rate Ib/MWh 52 SRGC02RT eGRID subregion annual C02 gas output emission rate Ib/MWh Abt Associates TSD for the 9,h Edition of eGRI | .xt 90 ------- APPENDIX A Field Name Description Unit 53 SRFSC2RT eGRID subregion annual C02 fossil fuel output emission rate Ib/MWh 54 SRCHGRT eGRID subregion annual Hg coal output emission rate Ib/GWh 55 SRFSHGRT eGRID subregion annual Hg fossil fuel output emission rate Ib/GWh 56 SRCNOXR eGRID subregion annual NOx coal input emission rate Ib/MMBtu 57 SRONOXR eGRID subregion annual NOx oil input emission rate Ib/MMBtu 58 SRGNOXR eGRID subregion annual NOx gas input emission rate Ib/MMBtu 59 SRFSNXR eGRID subregion annual NOx fossil fuel input emission rate Ib/MMBtu 60 SRCNXOR eGRID subregion ozone season NOx coal input emission rate Ib/MMBtu 61 SRONXOR eGRID subregion ozone season NOx oil input emission rate Ib/MMBtu 62 SRGNXOR eGRID subregion ozone season NOx gas input emission rate Ib/MMBtu 63 SRFSNOR eGRID subregion ozone season NOx fossil fuel input emission rate Ib/MMBtu 64 SRCS02R eGRID subregion annual S02 coal input emission rate Ib/MMBtu 65 SROS02R eGRID subregion annual S02 oil input emission rate Ib/MMBtu 66 SRGS02R eGRID subregion annual S02 gas input emission rate Ib/MMBtu 67 SRFSS2R eGRID subregion annual S02 fossil fuel input emission rate Ib/MMBtu 68 SRCC02R eGRID subregion annual C02 coal input emission rate Ib/MMBtu 69 SROC02R eGRID subregion annual C02 oil input emission rate Ib/MMBtu 70 SRGC02R eGRID subregion annual C02 gas input emission rate Ib/MMBtu 71 SRFSC2R eGRID subregion annual C02 fossil fuel input emission rate Ib/MMBtu 72 SRCHGR eGRID subregion annual Hg coal input emission rate Ib/BBtu 73 SRFSHGR eGRID subregion annual Hg fossil fuel input emission rate Ib/BBtu 74 SRNBNOX eGRID subregion annual NOx non-baseload output emission rate Ib/MWh 75 SRNBNXO eGRID subregion ozone season NOx non-baseload output emission rate Ib/MWh 76 SRNBS02 eGRID subregion annual S02 non-baseload output emission rate Ib/MWh 77 SRNBC02 eGRID subregion annual C02 non-baseload output emission rate Ib/MWh 78 SRNBCH4 eGRID subregion annual CH4 non-baseload output emission rate Ib/GWh 79 SRNBN20 eGRID subregion annual N20 non-baseload output emission rate Ib/GWh 80 SRNBC2ER eGRID subregion annual C02 equivalent non-baseload output emission rate Ib/MWh 81 SRNBHG eGRID subregion annual Hg non-baseload output emission rate Ib/GWh 82 SRGENACL eGRID subregion annual coal net generation MWh 83 SRGENAOL eGRID subregion annual oil net generation MWh 84 SRGENAGS eGRID subregion annual gas net generation MWh 85 SRGENANC eGRID subregion annual nuclear net generation MWh 86 SRGENAHY eGRID subregion annual hydro net generation MWh 87 SRGENABM eGRID subregion annual biomass net generation MWh 88 SRGENAWI eGRID subregion annual wind net generation MWh 89 SRGENASO eGRID subregion annual solar net generation MWh 90 SRGENAGT eGRID subregion annual geothermal net generation MWh 91 SRGENAOF eGRID subregion annual other fossil net generation MWh 92 SRGENAOP eGRID subregion annual other unknown/purchased fuel net generation MWh 93 SRGENATN eGRID subregion annual total nonrenewables net generation MWh 94 SRGENATR eGRID subregion annual total renewables net generation MWh 95 SRGENATH eGRID subregion annual total nonhydro renewables net generation MWh 96 SRGENACY eGRID subregion annual total combustion net generation MWh 97 SRGENACN eGRID subregion annual total noncombustion net generation MWh 98 SRCLPR eGRID subregion coal generation percent (resource mix) 99 SROLPR eGRID subregion oil generation percent (resource mix) 100 SRGSPR eGRID subregion gas generation percent (resource mix) 101 SRNCPR eGRID subregion nuclear generation percent (resource mix) 102 SRHYPR eGRID subregion hydro generation percent (resource mix) 103 SRBMPR eGRID subregion biomass generation percent (resource mix) 104 SRWIPR eGRID subregion wind generation percent (resource mix) 105 SRSOPR eGRID subregion solar generation percent (resource mix) 106 SRGTPR eGRID subregion geothermal generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 91 ------- APPENDIX A Field Name Description Unit 107 SROFPR eGRID subregion other fossil generation percent (resource mix) 108 SROPPR eGRID subregion other unknown/purchased fuel generation percent (resource mix) 109 SRTNPR eGRID subregion total nonrenewables generation percent (resource mix) 110 SRTRPR eGRID subregion total renewables generation percent (resource mix) 111 SRTHPR eGRID subregion total nonhydro renewables generation percent (resource mix) 112 SRCYPR eGRID subregion total combustion generation percent (resource mix) 113 SRCNPR eGRID subregion total noncombustion generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 92 ------- APPENDIX A Table A-7. eGRID File Structure, Year 2010 NRL File, NERC Region File Field Name Description Unit 1 SEQNRL10 eGRID year 2010 file NERC region sequence number 2 NERC NERC region acronym 3 NERCNAME NERC region name 4 NAMEPCAP NERC region namepiate capacity MW 5 NRHTIAN NERC region annual heat input MMBtu 6 NRHTIOZ NERC region ozone season heat input MMBtu 7 NRNGENAN NERC region annual net generation MWh 8 NRNGENOZ NERC region ozone season net generation MWh 9 NRNOXAN NERC region annual NOx emissions tons 10 NRNOXOZ NERC region ozone season NOx emissions tons 11 NRS02AN NERC region annual S02 emissions tons 12 NRC02AN NERC region annual C02 emissions tons 13 NRCH4AN NERC region annual CH4 emissions lbs 14 NRN20AN NERC region annual N20 emissions lbs 15 NRC02EQA NERC region annual C02equivalent emissions tons 16 NRHGAN NERC region annual Hg emissions lbs 17 NRNOXRTA NERC region annual NOx total output emission rate Ib/MWh 18 NRNOXRTO NERC region ozone season NOx total output emission rate Ib/MWh 19 NRS02RTA NERC region annual S02 total output emission rate Ib/MWh 20 NRC02RTA NERC region annual C02 total output emission rate Ib/MWh 21 NRCH4RTA NERC region annual CH4 total output emission rate Ib/GWh 22 NRN20RTA NERC region annual N20 total output emission rate Ib/GWh 23 NRC2ERTA NERC region annual C02 equivalent total output emission rate Ib/MWh 24 NRHGRTA NERC region annual Hg total output emission rate Ib/GWh 25 NRNOXRA NERC region annual NOx input emission rate Ib/MMBtu 26 NRNOXRO NERC region ozone season NOx input emission rate Ib/MMBtu 27 NRS02RA NERC region annual S02 input emission rate Ib/MMBtu 28 NRC02RA NERC region annual C02 input emission rate Ib/MMBtu 29 NRHGRA NERC region annual Hg input emission rate Ib/BBtu 30 NRNOXCRT NERC region annual NOx combustion output emission rate Ib/MWh 31 NRNOXCRO NERC region ozone season NOx combustion output emission rate Ib/MWh 32 NRS02CRT NERC region annual S02 combustion output emission rate Ib/MWh 33 NRC02CRT NERC region annual C02 combustion output emission rate Ib/MWh 34 NRCH4CRT NERC region annual CH4 combustion output emission rate Ib/GWh 35 NRN20CRT NERC region annual N20 combustion output emission rate Ib/GWh 36 NRHGCRT NERC region annual Hg combustion output emission rate Ib/GWh 37 NRCNOXRT NERC region annual NOx coal output emission rate Ib/MWh 38 NRONOXRT NERC region annual NOx oil output emission rate Ib/MWh 39 NRGNOXRT NERC region annual NOx gas output emission rate Ib/MWh 40 NRFSNXRT NERC region annual NOx fossil fuel output emission rate Ib/MWh 41 NRCNXORT NERC region ozone season NOxcoaloutput emission rate Ib/MWh 42 NRONXORT NERC region ozone season NOx oil output emission rate Ib/MWh 43 NRGNXORT NERC region ozone season NOx gas output emission rate Ib/MWh 44 NRFSNORT NERC region ozone season NOx fossil fuel output emission rate Ib/MWh 45 NRCS02RT NERC region annual S02 coal output emission rate Ib/MWh 46 NROS02RT NERC region annual S02 oil output emission rate Ib/MWh 47 NRGS02RT NERC region annual S02 gas output emission rate Ib/MWh 48 NRFSS2RT NERC region annual S02 fossil fuel output emission rate Ib/MWh 49 NRCC02RT NERC region annual C02 coal output emission rate Ib/MWh 50 NROC02RT NERC region annual C02 oil output emission rate Ib/MWh 51 NRGC02RT NERC region annual C02 gas output emission rate Ib/MWh 52 NRFSC2RT NERC region annual C02 fossil fuel output emission rate Ib/MWh Abt Associates TSD for the 9,h Edition of eGRI | .xt 93 ------- APPENDIX A Field Name Description Unit 53 NRCHGRT NERC region annual Hg coal output emission rate Ib/GWh 54 NRFSHGRT NERC region annual Hg fossil fuel output emission rate Ib/GWh 55 NRCNOXR NERC region annual NOx coal input emission rate Ib/MMBtu 56 NRONOXR NERC region annual NOx oil input emission rate Ib/MMBtu 57 NRGNOXR NERC region annual NOx gas input emission rate Ib/MMBtu 58 NRFSNXR NERC region annual NOx fossil fuel input emission rate Ib/MMBtu 59 NRCNXOR NERC region ozone season NOx coal input emission rate Ib/MMBtu 60 NRONXOR NERC region ozone season NOx oil input emission rate Ib/MMBtu 61 NRGNXOR NERC region ozone season NOx gas input emission rate Ib/MMBtu 62 NRFSNOR NERC region ozone season NOx fossil fuel input emission rate Ib/MMBtu 63 NRCS02R NERC region annual S02 coal input emission rate Ib/MMBtu 64 NROS02R NERC region annual S02 oil input emission rate Ib/MMBtu 65 NRGS02R NERC region annual S02 gas input emission rate Ib/MMBtu 66 NRFSS2R NERC region annual S02 fossil fuel input emission rate Ib/MMBtu 67 NRCC02R NERC region annual C02 coal input emission rate Ib/MMBtu 68 NROC02R NERC region annual C02 oil input emission rate Ib/MMBtu 69 NRGC02R NERC region annual C02 gas input emission rate Ib/MMBtu 70 NRFSC2R NERC region annual C02 fossil fuel input emission rate Ib/MMBtu 71 NRCHGR NERC region annual Hg coal input emission rate Ib/BBtu 72 NRFSHGR NERC region annual Hg fossil fuel input emission rate Ib/BBtu 73 NRNBNOX NERC region annual NOx non-baseload output emission rate Ib/MWh 74 NRNBNXO NERC region ozone season NOx non-baseload output emission rate Ib/MWh 75 NRNBS02 NERC region annual S02 non-baseload output emission rate Ib/MWh 76 NRNBC02 NERC region annual C02 non-baseload output emission rate Ib/MWh 77 NRNBCH4 NERC region annual CH4 non-baseload output emission rate Ib/GWh 78 NRNBN20 NERC region annual N20 non-baseload output emission rate Ib/GWh 79 NRNBHG NERC region annual Hg non-baseload output emission rate Ib/GWh 80 NRGENACL NERC region annual coal net generation MWh 81 NRGENAOL NERC region annual oil net generation MWh 82 NRGENAGS NERC region annual gas net generation MWh 83 NRGENANC NERC region annual nuclear net generation MWh 84 NRGENAHY NERC region annual hydro net generation MWh 85 NRGENABM NERC region annual biomass net generation MWh 86 NRGENAWI NERC region annual wind net generation MWh 87 NRGENASO NERC region annual solar net generation MWh 88 NRGENAGT NERC region annual geothermal net generation MWh 89 NRGENAOF NERC region annual other fossil net generation MWh 90 NRGENAOP NERC region annual other unknown/purchased fuel net generation MWh 91 NRGENATN NERC region annual total nonrenewables net generation MWh 92 NRGENATR NERC region annual total renewables net generation MWh 93 NRGENATH NERC region annual total nonhydro renewables net generation MWh 94 NRGENACY NERC region annual total combustion net generation MWh 95 NRGENACN NERC region annual total noncombustion net generation MWh 96 NRCLPR NERC region coal generation percent (resource mix) 97 NROLPR NERC region oil generation percent (resource mix) 98 NRGSPR NERC region gas generation percent (resource mix) 99 NRNCPR NERC region nuclear generation percent (resource mix) 100 NRHYPR NERC region hydro generation percent (resource mix) 101 NRBMPR NERC region biomass generation percent (resource mix) 102 NRWIPR NERC region wind generation percent (resource mix) 103 NRSOPR NERC region solar generation percent (resource mix) 104 NRGTPR NERC region geothermal generation percent (resource mix) 105 NROFPR NERC region other fossil generation percent (resource mix) 106 NROPPR NERC region other unknown/purchased fuel generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 94 ------- APPENDIX A Field Name Description Unit 107 NRTNPR NERC region total nonrenewables generation percent (resource mix) 108 NRTRPR NERC region total renewables generation percent (resource mix) 109 NRTHPR NERC region total nonhydro renewables generation percent (resource mix) 110 NRCYPR NERC region total combustion generation percent (resource mix) 111 NRCNPR NERC region total noncombustion generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI ^ | *95 ------- APPENDIX A Table A-8. eGRID File Structure, Year 2010 U.S. File, United States File Field Name Description Unit Source(s) 1 SEQUS10 eGRID year 2010 file U.S. sequence number 2 NAMEPCAP U.S. nameplate capacity MW 3 USHTIAN U.S. annual heat input MMBtu 4 USHTIOZ U.S. ozone season heat input MMBtu 5 USNGENAN U.S. annual net generation MWh 6 USNGENOZ U.S. ozone season net generation MWh 7 USNOXAN U.S. annual NOx emissions tons 8 USNOXOZ U.S. ozone season NOx emissions tons 9 USS02AN U.S. annual S02 emissions tons 10 USC02AN U.S. annual C02emissions tons 11 USCH4AN U.S. annual CH4 emissions lbs 12 USN20AN U.S. annual N20 emissions lbs 13 USC02EQA U.S. annual C02 equivalent emissions tons 14 USHGAN U.S. annual Hg emissions lbs 15 USNOXRTA U.S. annual NOx total output emission rate Ib/MWh 16 USNOXRTO U.S. ozone season NOx total output emission rate Ib/MWh 17 USS02RTA U.S. annual S02 total output emission rate Ib/MWh 18 USC02RTA U.S. annual C02 total output emission rate Ib/MWh 19 USCH4RTA U.S. annual CH4 total output emission rate Ib/GWh 20 USN20RTA U.S. annual N20 total output emission rate Ib/GWh 21 USC2ERTA U.S. annual C02 equivalent total output emission rate Ib/MWh 22 USHGRTA U.S. annual Hg total output emission rate Ib/GWh 23 USNOXRA U.S. annual NOx input emission rate Ib/MMBtu 24 USNOXRO U.S. ozone season NOx input emission rate Ib/MMBtu 25 USS02RA U.S. annual S02 input emission rate Ib/MMBtu 26 USC02RA U.S. annual C02 input emission rate Ib/MMBtu 27 USHGRA U.S. annual Hg input emission rate Ib/BBtu 28 USNOXCRT U.S. annual NOx combustion output emission rate Ib/MWh 29 USNOXCRO U.S. ozone season NOx combustion output emission rate Ib/MWh 30 USS02CRT U.S. annual S02 combustion output emission rate Ib/MWh 31 USC02CRT U.S. annual C02combustion output emission rate Ib/MWh 32 USCH4CRT U.S. annual CH4 combustion output emission rate Ib/GWh 33 USN20CRT U.S. annual N20 combustion output emission rate Ib/GWh 34 USHGCRT U.S. annual Hg combustion output emission rate Ib/GWh 35 USCNOXRT U.S. annual NOx coal output emission rate Ib/MWh 36 USONOXRT U.S. annual NOx oil output emission rate Ib/MWh 37 USGNOXRT U.S. annual NOx gas output emission rate Ib/MWh 38 USFSNXRT U.S. annual NOx fossil fuel output emission rate Ib/MWh 39 USCNXORT U.S. ozone season NOx coal output emission rate Ib/MWh 40 USONXORT U.S. ozone season NOx oil output emission rate Ib/MWh 41 USGNXORT U.S. ozone season NOx gas output emission rate Ib/MWh 42 USFSNORT U.S. ozone season NOx fossil fuel output emission rate Ib/MWh 43 USCS02RT U.S. annual S02 coal output emission rate Ib/MWh 44 USOS02RT U.S. annual S02 oil output emission rate Ib/MWh 45 USGS02RT U.S. annual S02 gas output emission rate Ib/MWh 46 USFSS2RT U.S. annual S02 fossil fuel output emission rate Ib/MWh 47 USCC02RT U.S. annual C02 coal output emission rate Ib/MWh 48 USOC02RT U.S. annual C02 oil output emission rate Ib/MWh 49 USGC02RT U.S. annual C02 gas output emission rate Ib/MWh 50 USFSC2RT U.S. annual C02 fossil fuel output emission rate Ib/MWh 51 USCHGRT U.S. annual Hg coal output emission rate Ib/GWh Abt Associates TSD for the 9,h Edition of eGRI | .xt 96 ------- APPENDIX A Field Name Description Unit Source(s) 52 USFSHGRT U.S. annual Hg fossil fuel output emission rate Ib/GWh 53 USCNOXR U.S. annual NOx coal input emission rate Ib/MMBtu 54 USONOXR U.S. annual NOx oil input emission rate Ib/MMBtu 55 USGNOXR U.S. annual NOx gas input emission rate Ib/MMBtu 56 USFSNXR U.S. annual NOx fossil fuel input emission rate Ib/MMBtu 57 USCNXOR U.S. ozone season NOx coal input emission rate Ib/MMBtu 58 USONXOR U.S. ozone season NOx oil input emission rate Ib/MMBtu 59 USGNXOR U.S. ozone season NOx gas input emission rate Ib/MMBtu 60 USFSNOR U.S. ozone season NOx fossil fuel input emission rate Ib/MMBtu 61 USCS02R U.S. annual S02 coal input emission rate Ib/MMBtu 62 USOS02R U.S. annual S02 oil input emission rate Ib/MMBtu 63 USGS02R U.S. annual S02 gas input emission rate Ib/MMBtu 64 USFSS2R U.S. annual S02 fossil fuel input emission rate Ib/MMBtu 65 USCC02R U.S. annual C02 coal input emission rate Ib/MMBtu 66 USOC02R U.S. annual C02 oil input emission rate Ib/MMBtu 67 USGC02R U.S. annual C02 gas input emission rate Ib/MMBtu 68 USFSC2R U.S. annual C02 fossil fuel input emission rate Ib/MMBtu 69 USCHGR U.S. annual Hg coal input emission rate Ib/BBtu 70 USFSHGR U.S. annual Hg fossil fuel input emission rate Ib/BBtu 71 USNBNOX U.S. annual NOx non-baseload output emission rate Ib/MWh 72 USNBNXO U.S. ozone season NOx non-baseload output emission rate Ib/MWh 73 USNBS02 U.S. annual S02 non-baseload output emission rate Ib/MWh 74 USNBC02 U.S. annual C02 non-baseload output emission rate Ib/MWh 75 USNBCH4 U.S. annual CH4 non-baseload output emission rate Ib/GWh 76 USNBN20 U.S. annual N20 non-baseload output emission rate Ib/GWh 77 USNBHG U.S. annual Hg non-baseload output emission rate Ib/GWh 78 USGENACL U.S. annual coal net generation MWh 79 USGENAOL U.S. annual oil net generation MWh 80 USGENAGS U.S. annual gas net generation MWh 81 USGENANC U.S. annual nuclear net generation MWh 82 USGENAHY U.S. annual hydro net generation MWh 83 USGENABM U.S. annual biomass net generation MWh 84 USGENAWI U.S. annual wind net generation MWh 85 USGENASO U.S. annual solar net generation MWh 86 USGENAGT U.S. annual geothermal net generation MWh 87 USGENAOF U.S. annual other fossil net generation MWh 88 USGENAOP U.S. annual other unknown/purchased fuel net generation MWh 89 USGENATN U.S. annual total nonrenewables net generation MWh 90 USGENATR U.S. annual total renewables net generation MWh 91 USGENATH U.S. annual total nonhydro renewables net generation MWh 92 USGENACY U.S. annual total combustion net generation MWh 93 USGENACN U.S. annual total noncombustion net generation MWh 94 USCLPR U.S. coal generation percent (resource mix) 95 USOLPR U.S. oil generation percent (resource mix) 96 USGSPR U.S. gas generation percent (resource mix) 97 USNCPR U.S. nuclear generation percent (resource mix) 98 USHYPR U.S. hydro generation percent (resource mix) 99 USBMPR U.S. biomass generation percent (resource mix) 100 USWIPR U.S. wind generation percent (resource mix) 101 USSOPR U.S. solar generation percent (resource mix) 102 USGTPR U.S. geothermal generation percent (resource mix) 103 USOFPR U.S. other fossil generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 97 ------- APPENDIX A Field Name Description Unit Source(s) 104 USOPPR U.S. other unknown/purchased fuel generation percent (resource mix) 105 USTNPR U.S. total nonrenewables generation percent (resource mix) 106 USTRPR U.S. total renewables generation percent (resource mix) 107 USTHPR U.S. total nonhydro renewables generation percent (resource mix) 108 USCYPR U.S. total combustion generation percent (resource mix) 109 USCNPR U.S. total noncombustion generation percent (resource mix) Abt Associates TSD for the 9,h Edition of eGRI | .xt 98 ------- APPENDIX A Table A-9. eGRID File Structure, Year 2010 GGL File, Grid Gross Loss (%) File Field Name Description Unit Source(s) 1 REGION One of the three interconnect power grids in the U.S. (plus Alaska, Hawaii, and the entire U.S.) 2 GENERAT The regional total net generation MWh 2010 FERC-714 updated by El A, but eGRID yr 2010 net generation for ASCC and HICC 3 FRGNINTC The regional net foreign interchange with Canada and Mexico (imports are positive) MWh 2010 FERC-714 updated by El A 4 INTRCHNG The regional total net interchange with a different U.S. region (imports are positive) MWh 2010 FERC-714 + updates 5 CONSUMP The regional total consumption MWh 2010 EIA-861 Files 1 & 2 + updates 6 GGRSLOSS The estimated regional grid gross loss as a percent [= 100 * (GENERAT + FRGNINTC+ INTRCHNG - CONSUMP) / GENERAT) ] % 7 YEAR Data year Abt Associates TSD for the 9,h Edition of eGRI | .xt 99 ------- APPENDIX B Appendix B. eGRID Subregion arid NERC Region Representational Maps Figure B-1. eGRID Subregion Representational Map [NEWE NWPP MROW, MROE NVCW RFCW SRMW RMPA] CAMX a2nm: AKMS AKGO 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. Abt Associates TSD for the 9th Edition of eGRID | pg. 100 ------- APPENDIX B Figure B-2. eGRID NERC Region Representational Map WECC HICC 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. Abt Associates TSD for the 9th Edition of eGRID | pg. 101 ------- |