DOE/EIA-0226(2001/08) Electric Power Monthly August 2001 With Data for May 2001 Energy Information Administration Office of Coal, Nuclear, Electric and Alternate Fuels U.S. Department of Energy Washington, DC 20585-0650 This report was prepared by the Energy Information Administration, the independent statistical and analytical agency within the Department of Energy. The information contained herein should not be construed as advocating or reflecting any policy position of the Department of Energy or any other organization. This report is available on the Web at: http://www.eia.doe.gov/cneaf/electricity/epm/epm.pdf
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DOE/EIA-0226(2001/08)
Electric Power MonthlyAugust 2001
With Data for May 2001
Energy Information AdministrationOffice of Coal, Nuclear, Electric
and Alternate FuelsU.S. Department of Energy
Washington, DC 20585-0650
This report was prepared by the Energy Information Administration, the independent statistical and analyticalagency within the Department of Energy. The information contained herein should not be construed asadvocating or reflecting any policy position of the Department of Energy or any other organization.
This report is available on the Web at:http://www.eia.doe.gov/cneaf/electricity/epm/epm.pdf
Energy Information Administration/Electric Power Monthly August 2001ii
The Electric Power Monthly is prepared by the U.S. Department of Energy's Energy Information Administration. Questionsand comments concerning the contents of the Electric Power Monthly may be directed to:
Mr. Melvin Johnson, Project LeaderEnergy Information Administration, EI-53U.S. Department of Energy1000 Independence Avenue, S.W.Washington, DC, 20585-0650
To ensure that this report meets the highest standards for quality and customersatisfaction, we encourage our readers to contact Melvin Johnson on (202) 287-1754(Internet:[email protected]) with comments or suggestionsto further improve the report.
New Electric Generating Units . . . . . . . . . . . . Thomas Williams 202-287-1926 [email protected]
New Nonutility Generatiing Units . . . . . . . . . . Betty Williams 202-287-1927 [email protected]
U.S. Electric Utility Net Generation . . . . . . . . . Melvin E. Johnson 202-287-1754 [email protected]
U.S. Electric Utility Consumption of Fuels . . . Melvin E. Johnson 202-287-1754 [email protected]
U.S. Electric Utility Stocks of Fuels . . . . . . . . Melvin E. Johnson 202-287-1754 [email protected]
U.S. Electric Utility Fossil-Fuel Receipts . . . . . Kenneth McClevey 202-287-1732 [email protected]
U.S. Electric Utility Fossil-Fuel Costs . . . . . . . Kenneth McClevey 202-287-1732 [email protected]
U.S. Retail Sales of Electricity . . . . . . . . . . . . Deborah Johnson 202-287-1970 [email protected]
U.S. Nonutility Net Generation . . . . . . . . . . . . Barbara Rucker 202-287-1765 [email protected]
U.S. Nonutility Consumption of Fuels . . . . . . . Barbara Rucker 202-287-1765 [email protected]
U.S. Nonutility Stocks of Fuels . . . . . . . . . . . . Barbara Rucker 202-287-1765 [email protected]
Sampling and Estimation Methodologies . . . . James Knaub, Jr. 202-287-1733 [email protected]
Requests for additional information on other energy statistics available from the Energy Information Administration or questionsconcerning subscriptions and report distribution may be directed to the National Energy Information Center at 202-586-8800 (TTY:for people who are deaf or hard of hearing, 202-586-1181).
Energy Information Administration/Electric Power Monthly August 2001 iii
Preface
The Electric Power Monthly (EPM) presents monthlyelectricity statistics for a wide audience includingCongress, Federal and State agencies, the electric utilityindustry, and the general public. The purpose of thispublication is to provide energy decisionmakers withaccurate and timely information that may be used informing various perspectives on electric issues that lieahead. The EIA collected the information in this reportto fulfill its data collection and disseminationresponsibilities as specified in the Federal EnergyAdministration Act of 1974 (Public Law 93-275) asamended.
Background
The Electric Power Division; Office of Coal, Nuclear,Electric and AlternateFuels, Energy Information Admin-istration (EIA), Department of Energy prepares the EPM.This publication provides monthly statistics at the State,Census division, and U.S. levels for net generation, fossilfuel consumption and stocks, quantity and quality offossil fuels, cost of fossil fuels, electricity retail sales,associated revenue, and average revenue per kilo-watthour of electricity sold. In addition, data on netgeneration, fuel consumption, fuel stocks, quantity and
cost of fossil fuels are also displayed for the NorthAmerican Electric Reliability Council (NERC) regions.
The EIA publishes statistics in the EPM on netgeneration by energy source; consumption, stocks,quantity, quality, and cost of fossil fuels; and capabilityof new generating units by company and plant.
Data Sources
The EPM contains information from the following datasources: Form EIA-759, “Monthly Power Plant Report”;Federal Energy Regulatory Commission (FERC) Form423, “Monthly Report of Cost and Quality of Fuels forElectric Plants”; Form EIA-900, “Monthly NonutilityPower Report”; Form EIA-826, “Monthly Electric UtilitySales and Revenue Report with State Distributions”;Form EIA-861, “Annual Electric Utility Report”; FormEIA-860A, “Annual Electric Generator Report B Utility;”Form EIA-860B, “Annual Electric Generator Report BNonutility”; and the Form EIA-906, “Power PlantReport” (Regulated and Nonregulated). Copies of theseforms and their instructions may be obtained from theNational Energy Information Center. A detailed descrip-tion of these forms is in Appendix B, “Technical Notes.”
Energy Information Administration/Electric Power Monthly August 2001iv
Office of Coal, Nuclear, Electric and Alternate FuelsElectric Power Industry Related Data: Available in Electronic Form
(as of August 2001)
Internet
CD-ROM Diskette
PortableDocument
Format(PDF)
ExecutableData Files
HypertextMarkup
Language(HTML)
Surveys:
Form EIA-412: Annual Report of PublicElectric Utilities
X X
Form EIA-767: Steam-ElectricOperation and Design Report
X X X
Form EIA-826: Monthly Electric UtilitySales and Revenue Report with StateDistributions
X X X X
Form EIA-860A: Annual ElectricGenerator Report - Utility
X X X X
Form EIA-860B: Annual ElectricGenerator Report - Nonutility
X
Form EIA-861: Annual Electric UtilityReport
X X X X
Form EIA-906: Power Plant Report(Regulated)
X X X X
Form EIA-906: Power Plant Report(Nonregulated)
X X
FERC Form 1: Annual Report of MajorElectric Utilities, Licensees, and Others
X X
FERC Form 423: Monthly Report ofCost and Quality of Fuels for ElectricPlants
X X
Publications:
Electric Power Monthly X X X
Data tables for Form EIA-906,Form EIA-826, Form EIA-860 (new unitsonly), and FERC Form 423
X X
Electric Power Annual Volume I X X X
Electric Power Annual Volume II X X X
Inventory of Power Plants in the UnitedStates
X X X
Electric Sales and Revenue X X X
Financial Statistics of Major U.S.Investor Owned Electric Utilities
X X
Financial Statistics of Major U.S.Publicly Owned Electric Utilities
X X X
Note: If you have any questions and/or need additional information, please contact the National Energy Information Center at(202) 586-8800.
Energy Information Administration/Electric Power Monthly August 2001 v
Energy Information Administration/Electric Power Monthly August 2001vi
Tables
1. New U.S. Electric Generating Units by Operating Company, Plant, and Month, 2001 . . . . . . . . . . . . . . . . . . 62. U.S. Electric Power Industry Summary Statistics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73. U.S. Electric Utility Net Generation, 1990 Through May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 94. U.S. Electric Utility Net Generation by Nonrenewable Energy Source, 1990 Through May 2001 . . . . . . . . 105. U.S. Electric Utility Net Generation by Renewable Energy Source, 1990 Through May 2001 . . . . . . . . . . . . 116. Electric Utility Net Generation by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127. Electric Utility Net Generation by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138. Electric Utility Net Generation from Coal by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . . . . . . 149. Electric Utility Net Generation from Petroleum by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . 15
10. Electric Utility Net Generation from Gas by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1611. Electric Utility Hydroelectric Net Generation by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . . . 1712. Electric Utility Nuclear-Powered Net Generation by Census Division and State . . . . . . . . . . . . . . . . . . . . . 1813. Electric Utility Net Generation from Other Energy Sources by Census Division and State . . . . . . . . . . . . . 1914. U.S. Electric Utility Consumption of Fossil Fuels, 1990 Through May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . 2115. Electric Utility Consumption of Coal by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2216. Electric Utility Consumption of Petroleum by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . 2217. Electric Utility Consumption of Gas by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2318. Electric Utility Consumption of Coal by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2419. Electric Utility Consumption of Petroleum by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . . . . . 2520. Electric Utility Consumption of Gas by Census Division and State . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2621. U.S. Electric Utility Stocks of Coal and Petroleum, 1990 Through May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . 2722. Electric Utility Stocks of Coal by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2823. Electric Utility Stocks of Petroleum by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2824. Electric Utility Stocks of Coal by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2925. Electric Utility Stocks of Petroleum by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2926. U.S. Electric Utility Receipts of and Average Cost for Fossil Fuels, 1990 Through April 2001 . . . . . . . . . . . 3227. Electric Utility Receipts of Coal by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3328. Average Cost of Coal Delivered to Electric Utilities by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . 3329. Electric Utility Receipts of Petroleum by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3430. Average Cost of Petroleum Delivered to Electric Utilities by NERC Region and Hawaii . . . . . . . . . . . . . . 3431. Electric Utility Receipts of Gas by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3532. Average Cost of Gas Delivered to Electric Utilities by NERC Region and Hawaii . . . . . . . . . . . . . . . . . . . . 3533. Electric Utility Receipts of Coal by Type, Census Division, and State, April 2001 . . . . . . . . . . . . . . . . . . . . 3634. Receipts and Average Cost of Coal Delivered to Electric Utilities by Census Division and State . . . . . . . . 3735. Receipts and Average Cost of Coal Delivered to Electric Utilities by Type of Purchase,
Mining Method, Census Division, and State, April 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3836. Receipts and Average Cost of Coal Delivered to Electric Utilities by Sulfur Content, Census Division,
and State, April 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3937. Electric Utility Receipts of Petroleum by Type, Census Division, and State, April 2001 . . . . . . . . . . . . . . . 4138. Receipts and Average Cost of Petroleum Delivered to Electric Utilities by Census Division and State . . . 4239. Receipts and Average Cost of Petroleum Delivered to Electric Utilities by Type of Purchase,
Census Division, and State, April 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4340. Receipts and Average Cost of Heavy Oil Delivered to Electric Utilities by Sulfur Content,
Census Division, and State, April 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4441. Electric Utility Receipts of Gas by Type, Census Division, and State, April 2001 . . . . . . . . . . . . . . . . . . . . . 4642. Receipts and Average Cost of Gas Delivered to Electric Utilities by Census Division and State . . . . . . . . . 4743. Receipts and Average Cost of Gas Delivered to Electric Utilities by Type of Purchase, Census Division,
49. Estimated Revenue from U.S. Electric Utility Retail Sales of Electricity to Ultimate Consumers by Sector,Census Division, and State, May 2001 and 2000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54
50. Estimated Coefficients of Variation for Revenue from U.S. Electric Utility Retail Sales of Electricityto Ultimate Consumers by Sector, Census Division, and State, May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . 55
51. Estimated Revenue from U.S. Electric Utility Retail Sales to Ultimate Consumers by Sector,Census Division, and State, Year-to-Date (May) 2001 and 2000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56
52. U.S. Electric Utility Average Revenue per Kilowatthour by Sector, 1990 Through May 2001 . . . . . . . . . . . 5753. Estimated U.S. Electric Utility Average Revenue per Kilowatthour to Ultimate Consumers by Sector,
Census Division, and State, May 2001 and 2000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5854. Estimated Coefficients of Variation for U.S. Electric Utility Average Revenue per Kilowatthour to
Ultimate Consumers by Sector, Census Division, and State, May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5955. Estimated U.S. Electric Utility Average Revenue per Kilowatthour to Ultimate Consumers by Sector,
Census Division, and State, Year-to-Date (May) 2001 and 2000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6056. U.S. Electric Utility Net Generation and Fuel Consumption, by Company and Plant, May 2001 . . . . . . . . 6157. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. Electric Utilities by Company
and Plant, April 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9458. U.S. Nonutility Net Generation, 1990 Through May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10959. U.S. Nonutility Net Generation by Nonrenewable Energy Source, 1990 Through May 2001 . . . . . . . . . . . 11060. U.S. Nonutility Net Generation by Renewable Energy Source, 1990 Through May 2001 . . . . . . . . . . . . . . 11161. Nonutility Net Generation by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11262. Nonutility Net Generation from Coal by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11263. Nonutility Net Generation from Petroleum by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11364. Nonutility Net Generation from Gas by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11365. Nonutility Hydroelectric Net Generation by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11466. Nonutility Net Generation from Nuclear by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11467. Nonutility Net Generation from Other Energy Sources by Census Division . . . . . . . . . . . . . . . . . . . . . . . . 11568. U.S. Nonutility Consumption of Fossil Fuels, 1990 Through May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11769. Nonutility Consumption of Coal by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11870. Nonutility Consumption of Petroleum by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11871. Nonutility Consumption of Gas by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11972. U.S. Nonutility Stocks of Coal and Petroleum, 1990 Through May 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . 12173. Nonutility Stocks of Coal by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12274. Nonutility Stocks of Petroleum by Census Division . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12275. U.S. Electric Nonutility Net Generation and Fuel Consumption, by Owner and Facility, May 2001 . . . . . 125B1. Major Disturbances and Unusual Occurrences, 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 156C1. Average Heat Content of Fossil-Fuel Receipts, April 2001 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 167C2. Comparison of Preliminary Versus Final Published Data at the U.S. Level, 1995 Through 1999 . . . . . . . . 168C3. Unit-of-Measure Equivalents for Electricity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 169C4. Comparison of Sample Versus Census Published Data at the U.S. Level, 1998 and 1999 . . . . . . . . . . . . . . 170C5. Estimated Coefficients of Variation for Electric Utility Net Generation by State, May 2001 . . . . . . . . . . . . 172C6. Estimated Coefficients of Variation for Electric Utility Fuel Consumption and Stocks by State,
Energy Information Administration/Electric Power Monthly August 2001viii
Illustrations
C1. North American Electric Reliability Council Regions for the Contiguous United States,Alaska and Hawaii . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171
Energy Information Administration/Electric Power Monthly August 2001 1
Monthly Update
Net Generation Year-to-Date 2001
During the first 5 months of the year, total U.S. netgeneration of electricity was 1,520 billion kilowatthours,1 percent higher than the amount reported during thecorresponding period in 2000. More than half (52percent) of the generation was produced by coal-firedplants. This was followed by 20 percent from nuclear,15 percent from gas, 6 percent from hydro, 4 percentfrom petroleum, and 2 percent from renewables.
Net Generation and Utility RetailSalesCMay 2001
Net Generation. Total U.S. net generation of electricitywas 307 billion kilowatthours, 2 percent below theamount reported in May 2000. Electric utilitiesgenerated 219 billion kilowatthours (71 percent of totalgeneration) and nonutility power producers generated88 billion kilowatthours (29 percent of total generation).At utilities, fossil fuels (primarily coal) accounted for 72percent of net generation, followed by 20 percent fromnuclear, and 8 percent from renewable resources(including hydro). At nonutilities, fossil fuels (primarilygas) accounted for 69 percent of total generation,followed by 21 percent from nuclear, and 11 percentfrom renewables (including hydro).
Utility Retail Sales. Total sales of electricity to ultimateconsumers in the United States were 262 billion kilo-watthours, 4 billion kilowatthours (2 percent) less thanthe amount reported in May 2000. The residential sectorhad sales of 82 billion kilowatthours, 2 percent less thanthe amount reported in May 2000. Retail sales in thecommercial sector were 4 percent higher while sales inthe industrial sector were 7 percent lower than amountsreported a year ago.
Coal. Receipts of coal at electric utilities totaled 60million short tons, down 3 million short tons from the
level reported in April 2000. This decrease from theprior year level is due primarily to data for the Ten-nessee Valley Authority not being available at the timeof publication. In addition, the sale and reclassificationof utility plants as nonutility plants has reduced thenumber of facilities that submit data on the FederalEnergy Regulatory Commission (FERC)Form423. Plantsrecently reclassified as nonutility and no longer requiredto report fuel receipts on the Federal Energy RegulatoryCommission (FERC) Form 423 include those operated byAtlantic City Electric Company, Baltimore Gas &Electric Company, Cajun Electric Power Cooperative,Central Hudson Gas & Electric Company, DuquesneLight Company, PECO Energy, Pennsylvania Power &Light Company, Potomac Edison Company, PotomacElectric Power Company, and Public Service Electric &Gas Company of New Jersey.
Petroleum. Receipts of petroleum totaled 10 millionbarrels, up nearly 5 million barrels from the levelreported in April 2000. While the sale and reclassi-fication of plants has tended to reduce fuel oil receiptsover the past year, this increase in petroleum receipts isdue primarily to some utilities switching from naturalgas to a less expensive fuel oil as a replacement fuel. Forthe month, the average delivered cost of fuel oil was$4.05 per million Btu, up from $3.90 per million Btureported in April 2000.
Gas. Receipts of gas totaled 178 billion cubic feet (Bcf),down from 200 Bcf reported in April 2000. The averagecost of gas delivered to electric utilities was $5.64 permillion Btu, compared to $3.16 per million Btu reportedin April 2000. Less expensive fuel oil has reduced theamount of natural gas consumed by electric utilities,especially in the Middle Atlantic and South AtlanticCensus Divisions. In addition, the sale and reclassi-fication of electric plants is having a large affect on gasreceipt data presented at the New England, MiddleAtlantic, and Pacific Contiguous Census Divisions, aswell as at the National level.
Energy Information Administration/Electric Power Monthly August 20012
After an electric utility plant is sold/transferred to a nonregulated entity, data on net generation, fuel consumption, andfuel stocks for that plant (with a nameplate capacity rating of 50 megawatts or more) will be collected on the EIA-900,“Monthly Nonutility Power Report.” Consequently, a comparison of data between the year 2000 and historical years atthe State, Census Division, and U.S. level will be affected by the reclassification of plants.
Electric Utility Plants Sold/Transferred and Reclassified as Nonutility Plants in 2001
Utility Plant State
NameplateCapacity
(megawatts) Datea Buyer
Commonwealth Edison Co Dresden 2 IL 828 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co Dresden 3 IL 828 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co Quad Cities 1 IL 828 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co Quad Cities 2 IL 828 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co Braidwood 1 IL 1,225 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co Braidwood 2 IL 1,225 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co Byron 1 IL 1,225 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co Byron 2 IL 1,225 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co LaSalle 1 IL 1,170 January 1, 2001 Exelon Generation, LLC
Commonwealth Edison Co LaSalle 2 IL 1,170 January 1, 2001 Exelon Generation, LLC
Philadelphia Electric Co Conowingo MD 474 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Chester PA 56 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Cromby PA 420 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Delaware PA 392 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Eddystone PA 1,569 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Falls PA 64 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Moser PA 64 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Muddy Run PA 800 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Richmond PA 198 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Schuyl Kill PA 233 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Southwork PA 74 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Croydon PA 546 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Fairless Hills PA 75 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Limerick 1 PA 1,138 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Limerick 2 PA 1,092 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Peachbottom 1 PA 1,152 January 1, 2001 Exelon Corporation
Philadelphia Electric Co Peachbottom 2 PA 1,152 January 1, 2001 Exelon Corporation
Central Hudson Gas & Elec Corp Danskammer NY 537 January 30, 2001 Dynergy Power Marketing
Central Hudson Gas & Elec Corp Roseton NY 1,242 January 30, 2001 Dynergy Power Marketing
Northeast Nuclear Energy Co Millstone 2 CT 910 March 31, 2001 Dominion Nuclear Connecticut, Inc
Northeast Nuclear Energy Co Millstone 3 CT 1,253 March 31, 2001 Dominion Nuclear Connecticut, Inc
aStart date for facility to begin reporting as a nonutility generator.Source: Energy Information Administration, Office of Coal, Nuclear, Electric and Alternate Fuels, U.S. Department of Energy.
Energy Information Administration/Electric Power Monthly August 2001 3
Electricity Supply and Demand(Billion Kilowatthours)
Electric Utilities b . . . . . . . . . . . 206.0 198.2 238.1 213.8 856.2aOther includes generation from wind, wood, waste, and solar sources.bElectricity from nonutility sources, including cogenerators and small power
producers. Quarterly numbers for nonutility net sales, own use, and generationby fuel source supplied by the Office of Coal, Nuclear, Electric and AlternateFuels, Energy Information Administration (EIA), based on annual data reportedto EIA on Form EIA-860B, “Annual Electric Generator Report – Nonutility.”
cIncludes refinery still gas and other process or waste gases, and liquefiedpetroleum gases.
eBalancing item, mainly transmission and distribution losses.Notes: !Minor discrepancies with other EIA published historical data are due
to rounding. !Historical data are printed in bold, estimates and forecasts are initalic. !The forecasts were generated bysimulation of the Short-Term IntegratedForecasting System. !Mid World Oil Price Case.
Sources: Historical Data and Estimates: Energy Information Administration,latestdataavailable from EIA databases supporting the following reports: ElectricPower Monthly, DOE/EIA-0226 and Monthly Energy Review, DOE/EIA-0035;Forecasts: Energy Information Administration, Short-Term IntegratedForecasting System database,andOfficeofCoal,Nuclear, Electric and AlternateFuels.
Electricity Supply and Demand Forecast for 20011
The EIA prepares a short-term forecast for electricity thatis published in the Short-Term Energy Outlook. This pageprovides that forecast for the current year along withexplanations behind the forecast.2
! Total annual electricity demand growth is projectedat about 2.2 percent in 2001 and 1.9 percent in 2002.This is compared with estimated demand growth in2000 of 3.7 percent over the previous year's level.Electricity demand growth is expected to be some-what slower in the forecast years than it was in 2000partly because the economy is growing more slowlythan it was in 2000.
! As a result of deregulation, a considerable numberof nuclear generating plants have been sold by theutility sector to the nonutility sector. This change inownership, however, is not expected to impact onoverall generation levels. In 2000, total nucleargeneration of electricity in both sectors increased by3.5 percent over the previous year. However, in 2001and 2002 total nuclear generation of electricity isexpected to be up only marginally.
! This summer's overall cooling degree-days (CDD)are projected to be 4.2 percent above normal basedon April through September temperatures, andabout the same percent above last summer's CDDtotal. Summer electricity demand is expected to be1.9 percent higher than last summer based on eco-nomic factors, i.e., still rising GDP, albeit less rapidthan last year, higher housing stocks and employ-ment as well as weather (last summer was just aboutnormal in temperature).
! Hydropower generation in the crucial PacificNorthwest is expected to be down by 16 percentfrom last summer, due mainly to lower water levels.According to the National Oceanic and AtmosphericAssociation, this winter was the second driest winteron record, after the 1976/77 winter. In addition,California electricity needs during this past winterfurther drained reservoirs, depriving the region ofhydroelectric generation resources for this springand summer.
1Energy Information Administration, Short-Term Energy Outlook:July 2001, DOE/EIA-0202 (Washington, DC, July 2001),www.eia.doe.gov/emeu/steo/pub/pdf/jul01.pdf.
2Further questions on this section may be directed to the NationalEnergy Information Center at 202-586-8800 (Internet:[email protected]).
Energy Information Administration/Electric Power Monthly August 20014
Heating Degree-Days by Census Division, May 2001
Census Division Number of Degree-Days Percent Change
Normal*
2000 2001Normalto 2001
2000to 2001
New England 275 281 252 -8 -10
Middle Atlantic 200 172 170 -15 -1
East North Central 217 158 162 -25 2
West North Central 189 147 162 -14 10
South Atlantic 51 34 43 NM NM
East South Central 63 30 46 NM NM
West South Central 10 13 9 NM NM
Mountain 231 168 172 -26 2
Pacific Contiguous 183 147 94 -49 -36
U.S. Average 150 119 113 -25 -5
*“Normal” is based on calculations using temperature data from 1961 through 1990.
(s)= Less than 0.5 percent and greater than -0.5 percent.Notes: ! Heating Degree-days are relative measures of outdoor air temperature used as indices of heating energy
requirements. ! Heating degree-days are the number of degrees per day that the daily average temperature fallsbelow 65 degrees Fahrenheit. The daily average temperature is the mean of the minimum and maximum temperaturesin a 24-hour period.
Source: National Oceanic and Atmospheric Administration’s National Weather Service Climate Analysis Center.
Energy Information Administration/Electric Power Monthly August 2001 5
Cooling Degree-Days by Census Division, May 2001
Census Division Number of Degree-Days Percent Change
Normal*
2000 2001Normalto 2001
2000to 2001
New England 5 12 25 NM NM
Middle Atlantic 24 42 29 NM NM
East North Central 52 56 39 NM NM
West North Central 72 80 61 NM NM
South Atlantic 176 239 191 8 -20
East South Central 142 213 168 18 -21
West South Central 253 350 285 13 -19
Mountain 85 147 159 NM NM
Pacific Contiguous 31 51 85 NM NM
U.S. Average 95 131 113 NM NM
*“Normal” is based on calculations using temperature data for 1961 through 1990.
Notes: ! Cooling degree-days are relative measures of outdoor air temperature used as indices of cooling energyrequirements. ! Cooling degree-days are the number of degrees per day that the daily average temperature fallsabove 65 degrees Fahrenheit. The daily average temperature is the mean of the minimum and maximum temperaturesin a 24-hour period.
Source: National Oceanic and Atmospheric Administration’s National Weather Service Climate Analysis Center.
Table 1. New U.S. Electric Generating Units by Operating Company, Plant, and Month, 2001
Net Generating Unit Month/ Type Summer Energy Plant State Unit Type Company Co Capability1 Source Number Code (megawatts)
JanuaryDeshler City of ............................................ U Deshler NE 1A 0.3 Petroleum ICFloride Keys El Coop Assn Inc.................. U Marathon FL 11 3.4 Petroleum ICRantoul Village of....................................... U Rantoul IL 15,16 3.6 Petroleum ICRiver Falls City of ...................................... U Junction WI 10 2.9 Petroleum ICCalpine Construction Finance Corp............ N Westbrook Energy Center ME STG3 160 Waste Heat CALowndes County Hospital Auth ................. N South Georgia Medical Cntr GA GEN4 .7 Petroleum ICNorthern Alternative Energy....................... N Florence Hills LLC MN FH30 1.9 Wind WTNorthern Alternative Energy....................... N Hope Creek LLC MN HC30 1.9 Wind WTNorthern Alternative Energy....................... N Ruthton Ridge LLC MN RR30 1.9 Wind WTNorthern Alternative Energy....................... N Soliloquoy Ridge LLC MN SR30 1.9 Wind WTNorthern Alternative Energy....................... N Winters Spawn LLC MN WS30 1.9 Wind WTNorthern Alternatives Energy ..................... N Spartan Hills LLC MN SH30 1.9 Wind WTTrigen Cinergy Solution Tuscola................ N Tuscola Station IL TG3 5.5 Coal ST
FebruaryArizona Public Service................................ U Solar AZ 1 .4 Solar PVDanville City of........................................... U Talbott VA 1 .7 Water HYSabetha City of............................................ U Sabetha KS 12 4.1 Petroleum ICStuart City of............................................... U Gilliam South IA 1 1.8 Petroleum ICThief River Falls City of ............................ U Thief River Falls MN IC3A 1.3 Petroleum ICTipton City of.............................................. U Tipton IA 1A 2 Gas ICNorthern Alternative Energy....................... N Jack River LLC MN JR30 1.9 Wind WTNorthern Alternative Energy....................... N Agassiz Beach LLC MN AB30 1.9 Wind WTNorthern Alternative Energy....................... N Autumn Hills LLC MN AH30 1.9 Wind WTNorthern Alternative Energy....................... N Jessica Mills LLC MN JM30 1.9 Wind WTNorthern Alternative Energy....................... N Julia Hills LLC MN JH30 1.9 Wind WTNorthern Alternative Energy....................... N Sun River LLC MN SU30 1.9 Wind WTNorthern Alternative Energy....................... N Tasr Nicholas LLC MN TN30 1.9 Wind WTSierra Pacific Industries Inc........................ N Sonora CA GEN2 7 Wood ST
MarchSpringfield Public Utils............................... U Springfield MN 9 1.8 Petroleum ICToledo Edison Co........................................ U Richland OH 4 114.8 Gas IC
5 114.8 Gas IC6 114.8 Gas IC
ANP Bellingham Energy Co ...................... N ANP Bellingham Energy Project MA UI 225 Gas GTCalpine Construction Finance..................... N South Point Energy Center AZ A,B 401 Gas GTDoswell LP .................................................. N Doswell Combined Cycle VA GEN7 159 Waste Heat CAEl Paso Electric Co ..................................... N Hueco Mountain Wind Ranch TX EXIS 1.3 Wind WTPine Bluff Energy LLC............................... N Pine Bluff Energy Center AR CT01 165 Gas CTSan Antonio Community Hospital.............. N San Antonio Community Hospital CA 2076 .87 Gas IC
AprilAssociated Electric Coo .............................. U St Francis MO 2 248.5 Gas CSGreat River Energy ..................................... U Pleasant Valley MN 1 149.6 Gas GT
2 149.6 Gas GTSacramento Municipal U ............................ U SCA CA CTIC 37.9 Gas CTANP Bellingham Energy Co ...................... N ANP Bellingham Energy Project MA U2,GT21 447 Gas GTCalpine Constr Finance Corp...................... N Westbrook Energy Center ME STG3 160 Waste Heat CACalpine Construction Finance..................... N South Point Energy Center AZ ST1 203 Waste Heat CADuke Energy Lee County ........................... N Lee County Generating Station IL CT6,CT7,CT8 204 Gas GT
CT1,CT2,CT5 204 Gas GTMerck & Co Inc West Point....................... N West Point Facility PA COG3 493 Gas GT
MayHolton City Of ............................................ U Holton KS 12 3.1 Petroleum IC
13 3.1 Petroleum ICJEA .............................................................. U Brandy Branch FL 1 158.6 Gas GT
2 158.6 Gas GTLincoln Electric System.............................. U Rokeby NE 3 81.1 Gas GTMadelia City Of .......................................... U Madelia MN 1 3.1 Gas ICVirginia Electric & Power .......................... U Ladysmith VA 1 151.7 Gas GT
2 151.7 Gas GTAES Ironwood Inc ...................................... N AES Ironwood PA CT1,CT2 404 Gas CTCalcasieu Power LLC ................................. N Calcasieu Power LLC LA G102 157 Gas GTDuke Energy Lee County LLC .................. N Lee County Generating Station IL CT3,CT4 136 Gas GTHeard County Power LLC.......................... N Heard Power County LLC GA CT1,CT2,CT3 426 Gas GTNRG So Central Generating LLC .............. N NRG Sterlington Power LLC LA 06,07 43 Gas GTONEOK Power Marketing Co.................... N Spring Creek Power Plant OK CT01 thru CT04 306 Gas GTPEI Power II LLC....................................... N PEI Power II LLC PA GEN2 35 Gas GTUniversity Park Energy LLC...................... N University Park Energy LLC IL UPG1 thru UPG6 301 Gas GTWFEC GENCO LLC .................................. N WFEC GENCO OK GEN1,GEN2 77 Gas GTWolf Hills Energy LLC .............................. N Wolf Hills Energy LLC VA WHG1 thru WHG5 251 Gas GT
Total Capability of Newly AddedUnits ......................................................... −- −- −- −- 6,660.4 −- −-
Total Capability of Retired Units............... −- −- −- −- 12.4 −- −- RU.S. Total Capability ................................... −- −- −- −- 818,172.8 −- −-
1 Net summer capability is estimated.R = Revised data.
Notes: •Totals may not equal sum of components because of independent rounding. •Data are preliminary. Final data for the year are to be releasedin the Inventory of Electric Utility Power Plants in the United States (DOE/EIA-0095) and Inventory of Nonutility Electric Power Plants in the United States(DOE/EIA-0095/2). •Type Companies are: U=Utility and N=Nonutility. •Unit Type Codes are: CA=Combined Cycle Steam, CC=Combined Cycle - TotalUnit, CT=Combined Cycle Combustion Turbine, CW=Combined Cycle Steam Turbine - Waste Heat Boiler only, GT=Combustion (gas) Turbine, HY=Hy-draulic Turbine (conventional), IC=Internal Combustion, PV=Photovoltaic Module, ST=Steam Turbine-Boiler, WT=Wind Turbine.
Energy Information Administration/Electric Power Monthly August 20016
Table 2. U.S. Electric Power Industry Summary Statistics
Year To Date May April May Items 2001 2001 2000 Difference 2001 2000 (percent)
Electric Power IndustryNet Generation (Million kWh)
1 Values are estimates based on a cutoff sample; see Technical Notes for a discussion of the sample design for Form EIA-900.2 Values for 2001 are estimates based on a cutoff model sample; see Technical Notes for a discussion of the sample design for the Form EIA-
759; 2000 estimates have been adjusted to reflect the Form EIA-759 census data and are final; see Technical Notes for adjustment methodology.3 Includes petroleum coke.4 Represents total pumped storage facility production minus energy used for pumping. Pumping energy used at pumped storage plants for May
2001 was 2,604 million kilowatthours.5 The May 2001 petroleum coke consumption was 76,869 short tons for electric utilities and 360,799 short tons for nonutilities.6 The May 2001 petroleum coke stocks were 129,930 short tons.7 •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample; see Technical Notes for a discussion of
the sample design for the Form EIA-826. See Technical Notes for the adjustment methodology. Retail revenue and retail average revenue perkilowatthour do not include taxes such as sales and excise taxes that are assessed on the consumer and collected through the utility. Retail salesand net generation may not correspond exactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricityfrom nonutilities or imported electricity). Net generation is for the calendar month while retail sales and associated revenue accumulate from billscollected for periods of time (28 to 35 days) that vary dependent upon customer class and consumption occurring in and outside the calendarmonth.
8 Includes public street and highway lighting, other sales to public authorities, sales to railroads and railways, sales to farms for irrigation, andinterdepartmental sales.
9 Values are preliminary for 2001 and final for 2000.10 The April 2001 petroleum coke receipts were 117,556 short tons.11 Average cost of fuel delivered to electric generating plants; cost values are weighted values.12 April 2001 petroleum coke cost was 74.3 cents per million Btu.13 Includes small amounts of coke-oven, refinery, and blast-furnace gas.* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.
NA = Data are not available.NM = This value may not be applicable or the percent difference calculation is not meaningful.
Notes: •Totals may not equal sum of components because of independent rounding. •Percent difference is calculated before rounding.•kWh=kilowatthours, and Mcf=thousand cubic feet. •Monetary values are expressed in nominal terms.
Sources: •Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; Form EIA-826, ‘‘Monthly Electric Utility Salesand Revenue Report with State Distributions’’; Form EIA-900, ‘‘Monthly Nonutility Power Report’’; Form EIA-906, ‘‘Power Plant Report’’; •FederalEnergy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 20018
U.S. Electric Utility Net Generation
Table 3. U.S. Electric Utility Net Generation, 1990 Through May 2001(Million Kilowatthours)
Hydro- Period Coal Petroleum1 Gas2 Nuclear Geothermal Other3 Total electric
1 Includes fuel oils nos. 1, 2, 4, 5, and 6, crude oil, kerosene, and petroleum coke2 Includes supplemental gaseous fuel.3 Includes biomass, wind, photovoltaic, and solar thermal energy sources.* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.
Notes: •Values for electric utilities for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample designfor the Form EIA-759. Values for electric utilities for 2000 have been adjusted to reflect the Form EIA-759 census data and are final--see Technical Notesfor adjustment methodology. Values for electric utilities for 1999 and prior years are final. •Totals may not equal sum of components because of independ-ent rounding. •Monthly values reflect the latest adjustments applied to the estimated data based on the final census data. •Due to restructuring of theelectric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 1990-2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, FormEIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 9
Table 4. U.S. Electric Utility Net Generation by Nonrenewable Energy Source, 1990 ThroughMay 2001(Million Kilowatthours)
All Nonrenewable Hydroelectric3 Period Coal1 Petroleum2 Gas Nuclear Energy Sources (Pumped Storage)
1 Includes lignite, bituminous coal, subbituminous coal, and anthracite.2 Includes fuel oil Nos. 1, 2, 4, 5, and 6, crude oil, kerosene, and petroleum coke.3 Pumping energy used for pumped storage plants was 2,604 million kilowatthours.
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final--see Technical Notes for adjustment methodology. Valuesfor 1999 and prior years are final. •Monthly values reflect the latest adjustments applied to the estimated data based on the final census data. •Totalsmay not equal sum of components because of independent rounding. Due to restructuring of the electric power industry, electric utilities are selling plants tothe nonutility sector. This will affect comparisons of current and historical data.
Sources: 1990-2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, FormEIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200110
Table 5. U.S. Electric Utility Net Generation by Renewable Energy Source, 1990 ThroughMay 2001(Thousand Kilowatthours)
All Renewable Hydroelectric Period Geothermal Biomass Wind Photovoltaic Energy Sources (Conventional)
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final--see Technical Notes for adjustment methodology. Valuesfor 1999 and prior years are final. •Monthly values reflect the latest adjustments applied to the estimated data based on the final census data. •Totalsmay not equal sum of components because of independent rounding. Due to restructuring of the electric power industry, electric utilities are selling plants tothe nonutility sector. This will affect comparisons of current and historical data.
Sources: 1990-2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, FormEIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 11
Table 6. Electric Utility Net Generation by NERC Region and Hawaii(Million Kilowatthours)
Year to Date NERC Region May April May and Hawaii 2001 2001 2000 Difference 2001 2000 (percent)
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •See Glossary for explanation of acronyms. •Due to restructuring of the electricpower industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200112
Table 7. Electric Utility Net Generation by Census Division and State(Million Kilowatthours)
Year to DateCensus Division May April May
and State 2001 2001 2000 Difference 2001 2000 (percent)
U.S. Total ....................................... 219,021 199,971 253,890 1,075,449 1,225,633 −12.3
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. Due to restructuring of the electric power industry, electric utilities are selling plantsto the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 13
Table 8. Electric Utility Net Generation from Coal by Census Division and State(Million Kilowatthours)
Year to Date
Census Division May April May Coal Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 128,666 117,933 134,171 646,350 683,286 −5.4 60.1 55.7
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-
ble, or the percent difference calculation is not meaningful.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Negative generation denotes that electric power con-sumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent difference is calcu-lated before rounding. •Coal includes lignite, bituminous coal, subbituminous coal, and anthracite. Due to restructuring of the electric power industry, electricutilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200114
Table 9. Electric Utility Net Generation from Petroleum by Census Division and State(Million Kilowatthours)
Year to Date
Census Division May April May Petroleum Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 7,062 6,879 5,743 38,150 19,782 92.9 3.5 1.6
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-
ble, or the percent difference calculation is not meaningful.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Negative generation denotes that electric power con-sumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent difference is calcu-lated before rounding. •Includes fuel oil Nos. 1, 2, 4, 5, and 6, crude oil, kerosene, and petroleum coke. Due to restructuring of the electric power industry,electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 15
Table 10. Electric Utility Net Generation from Gas by Census Division and State(Million Kilowatthours)
Year to Date
Census Division May April May Gas Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 22,761 20,565 29,146 89,035 104,587 −14.9 8.3 8.5
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-
ble, or the percent difference calculation is not meaningful.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Negative generation denotes that electric power con-sumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent difference is calcu-lated before rounding. Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This will affect compari-sons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200116
Table 11. Electric Utility Hydroelectric Net Generation by Census Division and State(Million Kilowatthours)
Year to Date
Census Division May April May Hydroelectric Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 17,059 15,401 24,755 82,903 117,646 −29.5 7.7 9.6
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-
ble, or the percent difference calculation is not meaningful.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Negative generation denotes that electric power con-sumed for plant use exceeds gross generation. •Pumping energy used at pumped storage plants was 2,604 million kilowatthours. •Totals may not equalsum of components because of independent rounding. •Percent difference is calculated before rounding. Due to restructuring of the electric power industry,electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 17
Table 12. Electric Utility Nuclear-Powered Net Generation by Census Division and State(Million Kilowatthours)
Year to Date
Census Division May April May Nuclear Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 43,285 38,992 59,864 218,028 299,348 −27.2 20.3 24.4
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Negative generation denotes that electric power con-sumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent difference is calcu-lated before rounding. Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This will affect compari-sons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200118
Table 13. Electric Utility Net Generation from Other Energy Sources by Census Division and State(Million Kilowatthours)
Year to Date
Census Division May April May Other Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 188 201 211 983 983 * .1 .1
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-
ble, or the percent difference calculation is not meaningful.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Negative generation denotes that electric power con-sumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent difference is calcu-lated before rounding. •Other energy sources include geothermal, wood, wind, waste, and solar. Due to restructuring of the electric power industry, electricutilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 19
U.S. Electric Utility Consumption of Fossil Fuels
Table 14. U.S. Electric Utility Consumption of Fossil Fuels, 1990 Through May 2001
Coal Petroleum Petroleum(thousand short tons) (thousand barrels) Coke Gas
Period (thousand (thousand short Mcf) Anthracite1 Bituminous2 Lignite Total Light Heavy Total tons)
1 Includes anthracite silt stored off-site.2 Includes subbituminous coal.
NA This estimated value is not available due to insufficient data or inadequate anticipated data/model performance.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final--see Technical Notes for adjustment methodology. Valuesfor 1999 and prior years are final. •Totals may not equal sum of components because of independent rounding. •Monthly values reflect the latest adjust-ments applied to the estimated data based on the final census data. •Mcf=thousand cubic feet. Due to restructuring of the electric power industry, electricutilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 1990-2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, FormEIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 21
Table 15. Electric Utility Consumption of Coal by NERC Region and Hawaii(Thousand Short Tons)
Year to Date NERC Region May April May and Hawaii 2001 2001 2000 Difference 2001 2000 (percent)
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •Coal includes lignite, bituminous coal, subbituminous coal, and anthracite. •SeeGlossary for explanation of acronyms. •Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This willaffect comparisons of current and historical data.
Sources: 2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Table 16. Electric Utility Consumption of Petroleum by NERC Region and Hawaii(Thousand Barrels)
Year to Date NERC Region May April May and Hawaii 2001 2001 2000 Difference 2001 2000 (percent)
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be appli-cable, or the percent difference calculation is not meaningful.
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •See Glossary for explanation of acronyms. •Due to restructuring of the electricpower industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200122
Table 17. Electric Utility Consumption of Gas by NERC Region and Hawaii(Million Cubic Feet)
Year to Date NERC Region May April May and Hawaii 2001 2001 2000 Difference 2001 2000 (percent)
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be appli-cable, or the percent difference calculation is not meaningful.
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •See Glossary for explanation of acronyms. •Due to restructuring of the electricpower industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 23
Table 18. Electric Utility Consumption of Coal by Census Division and State(Thousand Short Tons)
Year to DateCensus Division May April May
and State 2001 2001 2000 Difference 2001 2000 (percent)
U.S. Total ....................................... 66,185 59,839 67,428 329,973 343,099 −3.8
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •Coal includes lignite, bituminous coal, subbituminous coal, and anthracite. Due to re-structuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200124
Table 19. Electric Utility Consumption of Petroleum by Census Division and State(Thousand Barrels)
Year to DateCensus Division May April May
and State 2001 2001 2000 Difference 2001 2000 (percent)
U.S. Total ....................................... 11,575 11,392 9,702 63,903 32,634 95.8
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-
ble, or the percent difference calculation is not meaningful.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •Data do not include petroleum coke.•Due to restructuring of the electric power in-dustry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 25
Table 20. Electric Utility Consumption of Gas by Census Division and State(Million Cubic Feet)
Year to DateCensus Division May April May
and State 2001 2001 2000 Difference 2001 2000 (percent)
U.S. Total ....................................... 235,381 210,784 308,787 916,956 1,088,089 −15.7
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-
ble, or the percent difference calculation is not meaningful.Notes: •Values for 2001 are estimates based on a cutoff model sample--see the Technical Notes for a detailed discussion of the sample design for the
Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components be-cause of independent rounding.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200126
Fossil-Fuel Stocks at U.S. Electric Utilities
Table 21. U.S. Electric Utility Stocks of Coal and Petroleum, 1990 Through May 2001
Coal Petroleum Petroleum(thousand short tons) (thousand barrels) Coke
Period (thousand short Anthracite1 Bituminous2 Lignite Total Light Heavy Total tons)
2000January ............................................... W 119,494 W 123,661 14,655 21,678 36,333 296February ............................................. W 124,667 W 129,055 15,048 22,055 37,103 195March ................................................. W 122,773 W 127,130 14,643 20,966 35,608 171April ................................................... W 124,196 W 128,669 14,698 21,135 35,834 150May .................................................... W 122,432 W 127,090 14,206 20,169 34,375 113June .................................................... W 114,709 W 119,634 14,693 19,145 33,838 87July ..................................................... W 106,744 W 111,494 14,579 20,136 34,715 108August ................................................ W 101,314 W 106,201 14,419 18,759 33,178 157September ........................................... W 97,820 W 102,876 13,780 17,265 31,046 199October ............................................... W 99,570 W 104,422 13,932 17,302 31,234 247November ........................................... W 97,664 W 102,227 14,020 18,451 32,470 245December ........................................... W 84,985 W 90,115 12,655 16,899 29,554 186
2001January ............................................... W 80,916 W 85,759 14,945 15,629 30,574 200February ............................................. W 82,496 W 87,499 15,456 18,485 33,941 156March ................................................. W 90,965 W 95,801 14,723 18,123 32,846 155April ................................................... W 99,071 W 103,851 14,637 18,051 32,688 140May .................................................... W 106,315 W 110,956 14,417 21,309 35,725 130
1 Anthracite includes anthracite silt stored off-site.2 Bituminous coal includes subbituminous coal.
W = Withheld to avoid disclosure of individual company data.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final--see Technical Notes for adjustment methodology. Valuesfor 1999 and prior years are final. •Totals may not equal sum of components because of independent rounding. •Monthly values reflect the latest adjust-ments applied to the estimated data based on the final census data. •Prior to 1999, values represent December end-of-month stocks. For 1999 forward,values represent end-of-month stocks. Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This willaffect comparisons of current and historical data.
Sources: 1990-2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, FormEIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 27
Table 22. Electric Utility Stocks of Coal by NERC Region and Hawaii(Thousand Short Tons)
NERC Region May April May Monthly Difference Yearly Difference and Hawaii 2001 2001 2000 (percent) (percent)
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •Coal includes lignite, bituminous coal, subbituminous coal, and anthracite. •Stocksare end-of-month stocks at electric utilities. •See Glossary for explanation of acronyms. •Due to restructuring of the electric power industry, electric utilitiesare selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Sources: 2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Table 23. Electric Utility Stocks of Petroleum by NERC Region and Hawaii(Thousand Barrels)
NERC Region May April May Monthly Difference Yearly Difference and Hawaii 2001 2001 2000 (percent) (percent)
ECAR ................................................... 2,827 2,709 2,348 4.4 20.4ERCOT ................................................ 3,462 3,697 4,152 −6.3 −16.6MAAC ................................................. 764 792 1,974 −3.6 −61.3MAIN................................................... W W W W WMAPP (U.S.) ....................................... W W W W WNPCC (U.S.)........................................ 3,917 3,674 3,910 6.6 .2SERC ................................................... 5,394 4,569 4,598 18.0 17.3FRCC ................................................... 9,161 7,406 7,829 23.7 17.0SPP ....................................................... 5,245 4,876 4,188 7.6 25.3WSCC (U.S.) ....................................... 2,332 2,208 2,773 5.6 −15.9Contiguous U.S. ................................. 34,456 31,213 33,139 10.4 4.0ASCC................................................... W W W W WHawaii.................................................. W W W W WU.S. Total ............................................ 35,725 32,688 34,375 9.3 3.9
W = Withheld to avoid disclosure of individual company data.R = Revised Data.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •Data do not include petroleum coke. •Stocks are end-of-month stocks at electricutilities. •See Glossary for explanation of acronyms. •Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutilitysector. This will affect comparisons of current and historical data.
Sources: 2000: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 200128
Table 24. Electric Utility Stocks of Coal by Census Division(Thousand Short Tons)
May April May Monthly Difference Yearly Difference Census Division 2001 2001 2000 (percent) (percent)
New England......................................... W W W W WMiddle Atlantic ..................................... 1,445 1,375 11,483 5.0 −87.4East North Central ................................ 27,952 25,932 31,277 7.8 −10.6West North Central ............................... 17,879 16,145 19,518 10.7 −8.4South Atlantic ....................................... 20,636 19,246 20,416 7.2 1.1East South Central ................................ 10,708 9,509 10,684 12.6 .2West South Central ............................... 19,720 19,429 21,021 1.5 −6.2Mountain ............................................... 11,901 11,754 11,561 1.3 2.9Pacific Contiguous ................................ W W W W WPacific Noncontiguous .......................... — — — — —U.S. Total ............................................. 110,956 103,851 127,090 6.8 −12.7
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
W = Withheld to avoid disclosure of individual company data.Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-
759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •Coal includes lignite, bituminous coal, subbituminous coal, and anthracite. •Stocksare end-of-month stocks at electric utilities. Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. Thiswill affect comparisons of current and historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Table 25. Electric Utility Stocks of Petroleum by Census Division(Thousand Barrels)
May April May Monthly Difference Yearly Difference Census Division 2001 2001 2000 (percent) (percent)
New England......................................... 586 440 1,150 33.2 −49.1Middle Atlantic ..................................... 3,956 3,890 7,005 1.7 −43.5East North Central ................................ 2,965 2,760 2,224 7.4 33.3West North Central ............................... 2,013 1,950 1,726 3.2 16.6South Atlantic ....................................... 13,734 11,108 10,766 23.6 27.6East South Central ................................ 2,448 2,462 2,380 −.6 2.9West South Central ............................... 6,452 6,432 5,563 .3 16.0Mountain ............................................... 1,182 1,090 909 8.5 30.1Pacific Contiguous ................................ 1,122 1,081 1,537 3.7 −27.0Pacific Noncontiguous .......................... 1,269 1,475 1,115 −14.0 13.8U.S. Total ............................................. 35,725 32,688 34,375 9.3 3.9
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2001 are estimates based on a cutoff model sample--see Technical Notes for a discussion of the sample design for the Form EIA-759. Values for 2000 have been adjusted to reflect the Form EIA-759 census data and are final. •Totals may not equal sum of components because of in-dependent rounding. •Percent difference is calculated before rounding. •Data do not include petroleum coke. •Stocks are end-of-month stocks at electricutilities. Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of currentand historical data.
Sources: 2000 Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report’’; 2001: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 29
Receipts and Cost of Fossil Fuels at U.S. ElectricUtilities
Energy Information Administration/Electric Power Monthly August 2001 31
Table 26. U.S. Electric Utility Receipts of and Average Cost for Fossil Fuels,1990 Through April 2001
All Fossil Coal 1 Petroleum Gas Fuels 2
Heavy Oil 3 Total Period Receipts Cost Receipts Cost Cost (thousand (cents/ Receipts Cost Receipts Cost (thousand (cents/ (cents/ short tons) 106 Btu) (thousand (cents/ (thousand (cents/ Mcf) 106 Btu) 106 Btu) barrels) 106 Btu) barrels) 106 Btu)
1 Includes lignite, bituminous coal, subbituminous coal, and anthracite.2 The weighted average for all fossil fuels includes both heavy oil and light oil (Fuel Oil No. 2, kerosene, and jet fuel) prices. Data do not include petro-
leum coke.3 Heavy oil includes Fuel Oil Nos. 4, 5, and 6, and topped crude fuel oil.4 Data for 2001 are preliminary. Data for 2000 are final. Notes: •Totals may not equal sum of components because of independent rounding. •As of 1991, data are for electric generating plants with a total
steam-electric and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 1990 are for steam-electric plants with a generator nameplatecapacity of 50 or more megawatts. •Mcf=thousand cubic feet. •Monetary values are expressed in nominal terms. •Due to restructuring of the electricpower industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants,’’ and predecessorforms.
Energy Information Administration/Electric Power Monthly August 200132
Table 27. Electric Utility Receipts of Coal by NERC Region and Hawaii(Thousand Short Tons)
Year to Date NERC Region April March April and Hawaii 2001 1 2001 1 2000 1 Difference 2001 1 2000 1 (percent)
1 Data for 2001 are preliminary. Data for 2000 are final. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-elec-
tric and combined-cycle nameplate capacity of 50 or more megawatts. •Includes lignite, bituminous coal, subbituminous coal, and anthracite. •Due to re-structuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Table 28. Average Cost of Coal Delivered to Electric Utilities by NERC Region and Hawaii(Cents/Million Btu)
Year to Date NERC Region April March April and Hawaii 2001 1 2001 1 2000 1 Difference 2001 1 2000 1 (percent)
1 Data for 2001 are preliminary. Data for 2000 are final. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-elec-
tric and combined-cycle nameplate capacity of 50 or more megawatts. •Includes lignite, bituminous coal, subbituminous coal, and anthracite. •Monetary val-ues are expressed in monetary terms. •Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This willaffect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 33
Table 29. Electric Utility Receipts of Petroleum by NERC Region and Hawaii(Thousand Barrels)
Year to Date NERC Region April March April and Hawaii 2001 1 2001 1 2000 1 Difference 2001 1 2000 1 (percent)
1 Data for 2001 are preliminary. Data for 2000 are final. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-elec-
tric and combined-cycle nameplate capacity of 50 or more megawatts. •Due to restructuring of the electric power industry, electric utilities are selling plantsto the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Table 30. Average Cost of Petroleum Delivered to Electric Utilities by NERC Region and Hawaii(Cents/Million Btu)
Year to Date NERC Region April March April and Hawaii 2001 1 2001 1 2000 1 Difference 2001 1 2000 1 (percent)
1 Data for 2001 are preliminary. Data for 2000 are final. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-elec-
tric and combined-cycle nameplate capacity of 50 or more megawatts. •Monetary values are expressed in monetary terms. •Due to restructuring of theelectric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200134
Table 31. Electric Utility Receipts of Gas by NERC Region and Hawaii(Million Cubic Feet)
Year to Date NERC Region April March April and Hawaii 2001 1 2001 1 2000 1 Difference 2001 1 2000 1 (percent)
1 Data for 2001 are preliminary. Data for 2000 are final. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-elec-
tric and combined-cycle nameplate capacity of 50 or more megawatts. •Due to restructuring of the electric power industry, electric utilities are selling plantsto the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Table 32. Average Cost of Gas Delivered to Electric Utilities by NERC Region and Hawaii(Cents/Million Btu)
Year to Date NERC Region April March April and Hawaii 2001 1 2001 1 2000 1 Difference 2001 1 2000 1 (percent)
1 Data for 2001 are preliminary. Data for 2000 are final. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-elec-
tric and combined-cycle nameplate capacity of 50 or more megawatts. •Monetary values are expressed in monetary terms. •Due to restructuring of theelectric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 35
Table 33. Electric Utility Receipts of Coal by Type, Census Division, and State,April 2001
Anthracite Bituminous Subbituminous Lignite Total
Census Division (thousand (thousand (thousand (thousand (thousandand State (billion (billion (billion (billion (billionshort short short short shortBtu) Btu) Btu) Btu) Btu)tons) tons) tons) tons) tons)
U.S. Total ....................................... — — 27,103 646,592 28,020 489,579 5,153 66,559 60,277 1,202,730
Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with total steam-electricand combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are preliminary. •Due to restructuring of the electric power industry, elec-tric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200136
Table 34. Receipts and Average Cost of Coal Delivered to Electric Utilities by CensusDivision and State
April 2001 April 2000 Year to Date Receipts Receipts
Census Division Receipts Average Cost and State (thousand (billion (thousand (billion (billion Btu) (cents/million Btu)1 short tons) Btu) short tons) Btu)
U.S. Total ..................................................................... 60,277 1,202,730 63,890 1,309,027 5,022,569 5,500,321 123.1 120.9
1 Monetary values are expressed in nominal terms. Notes: •Data for 2001 are preliminary. Data for 2000 are final. •Totals may not equal sum of components because of independent rounding. •Data
are for electric generating plants with a total steam-electric and combined-cycle nameplate capacity of 50 or more megawatts. •Coal includes lignite, bitumi-nous coal, subbituminous coal, and anthracite. •Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector.This will affect comparisons of current and historical data. •See footnotes 4 through 8 of Table 57 for information concerning delivered cost of coal to Ala-bama, Florida, Kentucky, and Tennessee.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 37
Table 35. Receipts and Average Cost of Coal Delivered to Electric Utilities by Type of Purchase,Mining Method, Census Division, and State, April 2001
Type of Purchase Type of Mining
Contract Spot Strip and Auger Underground
Census Division Receipts Average Cost1 Receipts Average Cost1 Receipts Average Cost1 Receipts Average Cost1 and State
(1,000 ($/ (1,000 ($/ (1,000 ($/ (1,000 ($/ (Cents/ (Cents/ (Cents/ (Cents/ short short short short short short short short 106 Btu) 106 Btu) 106 Btu) 106 Btu) tons) ton) tons) ton) tons) ton) tons) ton)
U. S. Total .......................................... 47,000 122.3 24.07 13,277 129.4 27.07 45,478 116.5 21.71 14,798 141.7 34.00
1 Monetary values are expressed in nominal terms. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-
electric and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are preliminary. •Due to restructuring of the electric power in-dustry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data. •See footnotes 4 through 8 ofTable 57 for information concerning delivered cost of coal to Alabama, Florida, Kentucky, and Tennessee.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report on Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200138
Table 36. Receipts and Average Cost of Coal Delivered to Electric Utilities by Sulfur Content,Census Division, and State, April 2001
0.5% or Less More than 0.5% up to 1.0% More than 1.0% up to 1.5%
Average Average Average Receipts Receipts Receipts Census Division Cost1 Cost1 Cost1
and State (1,000 ($/ (1,000 ($/ (1,000 ($/ (Cents/ (Cents/ (Cents/ short short short short short short 106 Btu) 106 Btu) 106 Btu) tons) ton) tons) ton) tons) ton)
U. S. Total .................................................. 27,301 106.1 18.99 18,720 139.1 29.63 6,553 142.1 29.74
1 Monetary values are expressed in nominal terms. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-
electric and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are preliminary. •Due to restructuring of the electric power in-dustry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report on Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 39
Table 36. Receipts and Average Cost of Coal Delivered to Electric Utilities by Sulfur Content,Census Division, and State, April 2001 (Continued)
More than 1.5% up to 2.0% More than 2.0% up to 3.0% More than 3.0% All Purchases
Average Average Average Receipts Receipts Receipts Census Division Cost1 Cost1 Cost1
and State (1,000 ($/ (1,000 ($/ (1,000 (Cents/ ($/ (Cents/ ($/ (Cents/ (Cents/ short short short short short 106 short 106 short 106 Btu) 106 Btu)tons) ton) tons) ton) tons) Btu) ton) Btu) ton)
U. S. Total .................................................... 1,971 126.4 31.10 2,958 118.7 26.54 2,773 129.7 29.87 123.9 24.73
1 Monetary values are expressed in nominal terms.* = Less than 0.05. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-
electric and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are preliminary. •Due to restructuring of the electric power in-dustry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data. •See footnotes 4 through 8 ofTable 57 for information concerning delivered cost of coal to Alabama, Florida, Kentucky, and Tennessee.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report on Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200140
Table 37. Electric Utility Receipts of Petroleum by Type, Census Division, and State,April 2001
No. 2 Fuel Oil No. 4 Fuel Oil1 No. 5 Fuel Oil1 No. 6 Fuel Oil Total Census Division
U.S. Total ....................................... 731 4,279 — — — — 9,422 60,278 10,152 64,557
1 Blend of No. 2 Fuel Oil and No. 6 Fuel Oil.* The absolute value of the number is less than 0.5. Notes: •Totals may not equal sum of components because of independent rounding. •Totals may include small quantities of jet fuel or kerosene.
•Data are for electric generating plants with total steam-electric and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are pre-liminary. •Due to restructuring of the electric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of currentand historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 41
Table 38. Receipts and Average Cost of Petroleum Delivered to Electric Utilities by CensusDivision and State
April 2001 April 2000 Year to Date Receipts Receipts
Census Division Receipts Average Cost and State (thousand (billion (thousand (billion (billion Btu) (cents/million Btu)1 barrels) Btu) barrels) Btu)
U.S. Total ..................................................................... 10,152 64,557 5,258 33,389 295,470 105,310 442.9 398.4
1 Monetary values are expressed in nominal terms.* Less than 0.5. Notes: •Data for 2001 are preliminary. Data for 2000 are final. •Totals may not equal sum of components because of independent rounding. •Data
are for electric generating plants with a total steam-electric and combined-cycle nameplate capacity of 50 or more megawatts. •The April 2001 petroleumcoke receipts were 117,556 short tons and the cost was 74.3 cents per million Btu. •Due to restructuring of the electric power industry, electric utilitiesare selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200142
Table 39. Receipts and Average Cost of Petroleum Delivered to Electric Utilities by Type ofPurchase, Census Division, and State, April 2001
Fuel Oil No. 6 by Type of Purchase Averaged Cost of Fuel Oils1
Contract Spot No. 2 No. 4-No. 5 No. 6 Census Division and State Receipts Average Cost1 Receipts Average Cost1
U. S. Total ....................................... 4,781 393.3 25.24 4,641 383.2 24.44 634.0 37.13 — — 388.4 24.85
1 Monetary values are expressed in nominal terms. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-
electric and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are preliminary. •Due to restructuring of the electric power in-dustry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report on Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 43
Table 40. Receipts and Average Cost of Heavy Oil Delivered to Electric Utilities by SulfurContent, Census Division, and State, April 2001
0.3% or Less More than 0.3% up to 0.5% More than 0.5% up to 1.0%
Average Average Average Census Division Receipts Receipts Receipts Cost1 Cost1 Cost1 and State
U. S. Total .................................................. 672 419.7 25.99 1,925 461.8 29.10 3,130 383.4 24.47
1 Monetary values are expressed in nominal terms. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-
electric and combined-cycle nameplate capacity of 50 or more megawatts. •Fuel Oil No. 2 has been omitted from this table. •Oil and petroleum are usedinterchangeably in this report.•Data for 2001 are preliminary. •Due to restructuring of the electric power industry, electric utilities are selling plants to thenonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report on Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200144
Table 40. Receipts and Average Cost of Heavy Oil Delivered to Electric Utilities by SulfurContent, Census Division, and State, April 2001 (Continued)
More than 1.0% up to 2.0% More than 2.0% up to 3.0% More than 3.0% All Purchases
Average Average Average Receipts Receipts Receipts Census Division Cost1 Cost1 Cost1
U. S. Total .................................................... 2,641 353.8 23.01 1,053 340.6 22.09 — — — 388.4 24.85
1 Monetary values are expressed in nominal terms. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-
electric and combined-cycle nameplate capacity of 50 or more megawatts. •Fuel Oil No. 2 has been omitted from this table. •Oil and petroleum are usedinterchangeably in this report.•Data for 2001 are preliminary. •Due to restructuring of the electric power industry, electric utilities are selling plants to thenonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report on Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 45
Table 41. Electric Utility Receipts of Gas by Type, Census Division, and State,April 2001
Natural Blast-Furnance1 Refinery Total Census Division
and State (thousand (billion (thousand (billion (thousand (billion (thousand (billion Mcf) Btu) Mcf) Btu) Mcf) Btu) Mcf) Btu)
U.S. Total...................................... 178,204 183,937 — — 18 19 178,222 183,956
1 Includes coke oven gas.* The absolute value of the number is less than 0.5. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with total steam-electric
and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are preliminary. •Mcf=thousand cubic feet. •Due to restructuring of theelectric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200146
Table 42. Receipts and Average Cost of Gas Delivered to Electric Utilities by CensusDivision and State
April 2001 April 2000 Year to Date Receipts Receipts
Census Division Receipts Average Cost and State (thousand (billion (thousand (billion (billion Btu) (cents/million Btu)1 Mcf) Btu) Mcf) Btu)
U.S. Total ..................................................................... 178,222 183,956 199,696 204,156 586,122 726,269 677.0 293.5
1 Monetary values are expressed in nominal terms.* Less than 0.5. Notes: •Data for 2001 are preliminary. Data for 2000 are final. •Totals may not equal sum of components because of independent rounding. •Data
are for electric generating plants with a total steam-electric and combined-cycle nameplate capacity of 50 or more megawatts. •Includes small quantities ofcoke-oven, refinery, and blast-furnace gas. •Mcf=thousand cubic feet. •Due to restructuring of the electric power industry, electric utilities are sellingplants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 47
Table 43. Receipts and Average Cost of Gas Delivered to Electric Utilities by Type of Purchase,Census Division, and State, April 2001
Firm Gas Interruptible Gas Spot Gas Total Gas
Average Average Average AverageCensus Division Receipts Receipts Receipts Receipts Cost1 Cost1 Cost1 Cost1 and State
U. S. Total .......................................... 67,134 555.0 5.73 23,633 537.6 5.49 87,454 577.4 5.98 178,222 563.7 5.82
1 Monetary values are expressed in nominal terms.* = Less than 0.05. Notes: •Totals may not equal sum of components because of independent rounding. •Data are for electric generating plants with a total steam-
electric and combined-cycle nameplate capacity of 50 or more megawatts. •Data for 2001 are preliminary. •Mcf=thousand cubic feet. •Due to restructur-ing of the electric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report on Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 200148
U.S. Electric Utility Sales, Revenue, and AverageRevenue per Kilowatthour
Table 44. U.S. Electric Utility Retail Sales of Electricity by Sector, 1990 Through May 2001(Million Kilowatthours)
Period Residential Commercial Industrial Other1 All Sectors
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.Notes: •Sales values for 1999 include energy service provider (power marketer) data. •Values for 2000 are preliminary. •Values for 2001 are esti-
mates based on a cutoff model sample. Data for the state of Maine are unavailable due to deregulation activity. The New England Census Division had tobe estimated as a combined group instead of adding State level estimates. See Technical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on either NAICS codes or demand/or usage falling within specified limits (based ondifferent rate schedules.) •Retail sales and net generation may not correspond exactly for a particular month for a variety of reasons (i.e., sales data mayinclude purchases of electricity from nonutilities or imported electricity). Net generation is for the calendar month while retail sales and associated revenueaccumulate from bills collected for periods of time (28 to 35 days) that vary dependent upon customer class and consumption occurring in and outside thecalendar month. •Totals may not equal sum of components because of independent rounding.
Sources: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions,’’ and FormEIA-861, ‘‘Annual Electric Utility Report.’’
Energy Information Administration/Electric Power Monthly August 2001 49
Table 45. Estimated U.S. Electric Utility Retail Sales of Electricity to Ultimate Consumersby Sector, Census Division, and State, May 2001 and 2000(Million Kilowatthours)
Residential Commercial Industrial Other1 All Sectors Census Division and State 2001 2000 2001 2000 2001 2000 2001 2000 2001 2000
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.Notes: •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailable
due to deregulation activity. The New England Census Division had to be estimated as a combined group instead of adding State level estimates. SeeTechnical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on eitherNAICS codes or demand/or usage falling within specified limits (based on different rate schedules.) •Retail sales and net generation may not correspondexactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net gen-eration is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary de-pendent upon customer class and consumption occurring in and outside the calendar month. •Totals may not equal sum of components because of inde-pendent rounding.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 200150
Table 46. Estimated Coefficients of Variation for U.S. Electric Utility Retail Sales of Electricityto Ultimate Consumers by Sector, Census Division and State, May 2001(Percent)
Census Division Residential Commercial Industrial Other1 All Sectors and State
New England ...................................... NA NA NA NA NAConnecticut ....................................... NA NA NA NA NAMaine ................................................ NA NA NA NA NAMassachusetts ................................... NA NA NA NA NANew Hampshire ................................ NA NA NA NA NARhode Island..................................... NA NA NA NA NAVermont ............................................ NA NA NA NA NA
Middle Atlantic .................................. NA NA NA NA NANew Jersey........................................ NA NA NA NA NANew York ......................................... NA NA NA NA NAPennsylvania ..................................... NA NA NA NA NA
East North Central ............................ NA NA NA NA NAIllinois ............................................... NA NA NA NA NAIndiana .............................................. NA NA NA NA NAMichigan ........................................... NA NA NA NA NAOhio .................................................. NA NA NA NA NAWisconsin.......................................... NA NA NA NA NA
West North Central........................... NA NA NA NA NAIowa .................................................. NA NA NA NA NAKansas ............................................... NA NA NA NA NAMinnesota.......................................... NA NA NA NA NAMissouri ............................................ NA NA NA NA NANebraska ........................................... NA NA NA NA NANorth Dakota .................................... NA NA NA NA NASouth Dakota .................................... NA NA NA NA NA
South Atlantic .................................... NA NA NA NA NADelaware ........................................... NA NA NA NA NADistrict of Columbia......................... NA NA NA NA NAFlorida............................................... NA NA NA NA NAGeorgia.............................................. NA NA NA NA NAMaryland........................................... NA NA NA NA NANorth Carolina .................................. NA NA NA NA NASouth Carolina .................................. NA NA NA NA NAVirginia ............................................. NA NA NA NA NAWest Virginia.................................... NA NA NA NA NA
East South Central ............................ NA NA NA NA NAAlabama ............................................ NA NA NA NA NAKentucky........................................... NA NA NA NA NAMississippi ........................................ NA NA NA NA NATennessee.......................................... NA NA NA NA NA
West South Central ........................... NA NA NA NA NAArkansas............................................ NA NA NA NA NALouisiana........................................... NA NA NA NA NAOklahoma.......................................... NA NA NA NA NATexas................................................. NA NA NA NA NA
Mountain ............................................ NA NA NA NA NAArizona.............................................. NA NA NA NA NAColorado............................................ NA NA NA NA NAIdaho ................................................. NA NA NA NA NAMontana ............................................ NA NA NA NA NANevada .............................................. NA NA NA NA NANew Mexico ..................................... NA NA NA NA NAUtah................................................... NA NA NA NA NAWyoming .......................................... NA NA NA NA NA
Pacific Contiguous ............................. NA NA NA NA NACalifornia .......................................... NA NA NA NA NAOregon .............................................. NA NA NA NA NAWashington ....................................... NA NA NA NA NA
Pacific Noncontiguous ....................... NA NA NA NA NAAlaska ............................................... NA NA NA NA NAHawaii ............................................... NA NA NA NA NA
U.S. Average....................................... NA NA NA NA NA
1 Includes public street and highway lighting, other sales to public authorities, sales to railroads and railways, sales to farms for irrigation, and inter-departmental sales.
NM = This estimated value is not available due to insufficient data.NA = Not available.
Notes: •See technical notes for CV methodology. •It should be noted that such things as large changes in retail sales, reclassification of retail sales,or changes in billing procedures can contribute to unusually high coefficients of variation.
Sources: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 2001 51
Table 47. Estimated U.S. Electric Utility Retail Sales of Electricity to Ultimate Consumersby Sector, Census Division, and State, Year-to-Date (May) 2001 and 2000(Million Kilowatthours)
Residential Commercial Industrial Other1 All Sectors Census Division and State 2001 2000 2001 2000 2001 2000 2001 2000 2001 2000
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.Notes: •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailable
due to deregulation activity. The New England Census Division had to be estimated as a combined group instead of adding State level estimates. SeeTechnical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on eitherNAICS codes or demand/or usage falling within specified limits (based on different rate schedules.) •Retail sales and net generation may not correspondexactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net gen-eration is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary de-pendent upon customer class and consumption occurring in and outside the calendar month. •Totals may not equal sum of components because of inde-pendent rounding.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 200152
Table 48. Revenue from U.S. Electric Utility Retail Sales of Electricity to UltimateConsumers by Sector, 1990 Through May 2001(Million Dollars)
Period Residential Commercial Industrial Other1 All Sectors
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.Notes: •Revenue values for 1999 include an estimate for energy service provider (power marketer) data. •Values for 2000 are preliminary. •Values
for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailable due to deregulation activity. The New EnglandCensus Division had to be estimated as a combined group instead of adding State level estimates. See Technical Notes for a discussion of the sampledesign for the Form EIA-826. Utilities may classify commercial and industrial consumers based on either NAICS codes or demand/or usage falling withinspecified limits (based on different rate schedules.) •Values for 1996 in the commercial and industrial sectors for Maryland, the South Atlantic Census Divi-sion, and the U.S. Total reflect an electric utility’s reclassification for this information by Standard Industrial Classification Code (SIC). •Retail sales and netgeneration may not correspond exactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilitiesor imported electricity). Net generation is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods oftime (28 to 35 days) that vary dependent upon customer class and consumption occurring in and outside the calendar month. •Totals may not equal sumof components because of independent rounding.
Sources: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions,’’ and FormEIA-861, ‘‘Annual Electric Utility Report.’’
Energy Information Administration/Electric Power Monthly August 2001 53
Table 49. Estimated Revenue from U.S. Electric Utility Retail Sales of Electricity to UltimateConsumers by Sector, Census Division, and State, May 2001 and 2000(Million Dollars)
Residential Commercial Industrial Other1 All Sectors Census Division and State 2001 2000 2001 2000 2001 2000 2001 2000 2001 2000
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.* Less than 0.5.
Notes: •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailabledue to deregulation activity. The New England Census Division had to be estimated as a combined group instead of adding State level estimates. SeeTechnical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on eitherNAICS codes or demand/or usage falling within specified limits (based on different rate schedules.) •Retail sales and net generation may not correspondexactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net gen-eration is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary de-pendent upon customer class and consumption occurring in and outside the calendar month. •Totals may not equal sum of components because of inde-pendent rounding.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 200154
Table 50. Estimated Coefficients of Variation for Revenue from U.S. Electric Utility Retail Salesof Electricity to Ultimate Consumers by Sector, Census Division, and State, May 2001(Percent)
Census Division Residential Commercial Industrial Other1 All Sectors and State
New England ...................................... NA NA NA NA NAConnecticut ....................................... NA NA NA NA NAMaine ................................................ NA NA NA NA NAMassachusetts ................................... NA NA NA NA NANew Hampshire ................................ NA NA NA NA NARhode Island..................................... NA NA NA NA NAVermont ............................................ NA NA NA NA NA
Middle Atlantic .................................. NA NA NA NA NANew Jersey........................................ NA NA NA NA NANew York ......................................... NA NA NA NA NAPennsylvania ..................................... NA NA NA NA NA
East North Central ............................ NA NA NA NA NAIllinois ............................................... NA NA NA NA NAIndiana .............................................. NA NA NA NA NAMichigan ........................................... NA NA NA NA NAOhio .................................................. NA NA NA NA NAWisconsin.......................................... NA NA NA NA NA
West North Central........................... NA NA NA NA NAIowa .................................................. NA NA NA NA NAKansas ............................................... NA NA NA NA NAMinnesota.......................................... NA NA NA NA NAMissouri ............................................ NA NA NA NA NANebraska ........................................... NA NA NA NA NANorth Dakota .................................... NA NA NA NA NASouth Dakota .................................... NA NA NA NA NA
South Atlantic .................................... NA NA NA NA NADelaware ........................................... NA NA NA NA NADistrict of Columbia......................... NA NA NA NA NAFlorida............................................... NA NA NA NA NAGeorgia.............................................. NA NA NA NA NAMaryland........................................... NA NA NA NA NANorth Carolina .................................. NA NA NA NA NASouth Carolina .................................. NA NA NA NA NAVirginia ............................................. NA NA NA NA NAWest Virginia.................................... NA NA NA NA NA
East South Central ............................ NA NA NA NA NAAlabama ............................................ NA NA NA NA NAKentucky........................................... NA NA NA NA NAMississippi ........................................ NA NA NA NA NATennessee.......................................... NA NA NA NA NA
West South Central ........................... NA NA NA NA NAArkansas............................................ NA NA NA NA NALouisiana........................................... NA NA NA NA NAOklahoma.......................................... NA NA NA NA NATexas................................................. NA NA NA NA NA
Mountain ............................................ NA NA NA NA NAArizona.............................................. NA NA NA NA NAColorado............................................ NA NA NA NA NAIdaho ................................................. NA NA NA NA NAMontana ............................................ NA NA NA NA NANevada .............................................. NA NA NA NA NANew Mexico ..................................... NA NA NA NA NAUtah................................................... NA NA NA NA NAWyoming .......................................... NA NA NA NA NA
Pacific Contiguous ............................. NA NA NA NA NACalifornia .......................................... NA NA NA NA NAOregon .............................................. NA NA NA NA NAWashington ....................................... NA NA NA NA NA
Pacific Noncontiguous ....................... NA NA NA NA NAAlaska ............................................... NA NA NA NA NAHawaii ............................................... NA NA NA NA NA
U.S. Average....................................... NA NA NA NA NA
1 Includes public street and highway lighting, other sales to public authorities, sales to railroads and railways, sales to farms for irrigation, and inter-departmental sales.
NM = This estimated value is not available due to insufficient data.NA = Not available.
Notes: •See technical notes for CV methodology. •It should be noted that such things as large changes in retail sales, reclassification of retail sales,or changes in billing procedures can contribute to unusually high coefficients of variation.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 2001 55
Table 51. Estimated Revenue from U.S. Electric Utility Retail Sales to Ultimate Consumersby Sector, Census Division, and State, Year-to-Date (May) 2001 and 2000(Million Dollars)
Residential Commercial Industrial Other1 All Sectors Census Division and State 2001 2000 2001 2000 2001 2000 2001 2000 2001 2000
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.Notes: •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailable
due to deregulation activity. The New England Census Division had to be estimated as a combined group instead of adding State level estimates. SeeTechnical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on eitherNAICS codes or demand/or usage falling within specified limits (based on different rate schedules.) •Retail sales and net generation may not correspondexactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net gen-eration is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary de-pendent upon customer class and consumption occurring in and outside the calendar month. •Totals may not equal sum of components because of inde-pendent rounding.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 200156
Table 52. U.S. Electric Utility Average Revenue per Kilowatthour by Sector,1990 Through May 2001(Cents)
Period Residential Commercial Industrial Other1 All Sectors
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales irrigation, & interdepartmental sales.Notes: •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailable
due to deregulation activity. The New England Census Division had to be estimated as a combined group instead of adding State level estimates. SeeTechnical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on eitherNAICS codes or demand/or usage falling within specified limits (based on different rate schedules.) •Values for 1996 in the commercial and industrial sec-tors for Maryland, the South Atlantic Census Division, and the U.S. Total reflect an electric utility’s reclassification for this information by Standard IndustrialClassification Code (SIC). •Retail sales and net generation may not correspond exactly for a particular month for a variety of reasons (i.e., sales data mayinclude purchases of electricity from nonutilities or imported electricity). Net generation is for the calendar month while retail sales and associated revenueaccumulate from bills collected for periods of time (28 to 35 days) that vary dependent upon customer class and consumption occurring in and outside thecalendar month. •Totals may not equal sum of components because of independent rounding.
Sources: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions,’’ and FormEIA-861, ‘‘Annual Electric Utility Report.’’
Energy Information Administration/Electric Power Monthly August 2001 57
Table 53. Estimated U.S. Electric Utility Average Revenue per Kilowatthour to UltimateConsumers by Sector, Census Division, and State, May 2001 and 2000(Cents)
Residential Commercial Industrial Other1 All Sectors Census Division and State 2001 2000 2001 2000 2001 2000 2001 2000 2001 2000
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.Notes: •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailable
due to deregulation activity. The New England Census Division had to be estimated as a combined group instead of adding State level estimates. SeeTechnical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on eitherNAICS codes or demand/or usage falling within specified limits (based on different rate schedules.) •Retail sales and net generation may not correspondexactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net gen-eration is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary de-pendent upon customer class and consumption occurring in and outside the calendar month. •Totals may not equal sum of components because of inde-pendent rounding.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 200158
Table 54. Estimated Coefficients of Variation for U.S. Electric Utility Average Revenue perKilowatthour to Ultimate Consumers by Sector, Census Division, and State, May 2001(Percent)
Census Division Residential Commercial Industrial Other1 All Sectors and State
New England ...................................... NA NA NA NA NAConnecticut ....................................... NA NA NA NA NAMaine ................................................ NA NA NA NA NAMassachusetts ................................... NA NA NA NA NANew Hampshire ................................ NA NA NA NA NARhode Island..................................... NA NA NA NA NAVermont ............................................ NA NA NA NA NA
Middle Atlantic .................................. NA NA NA NA NANew Jersey........................................ NA NA NA NA NANew York ......................................... NA NA NA NA NAPennsylvania ..................................... NA NA NA NA NA
East North Central ............................ NA NA NA NA NAIllinois ............................................... NA NA NA NA NAIndiana .............................................. NA NA NA NA NAMichigan ........................................... NA NA NA NA NAOhio .................................................. NA NA NA NA NAWisconsin.......................................... NA NA NA NA NA
West North Central........................... NA NA NA NA NAIowa .................................................. NA NA NA NA NAKansas ............................................... NA NA NA NA NAMinnesota.......................................... NA NA NA NA NAMissouri ............................................ NA NA NA NA NANebraska ........................................... NA NA NA NA NANorth Dakota .................................... NA NA NA NA NASouth Dakota .................................... NA NA NA NA NA
South Atlantic .................................... NA NA NA NA NADelaware ........................................... NA NA NA NA NADistrict of Columbia......................... NA NA NA NA NAFlorida............................................... NA NA NA NA NAGeorgia.............................................. NA NA NA NA NAMaryland........................................... NA NA NA NA NANorth Carolina .................................. NA NA NA NA NASouth Carolina .................................. NA NA NA NA NAVirginia ............................................. NA NA NA NA NAWest Virginia.................................... NA NA NA NA NA
East South Central ............................ NA NA NA NA NAAlabama ............................................ NA NA NA NA NAKentucky........................................... NA NA NA NA NAMississippi ........................................ NA NA NA NA NATennessee.......................................... NA NA NA NA NA
West South Central ........................... NA NA NA NA NAArkansas............................................ NA NA NA NA NALouisiana........................................... NA NA NA NA NAOklahoma.......................................... NA NA NA NA NATexas................................................. NA NA NA NA NA
Mountain ............................................ NA NA NA NA NAArizona.............................................. NA NA NA NA NAColorado............................................ NA NA NA NA NAIdaho ................................................. NA NA NA NA NAMontana ............................................ NA NA NA NA NANevada .............................................. NA NA NA NA NANew Mexico ..................................... NA NA NA NA NAUtah................................................... NA NA NA NA NAWyoming .......................................... NA NA NA NA NA
Pacific Contiguous ............................. NA NA NA NA NACalifornia .......................................... NA NA NA NA NAOregon .............................................. NA NA NA NA NAWashington ....................................... NA NA NA NA NA
Pacific Noncontiguous ....................... NA NA NA NA NAAlaska ............................................... NA NA NA NA NAHawaii ............................................... NA NA NA NA NA
U.S. Average....................................... NA NA NA NA NA
1 Includes public street and highway lighting, other sales to public authorities, sales to railroads and railways, sales to farms for irrigation, and inter-departmental sales.
NM = This estimated value is not available due to insufficient data.NA = Not available.
Notes: •See technical notes for CV methodology. •It should be noted that such things as large changes in retail sales, reclassification of retail sales,or changes in billing procedures can contribute to unusually high coefficients of variation.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 2001 59
Table 55. Estimated U.S. Electric Utility Average Revenue per Kilowatthour to UltimateConsumers by Sector, Census Division, and State, Year-to-Date (May) 2001 and 2000(Cents)
Residential Commercial Industrial Other1 All Sectors Census Division and State 2001 2000 2001 2000 2001 2000 2001 2000 2001 2000
1 Includes public street & highway lighting, other sales to public authorities, sales to railroads & railways, sales for irrigation, and interdepartmental sales.Notes: •Values for 2000 are preliminary. •Values for 2001 are estimates based on a cutoff model sample. Data for the state of Maine are unavailable
due to deregulation activity. The New England Census Division had to be estimated as a combined group instead of adding State level estimates. SeeTechnical Notes for a discussion of the sample design for the Form EIA-826. Utilities may classify commercial and industrial consumers based on eitherNAICS codes or demand/or usage falling within specified limits (based on different rate schedules.) •Retail sales and net generation may not correspondexactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net gen-eration is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary de-pendent upon customer class and consumption occurring in and outside the calendar month. •Totals may not equal sum of components because of inde-pendent rounding.
Source: Energy Information Administration, Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 200160
Monthly Plant Aggregates: U.S. Electric Utility NetGeneration and Fuel Consumption
Table 56. U.S. Electric Utility Net Generation and Fuel Consumption, by Companyand Plant, May 2001
1 Other energy sources include geothermal, solar, wood, wind, and waste.* Less than 0.5. Notes: •Totals may not equal sum of components because of independent rounding. •Net generation for jointly owned units is reported by the
operator. •Negative generation denotes that electric power consumed for plant use exceeds gross generation. •Station losses include energy used forpumped storage. •Generation is included for plants in test status. •Nuclear generation is included for those plants with an operating license issuedauthorizing fuel loading/low power testing prior to receipt of full power amendment. •Central storage is a common area for fuel stocks not assigned tospecific plants. •Mcf=thousand cubic feet and bbls=barrels. •Holding Companies are: AEP is American Electric Power, APS is Allegheny Power System,ACE is Atlantic City Electric, CSW is Central & South West Corporation, CES is Commonwealth Energy System, DMV is Delmarva, EU is Eastern UtilitiesAssociates Company, GPS is General Public Utilities, MSU is Middle South Utilities, NEES is New England Electric System, NU is Northeast Utilities, SC isSouthern Company, TXU is TXU Electric Company.
Source: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 91
Monthly Plant Aggregates: U.S. Electric UtilityReceipts, Cost, and Quality of Fossil Fuels
Energy Information Administration/Electric Power Monthly August 2001 93
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 200194
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Cincinnati Gas & Electric Co ................ 947 116.4 28.08 2.21 66 574.4 33.67 .27 — — — 98 2 —
See notes and footnotes at end of table.
Energy Information Administration/Electric Power Monthly August 2001 95
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 200196
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 2001 97
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 200198
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 2001 99
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 2001100
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 2001 101
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 2001102
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 2001 103
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
Energy Information Administration/Electric Power Monthly August 2001 105
Table 57. Receipts, Average Cost, and Quality of Fossil Fuels Delivered to U.S. ElectricUtilities by Company and Plant, April 2001 (Continued)
Coal Petroleum1 Gas % of Total Btu
Average Average Average Receipts Receipts Receipts Cost Cost CostUtility (Holding Company) Avg. Avg. Pe- Plant (State) Sul- Sul- (Cents (Cents (Cents Coal tro- Gas ($ per fur fur (1,000 per (1,000 per $ per (1,000 per $ per leum short % % tons) 10 bbls) 10 bbl Mcf) 10 Mcf ton) Btu) Btu) Btu)
U.S. Total .................................................. 60,277 123.9 24.73 .85 10,152 4 404.7 25.73 1.11 178,222 4 563.7 5.82 83 4 13
1 The April 2001 petroleum coke receipts were 117,556 short tons and the cost was 74.3 cents per million Btu.2 The entry includes at least one delivery at a price of 1,000 cents per million Btu or greater. High price is frequently caused when fixed costs are
averaged into a small quantity.3 Most coal destined for the Barry plant is reported by the Alabama Power Company as it is received at the Gorgas Transshipping Facility.4 Monetary values are expressed in nominal terms.5 The cost reported under IMT Transfer (Louisiana) is the weighted average cost of coal delivered to this facility. Florida Power Corporation incurs
additional costs for transporting coal from the transfer facility to the Crystal River power plant. These additional costs are not included in data shown inthis report. When aggregated at the State level, data for this transfer facility are shown as though the coal were delivered to Florida.
Energy Information Administration/Electric Power Monthly August 2001106
6 The cost reported under Davant Transfer (Louisiana) is the weighted average cost of coal delivered to this facility located in Louisiana. The TampaElectric Company incurs additional costs for transporting this coal from Davant to its power plants which are located in Florida. These costs are notincluded in data shown in this report. When aggregated at the State level, data for this transfer facility are shown as though the coal were delivered toFlorida.
7 Data for TXU Electric Company include lignite delivered for the Aluminium Company of America (ALCOA) portion of Unit 4 of the Sandow Plant. * For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05.
Notes: •Data for 2001 are preliminary. •Totals may not equal sum of components because of independent rounding. •Data are for electricgenerating plants with a total steam-electric and combined-cycle nameplate capacity of 50 or more megawatts. •The Tennessee Valley Authority did notprovide April fuel receipt and cost data in time for inclusion in this report. •Mcf=thousand cubic feet and bbl=barrel.
Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 107
U.S. Electric Nonutility Net Generation
Table 58. U.S. Nonutility Net Generation, 1990 Through May 2001(Million Kilowatthours)
Hydro- Period Coal Petroleum1 Gas2 Nuclear Geothermal Other3 Total electric
1 Includes fuel oils nos. 1, 2, 4, 5, and 6, crude oil, kerosene, and petroleum coke2 Includes supplemental gaseous fuel.3 Includes biomass, wind, photovoltaic, solar thermal, batteries, chemicals, hydrogen, and sulfur.
Notes: •Values for 2000 and 2001 are estimates. •Values for 1999 and prior years are final. •See Technical Notes for a discussion of the sample de-sign. •Totals may not equal sum of components because of independent rounding. •Due to restructuring of the electric power industry, the sale of gener-ating assets is resulting in a reclassification of plants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Sources: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report,’’, 2001: Form EIA-906, ‘‘Power Plant Report.’’ and FormEIA-860B, ‘‘Annual Electric Generator Report - Nonutility,’’ and predecessor forms.
Energy Information Administration/Electric Power Monthly August 2001 109
Table 59. U.S. Nonutility Net Generation by Nonrenewable Energy Source, 1990 ThroughMay 2001(Million Kilowatthours)
All Nonrenewable Hydroelectric Period Coal1 Petroleum2 Gas Nuclear Energy Sources (Pumped Storage)
Year to Date2001 ...................................... 400,188 146,141 24,850 138,032 91,415 −2492000 ...................................... 228,298 92,145 11,871 115,852 8,577 −146
1 Includes lignite, bituminous coal, subbituminous coal, and anthracite.2 Includes fuel oil Nos. 1, 2, 4, 5, and 6, crude oil, kerosene, and petroleum coke.
Notes: •Values for 2000 and 2001 are estimates. •Values for 1999 and prior years are final. •See Technical Notes for a discussion of the sample de-sign. •Totals may not equal sum of components because of independent rounding. •Due to restructuring of the electric power industry, the sale of gener-ating assets is resulting in a reclassification of plants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Sources: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report,’’, 2001: Form EIA-906, ‘‘Power Plant Report.’’ and FormEIA-860B, ‘‘Annual Electric Generator Report - Nonutility,’’ and predecessor forms.
Energy Information Administration/Electric Power Monthly August 2001110
Table 60. U.S. Nonutility Net Generation by Renewable Energy Source, 1990 ThroughMay 2001(Million Kilowatthours)
All Renewable Hydroelectric Solar Period Geothermal Biomass Wind Photovoltaic Energy Sources (Conventional) Thermal
Year to Date2001 ................................... 44,772 10,042 5,824 25,790 2,896 220 NA2000 ................................... 44,586 11,063 5,514 25,597 2,125 23 263
* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.Notes: •Values for 2000 and 2001 are estimates. •Values for 1999 and prior years are final. •See Technical Notes for a discussion of the sample de-
sign. •Totals may not equal sum of components because of independent rounding. •Due to restructuring of the electric power industry, the sale of gener-ating assets is resulting in a reclassification of plants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Sources: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report,’’, 2001: Form EIA-906, ‘‘Power Plant Report.’’ and FormEIA-860B, ‘‘Annual Electric Generator Report - Nonutility,’’ and predecessor forms.
Energy Information Administration/Electric Power Monthly August 2001 111
Table 61. Nonutility Net Generation by Census Division(Million Kilowatthours)
U.S. Total ....................................... 87,851 82,157 57,814 444,960 272,884 63.1
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Totals may not equal sum of compo-nents because of independent rounding. •Percent difference is calculated before rounding. •Due to restructuring of the electric power industry, the sale ofgenerating assets is resulting in a reclassification of plants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Table 62. Nonutility Net Generation from Coal by Census Division(Million Kilowatthours)
Year to Date
Census Division May April May Coal Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 26,595 26,003 19,593 146,141 92,145 58.6 32.8 33.8
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Negative generation denotes thatelectric power consumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent dif-ference is calculated before rounding. •Coal includes lignite, bituminous coal, subbituminous coal, and anthracite. •Due to restructuring of the electric powerindustry, the sale of generating assets is resulting in a reclassification of plants from the utility to nonutility sector. This will affect comparisons of current andhistorical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001112
Table 63. Nonutility Net Generation from Petroleum by Census Division(Million Kilowatthours)
Year to Date
Census Division May April May Petroleum Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 3,761 4,055 2,086 24,850 11,871 109.3 5.6 4.4
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Negative generation denotes thatelectric power consumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent dif-ference is calculated before rounding. •Includes fuel oil Nos. 1, 2, 4, 5, and 6, crude oil, kerosene, and petroleum coke. •Due to restructuring of the electricpower industry, the sale of generating assets is resulting in a reclassification of plants from the utility to nonutility sector. This will affect comparisons of cur-rent and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Table 64. Nonutility Net Generation from Gas by Census Division(Million Kilowatthours)
Year to Date
Census Division May April May Gas Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 29,882 25,759 25,596 138,032 115,852 19.1 31.0 42.5
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Negative generation denotes thatelectric power consumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent dif-ference is calculated before rounding. •Due to restructuring of the electric power industry, the sale of generating assets is resulting in a reclassification ofplants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 113
Table 65. Nonutility Hydroelectric Net Generation by Census Division(Million Kilowatthours)
Year to Date
Census Division May April May Hydroelectric Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 2,136 2,318 2,293 9,793 10,917 −10.3 2.2 4.0
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Negative generation denotes thatelectric power consumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percentdifference is calculated before rounding. •Due to restructuring of the electric power industry, the sale of generating assets is resulting in a reclassification ofplants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Table 66. Nonutility Net Generation from Nuclear by Census Division(Million Kilowatthours)
Year to Date
Census Division May April May Nuclear Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 18,233 16,961 1,615 91,415 8,577 965.9 20.5 3.1
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Negative generation denotes thatelectric power consumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent dif-ference is calculated before rounding. •Due to restructuring of the electric power industry, the sale of generating assets is resulting in a reclassification ofplants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001114
Table 67. Nonutility Net Generation from Other Energy Sources by Census Division(Million Kilowatthours)
Year to Date
Census Division May April May Other Generation Share of Total (percent) and State 2001 2001 2000 Difference 2001 2000 2001 2000 (percent)
U.S. Total.................................................... 7,244 7,060 6,630 34,730 33,522 3.6 7.8 12.3
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Negative generation denotes thatelectric power consumed for plant use exceeds gross generation. •Totals may not equal sum of components because of independent rounding. •Percent dif-ference is calculated before rounding. •Other energy sources include geothermal, wood, wind, waste, and solar. •Due to restructuring of the electric powerindustry, the sale of generating assets is resulting in a reclassification of plants from the utility to nonutility sector. This will affect comparisons of current andhistorical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 115
U.S. Electric Nonutility Consumption of FossilFuels
Table 68. U.S. Nonutility Consumption of Fossil Fuels, 1990 Through May 2001
Coal Petroleum Petroleum(thousand short tons) (thousand barrels) Coke Gas
Period (thousand (thousand short Mcf) Anthracite1 Bituminous2 Lignite Total Light Heavy Total tons)
January .................................................................... NA NA NA 3,339 — 4,690 4,690 205 188,404February .................................................................. NA NA NA 2,871 — 3,692 3,692 142 166,583March ...................................................................... NA NA NA 3,704 — 3,770 3,770 400 184,584April ........................................................................ NA NA NA 3,682 — 4,016 4,016 299 189,032May ......................................................................... NA NA NA 3,736 — 4,777 4,777 212 191,898June ......................................................................... NA NA NA 4,502 — 5,526 5,526 216 213,185July .......................................................................... NA NA NA 5,660 — 6,020 6,020 147 271,593August ..................................................................... NA NA NA 5,493 — 4,818 4,818 190 270,424September ............................................................... NA NA NA 4,940 — 3,984 3,984 156 246,727October ................................................................... NA NA NA 5,888 — 3,346 3,346 144 257,501November ............................................................... NA NA NA 5,472 — 2,978 2,978 336 222,502December ................................................................ NA NA NA 9,109 — 4,524 4,524 467 233,092Total ...................................................................... NA NA NA 58,396 NA NA 52,141 2,915 2,635,525
2000January .................................................................... NA NA NA 9,590 NA NA 5,173 270 242,693February .................................................................. NA NA NA 8,738 NA NA 3,460 254 231,211March ...................................................................... NA NA NA 8,910 NA NA 2,367 282 236,980April ........................................................................ NA NA NA 8,501 NA NA 2,236 261 226,604May ......................................................................... NA NA NA 9,664 NA NA 2,848 229 263,660June ......................................................................... NA NA NA 10,691 NA NA 3,935 230 288,515July .......................................................................... NA NA NA 12,925 NA NA 3,701 263 309,759August ..................................................................... NA NA NA 13,345 NA NA 5,301 235 352,104September ............................................................... NA NA NA 11,931 NA NA 3,910 259 307,180October ................................................................... NA NA NA 11,714 NA NA 4,533 257 288,131November ............................................................... NA NA NA 11,853 NA NA 4,681 251 269,785December ................................................................ NA NA NA 13,769 NA NA 10,496 228 270,468Total ...................................................................... NA NA NA 131,631 NA NA 52,640 3,021 3,287,090
2001January .................................................................... NA NA NA 17,110 NA NA 13,205 374 297,460February .................................................................. NA NA NA 14,791 NA NA 7,253 344 274,737March ...................................................................... NA NA NA 14,695 NA NA 7,605 341 303,526April ........................................................................ NA NA NA 13,062 NA NA 6,717 307 289,158May ......................................................................... NA NA NA 13,413 NA NA 5,666 361 318,028Total ...................................................................... NA NA NA 73,071 NA NA 40,446 1,727 1,482,909
Year to Date2001 ......................................................................... NA NA NA 73,071 NA NA 40,446 1,727 1,482,9092000 ......................................................................... NA NA NA 45,402 2,638 13,446 16,084 1297 1,201,149
1 Includes anthracite silt stored off-site.2 Includes subbituminous coal.
Notes: •Values for 2000 and 2001 are estimates. •Values for 1999 and prior years are final. •1990-1998 consumption also includes fuels used for theproduction of thermal heat from cogenerators. •See Technical Notes for a discussion of the sample design. •Totals may not equal sum of componentsbecause of independent rounding. •Mcf=thousand cubic feet.•Due to restructuring of the electric power industry, the sale of generating assets is resulting ina reclassification of plants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Sources: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report,’’, 2001: Form EIA-906, ‘‘Power Plant Report.’’ and FormEIA-860B, ‘‘Annual Electric Generator Report - Nonutility,’’ and predecessor forms.
Energy Information Administration/Electric Power Monthly August 2001 117
Table 69. Nonutility Consumption of Coal by Census Division(Thousand Short Tons)
Year to DateCensus Division May April May
and State 2001 2001 2000 Difference 2001 2000 (percent)
U.S. Total ....................................... 13,413 13,062 9,664 73,071 45,402 60.9
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Totals may not equal sum of compo-nents because of independent before rounding. •Coal includes lignite, bituminous coal, subbituminous coal, and anthracite. Due to restructuring of the elec-tric power industry, electric utilities are selling plants to the nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Table 70. Nonutility Consumption of Petroleum by Census Division(Thousand Barrels)
Year to DateCensus Division May April May
and State 2001 2001 2000 Difference 2001 2000 (percent)
U.S. Total ....................................... 5,666 6,717 2,848 40,446 16,084 151.5
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Totals may not equal sum of compo-nents because of independent rounding. •Percent difference is calculated before rounding. •Data do not include petroleum coke, therefore, percent changein fuel consumption and generation may not be consistent. •Due to restructuring of the electric power industry, the sale of generating assets is resulting in areclassification of plants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001118
Table 71. Nonutility Consumption of Gas by Census Division(Million Cubic Feet)
Year to DateCensus Division May April May
and State 2001 2001 2000 Difference 2001 2000 (percent)
U.S. Total ....................................... 318,028 289,158 263,660 1,482,909 1,201,149 23.5
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
Notes: •Values for 2000 and 2001 are estimates. •See Technical Notes for a discussion of the sample design. •Totals may not equal sum of compo-nents because of independent rounding. •Due to restructuring of the electric power industry, the sale of generating assets is resulting in a reclassification ofplants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 119
Fossil-Fuel Stocks at U.S. Electric Nonutilities
Table 72. U.S. Nonutility Stocks of Coal and Petroleum, 1990 Through May 2001
Coal Petroleum Petroleum(thousand short tons) (thousand barrels) Coke
Census Division (thousand and State short Anthracite1 Bituminous2 Lignite Total Light Heavy Total tons)
1990 ....................................................... NA NA NA NA NA NA NA NA1991 ....................................................... NA NA NA NA NA NA NA NA1992 ....................................................... NA NA NA NA NA NA NA NA1993 ....................................................... NA NA NA NA NA NA NA NA1994 ....................................................... NA NA NA NA NA NA NA NA1995 ....................................................... NA NA NA NA NA NA NA NA1996 ....................................................... NA NA NA NA NA NA NA NA1997 ....................................................... NA NA NA NA NA NA NA NA1998 ....................................................... NA NA NA NA NA NA NA NA1999
January ............................................... NA NA NA 4,678 NA NA 3,258 NAFebruary ............................................. NA NA NA 4,777 NA NA 2,957 NAMarch ................................................. NA NA NA 5,098 NA NA 3,042 NAApril ................................................... NA NA NA 5,282 NA NA 3,319 NAMay .................................................... NA NA NA 5,546 NA NA 4,579 NAJune .................................................... NA NA NA 6,374 NA NA 4,504 NAJuly ..................................................... NA NA NA 5,948 NA NA 5,353 NAAugust ................................................ NA NA NA 6,462 NA NA 5,129 NASeptember ........................................... NA NA NA 6,677 NA NA 5,453 NAOctober ............................................... NA NA NA 7,848 NA NA 6,561 NANovember ........................................... NA NA NA 9,694 NA NA 6,185 NADecember ........................................... NA NA NA 14,050 NA NA 8,666 NA
2000January ............................................... NA NA NA 15,233 NA NA 6,710 NAFebruary ............................................. NA NA NA 14,446 NA NA 6,611 NAMarch ................................................. NA NA NA 14,983 NA NA 6,587 NAApril ................................................... NA NA NA 16,235 NA NA 7,336 NAMay .................................................... NA NA NA 17,240 NA NA 7,621 NAJune .................................................... NA NA NA 16,719 NA NA 9,344 NAJuly ..................................................... NA NA NA 16,317 NA NA 12,470 NAAugust ................................................ NA NA NA 16,546 NA NA 11,383 NASeptember ........................................... NA NA NA 16,020 NA NA 11,784 NAOctober ............................................... NA NA NA 15,980 NA NA 12,365 NANovember ........................................... NA NA NA 15,537 NA NA 12,701 NADecember ........................................... NA NA NA 13,001 NA NA 11,089 NA
2001January ............................................... NA NA NA 18,779 NA NA 13,964 NAFebruary ............................................. NA NA NA 21,249 NA NA 16,180 NAMarch ................................................. NA NA NA 23,743 NA NA 15,346 NAApril ................................................... NA NA NA 24,386 NA NA 16,061 NAMay .................................................... NA NA NA 25,434 NA NA 19,487 NA
1 Anthracite includes anthracite silt stored off-site.2 Bituminous coal includes subbituminous coal.
Notes: •Values are not available for nonutility plants prior to 1999. Data for 2000 and 2001 represent only stocks reported by facilities that are in thecutoff model sample. Data do not include estimates for facilities that are not required to report on Form EIA-900. •Totals may not equal sum of compo-nents because of independent rounding. •Due to restructuring of the electric power industry, the sale of generating assets is resulting in a reclassification ofplants from the utility to nonutility sector. This will affect comparisons of current and historical data.
Sources: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report,’’, 2001: Form EIA-906, ‘‘Power Plant Report.’’ and FormEIA-860B, ‘‘Annual Electric Generator Report - Nonutility,’’ and predecessor forms.
Energy Information Administration/Electric Power Monthly August 2001 121
Table 73. Nonutility Stocks of Coal by Census Division(Thousand Short Tons)
May April May Monthly Difference Yearly Difference Census Division 2001 2001 2000 (percent) (percent)
New England......................................... 820 490 749 67.3 9.4Middle Atlantic ..................................... 6,350 6,468 5,035 −1.8 26.1East North Central ................................ 5,058 4,751 5,443 6.5 NMWest North Central ............................... W W W NM NMSouth Atlantic ....................................... 3,782 3,472 747 8.9 406.1East South Central ................................ W W W NM NMWest South Central ............................... 1,409 1,569 1,843 −10.2 −23.6Mountain ............................................... W W W NM NMPacific Contiguous ................................ 1,233 881 698 39.9 76.8Pacific Noncontiguous .......................... W W W NM NM
U.S. Total ............................................. 25,434 24,386 17,240 4.3 47.5
NM = This estimated value is not available due to insufficient data or inadequate anticipated data/model performance, information may not be applica-ble, or the percent difference calculation is not meaningful.
W = Withheld to avoid disclosure of individual company data.Notes: •Data for 2000 and 2001 represent only stocks reported by facilities that are in the cutoff model sample. Data do not include estimates for fa-
cilities that are not required to report on Form EIA-900. •Totals may not equal sum of components because of independent rounding. •Percent difference iscalculated before rounding. •Coal includes lignite, subbituminous, bituminous, and anthracite coal. •Stocks are end-of-month stocks at nonutility facilities re-porting on the EIA Form 900. •Due to restructuring of the electric power industry, the sale of generating assets is resulting in a reclassification of plantsfrom the utility to nonutility sector. This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Table 74. Nonutility Stocks of Petroleum by Census Division(Thousand Barrels)
May April May Monthly Difference Yearly Difference Census Division 2001 2001 2000 (percent) (percent)
New England......................................... 5,084 3,655 3,513 39.1 44.7Middle Atlantic ..................................... 7,808 6,314 1,826 23.7 327.6East North Central ................................ W W W NM NMWest North Central ............................... W W W NM NMSouth Atlantic ....................................... 3,936 3,921 1,228 .4 220.5East South Central ................................ W W W NM NMWest South Central ............................... W W W NM NMMountain ............................................... W W W NM NMPacific Contiguous ................................ W W W NM NMPacific Noncontiguous .......................... W W W NM NM
U.S. Total ............................................. 19,487 16,061 7,621 21.3 155.7
Notes: •Data for 2000 and 2001 represent only stocks reported by facilities that are in the cutoff model sample. Data do not include estimates for fa-cilities that are not required to report on Form EIA-900. •Totals may not equal sum of components because of independent rounding. •Percent difference iscalculated before rounding. •Data do not include petroleum coke. •Stocks are end-of-month stocks at nonutility facilities reporting on the EIA Form 900.•Due to restructuring of the electric power industry, the sale of generating assets is resulting in a reclassification of plants from the utility to nonutility sector.This will affect comparisons of current and historical data.
Source: Energy Information Administration, Form EIA-900, ‘‘Monthly Nonutility Power Report.’’; 2001: Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001122
Monthly Plant Aggregates: U.S. Electric NonutilityNet Generation and Fuel Consumption
Energy Information Administration/Electric Power Monthly August 2001 123
Table 75. U.S. Electric Nonutility Net Generation and Fuel Consumption, by Owner and Facility,May 2001
American Ref-Fuel Co..................................................... — — — — — 42,745 — — —American Ref Fuel Co of Hempstead (NY)................ — — — — — 42,745 — — —
American Ref-Fuel Co of Essex ..................................... — — — — — 44,405 — — —American Ref Fuel Co of Essex Count (NJ) .............. — — — — — 44,405 — — —
American Ref-Fuel Co of SE CT ................................... — — — — — 11,848 — — —American Ref Fuel Co of SE CT (CT) ....................... — — — — — 11,848 — — —
American Ref-Fuel Co-Niagara....................................... — — 272 — — 21,763 — — 8American Ref Fuel Co of Niagara LP (NY)............... — — 272 — — 21,763 — — 8
Capital District Energy Center ........................................ — — 24,429 — — 6,448 — — 280Capital District Energy Center Coge (CT) .................. — — 24,429 — — 6,448 — — 280
Central Wayne Energy Recvy LP ................................... — — 304 — — 10,322 — — 13Central Wayne Air Quality Energy Re (MI)............... — — 304 — — 10,322 — — 13
Davenport City of ............................................................ — — 198 — — — — — 2Davenport Water Pollution Control P (IA) ................. — — 198 — — — — — 2
Davis CSWM & Energy RSSD ...................................... — 13 — — — 280 — * —Wasatch Energy Systems (UT) .................................... — 13 — — — 280 — * —
De Pere Energy LLC ....................................................... — — — — — — — — —De Pere Energy Center (WI)........................................ — — — — — — — — —
Dow Chemical Co ........................................................... — — 822,016 — — — — — 11,903CA II (Chlor Alkali II) (LA) ....................................... — — 60,722 — — — — — 798Power and Utilities (LA).............................................. — — 292,848 — — — — — 5,830The Dow Chemical Co Texas Operation (TX) ........... — — 468,446 — — — — — 5,275
Duke Energy Morro Bay LLC ........................................ — — 422,080 — — — — — 4,097Duke Energy Morro Bay LLC (CA) ........................... — — 422,080 — — — — — 4,097
Duke Energy Moss Landing LLC................................... — — 712,092 — — — — — 6,028Duke Energy Moss Landing LLC (CA) ...................... — — 712,092 — — — — — 6,028
Duke Energy Oakland LLC............................................. — 4,110 — — — — — 9 —Duke Energy Oakland LLC (CA)................................ — 4,110 — — — — — 9 —
Duke Energy South Bay LLC......................................... — 2,344 183,376 — — — — 4 1,863Duke Energy South Bay LLC (CA) ............................ — 2,344 183,376 — — — — 4 1,863
DuPage County ................................................................ — 21 301 — — — — * 3DuPage County Region 9 West Wastewa (IL) ........... — 21 301 — — — — * 3
Eastman Kodak Co .......................................................... 63,083 209 7 134 — — 63 1 *Kodak Park Site (NY) .................................................. 63,083 209 7 134 — — 63 1 *
Ebensburg Power Co ....................................................... 10,957 — — — — — 12 — —Ebensburg Power Co (PA)........................................... 10,957 — — — — — 12 — —
El Dorado Energy LLC ................................................... — — 876 — — — — — 16El Dorado Energy (NV) ............................................... — — 876 — — — — — 16
El Segundo Power LLC................................................... — — 248,556 — — — — — 2,488El Segundo Power (CA)............................................... — — 248,556 — — — — — 2,488
Gilberton Power Co ......................................................... 58,739 — — — — — 51 — —John B Rich Memorial Power Station (PA)................ 58,739 — — — — — 51 — —
North American Power Group ........................................ — — — — — — — — —Ultrapower 3 Blue Lake (CA) ..................................... — — — — — — — — —
Oak Creek Energy System Inc II .................................... — — — — — 12,367 — — —Oak Creek Energy Systems Inc (CA).......................... — — — — — 12,367 — — —
POSDEF Power Co LP ................................................... 30,851 — — — — — 16 — —Port of Stockton District Energy Fa (CA)................... 30,851 — — — — — 16 — —
Soda Lake Ltd Partnership .............................................. — — — — — 5,665 — — —Soda Lake Geothermal No I II (NV) .......................... — — — — — 5,665 — — —
SF Phosphates Ltd Co ..................................................... — — — — — 7,910 — — —SF Phosphates Ltd Co (WY) ....................................... — — — — — 7,910 — — —
Tacoma City of ................................................................ 4,315 41 53 — — 10,974 6 * 1City of Tacoma Steam Plant (WA) ............................. 4,315 41 53 — — 10,974 6 * 1
Tampa City of .................................................................. — — — — — 7,584 — — —McKay Bay Facility (FL)............................................. — — — — — 7,584 — — —
Tampa Dept of Sanitary Sewers ..................................... — — 1,124 — — — — — 20City of Tampa Howard F Curren AWT P (FL).......... — — 1,124 — — — — — 20
* Less than 0.05. Notes: •Totals may not equal sum of components because of independent rounding. •Net generation for jointly owned units is reported by the
operator. •Negative generation denotes that electric power consumed for plant use exceeds gross generation. •Station losses include energy used forpumped storage. •Generation is included for plants in test status. •Nuclear generation is included for those plants with an operating license issuedauthorizing fuel loading/low power testing prior to receipt of full power amendment.•Mcf=thousand cubic feet and bbls=barrels.
Source: Energy Information Administration, Form EIA-906, ‘‘Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 151
Energy Information Administration/Electric Power Monthly August 2001 153
Appendix A
General Information
Articles
Feature articles on electric power energy-related subjects are frequently included in this publication. Thefollowing articles and special focus items have appeared in previous issues.
June 1990 . . . . . . . . . . . . . . . Petroleum Fuel-Switching Capability in the Electric Utility Industry
April 1991 . . . . . . . . . . . . . . U.S. Wholesale Electricity Transactions
April 1992 . . . . . . . . . . . . . . Electric Utility Demand-Side Management
April 1992 . . . . . . . . . . . . . . Nonutility Power Producers
August 1992 . . . . . . . . . . . . Performance Optimization and Repowering of Generating Units
February 1993 . . . . . . . . . . . Improvement in Nuclear Power Plant Capacity Factors
October 1993 . . . . . . . . . . . . Municipal Solid Waste in the U.S. Energy Supply
November 1993 . . . . . . . . . . Electric Utility Demand-Side Management and Regulatory Effects
November 1994 . . . . . . . . . . The Impact of Flow Control and Tax Reform on Ownership and Growth in theU.S. Waste-to-Energy Industry
July 1995 . . . . . . . . . . . . . . . Nonutility Electric Generation: Industrial Power Production
August 1995 . . . . . . . . . . . . Steam Generator Degradation and Its Impact on Continued Operation ofPressurized Water Reactors in the United States
September 1995 . . . . . . . . . . New Sources of Nuclear Fuel
November 1995 . . . . . . . . . . Relicensing and Environmental Issues Affecting Hydropower
May 1996 . . . . . . . . . . . . . . . U.S. Electric Utility Demand-Side Management: Trends and Analysis
June 1996 . . . . . . . . . . . . . . . Upgrading Transmission Capacity for Wholesale Electric Power Trade
May 1998 . . . . . . . . . . . . . . . Reducing Nitrogen Oxide Emissions: 1996 Compliance with Title IV Limits
For additional information or questions regarding availability of article reprints, please contact the NationalEnergy Information Center at (202)586-8800 or by FAX at (202)586-0727.
Energy Information Administration/Electric Power Monthly August 2001154
Bibliography
1. Energy Information Administration, Office of Coal, Nuclear, Electric and Alternate Fuels, Inventory of Power Plants inthe United States, DOE/EIA-0095(93) (Washington DC, 1994), pp. 247-248.
2. Energy Information Administration, Office of Statistical Standards, An Assessment of the Quality of Selected EIA DataSeries. Electric Power Data, DOE/EIA-0292(89) (Washington DC, 1989).
3. Kott, P.S., “Nonresponse in a Periodic Sample Survey,” Journal of Business and Economic Statistics, April 1987,Volume 5, Number 2, pp. 287-293.
4. Knaub, J.R., Jr., “Ratio Estimation and Approximate Optimum Stratification in Electric Power Surveys,” Proceedingsof the Section on Survey Research Methods, American Statistical Association, 1989, pp. 848-853.
5. Knaub, J.R., Jr., “More Model Sampling and Analyses Applied to Electric Power Data,” Proceedings of the Section onSurvey Research Methods, American Statistical Association, 1992, pp. 876-881.
6. Royall, R.M. (1970), “On Finite Population Sampling Theory Under Certain Linear Regression Models,” Biometrika,57, 377-387.
7. Royall, R.M., and W.G. Cumberland (1978), “Variance Estimation in Finite Population Sampling,” Journal of theAmerican Statistical Association, 73, 351-358.
8. Royall, R.M., andW.G. Cumberland(1981), “AnEmpirical Study of the Ratio Estimator and Estimators of Its Variance,”Journal of the American Statistical Association, 76, 66-68.
9. Knaub, J.R., Jr., “Alternative to the Iterated Reweighted Least Squares Method: Apparent Heteroscedasticity and LinearRegression Model Sampling,” Proceedings of the International Conference on Establishment Surveys, AmericanStatistical Association, 1993, pp. 520-525.
10. Rao, P.S.R.S. (1992), Unpublished notes on model covariance.
11. Hansen, M.H., Hurwitz, W.N. and Madow, W.G. (1953), “Sample Survey Methods and Theory,” Volume II, Theory,pp. 56-58.
12. Knaub, J.R., Jr., “Relative Standard Error for a Ratio of Variables at an Aggregate Level Under Model Sampling,” inProceedings of the Section on Survey Research Methods, American Statistical Association, 1994, pp. 310-312.
13. Knaub, J.R., Jr., “Weighted Multiple Regression Estimation for Survey Model Sampling,” InterStat(http://interstat.stat.vt.edu), May 1996.
Energy Information Administration/ Electric Power Monthly August 2001 155
Appendix B
Major Disturbances and Unusual Occurrences
This discussion was prepared for publication in theElectric Power Monthly by the Office of EnergyEmergency Management (under the Office of Non-proliferation and National Security).
Electric power systems are subject to a variety ofincidents that, to a smaller or greater degree, mayadversely affect the delivery of electricity to consumers.Among these are natural phenomena (such as stormsand earthquakes); failure of electric system components;accidental or purposeful activities inimical to continuedsafe operation of electric power systems; and, difficultiesassociated with the normal operation of large, extremelycomplex real-time systems.
Under current Federal regulations, some disturbancesare reported to the Federal Government. The legal basisfor the requirements and the specifications of infor-mation reported are detailed in Title 10, Part 205,Subpart W, of the Code of Federal Regulations, Sections205.350C205.353, published in the Federal Register onOctober 31, 1986.
In general, the incidents to be reported are grouped intotwo categories: (1) mandatory in all cases; and (2) man-datory if the incident meets specified criteria, where theutility involved is permitted to exercise some judgmentas to whether the criteria have been met. Underlying theformulation of the reporting criteria, requirements, andprocedures was the need for the Federal Government tobe aware of potentially dangerous situations, temperedby the desire to minimize burdens on the reportingutilities. Another consideration in the development ofthe rules was the benefit gained from knowledge of thecauses and effects of undesired events that may havebeen caused by unforseen system defects or bypurposeful adverse actions to system design andoperation. The final rules reflect modification of thepreliminary rules, as published in the Federal Register,based on comments from the electric power industryand the general public.
A report is mandatory when, for the purpose ofmaintaining the continuity of the bulk power supply
system, a utility, due to any equipment failure/systemoperational action or event, (1) initiates a system voltagereduction of 3 percent or more, (2) disconnects circuitssupplyingover 100 megawatts of firm customer load, (3)issues an appeal to the public for a voluntary reductionin the use of electricity, or (4) has existing or anticipatedfuel supply emergency situations requiring abnormaluse of a particular fuel with the potential to reducesupply or stocks if needed to maintain reliable electricservice. A report is also mandatory in regard to anyactual or suspected act of sabotage or terrorism directedat the bulk power supply system.
In general, reports are to be made by telephone to theEmergency Operating Center, Department of Energy, inWashington, DC, as soon as practicable for instances ofload shedding or loss of service, and, at the last, within3 hours of the beginning of a service interruption. Forother disturbances, the allowable reporting time rangesfrom 24 hours to days. Written reports may be requiredby the Director, Office of Energy Emergency Man-agement, if the circumstances so indicate.
The DOE is concerned that the operation of the bulkpower system in the United States shall be as troublefree as possible. To that end, information is collected, asdiscussed above, regarding major disturbances to thenormal functioning of that system. Events, such asdamage to some local distribution circuits by storms orother uncontrollable events, while annoying to thecustomers affected, do not greatly affect the supply ofbulk power to the system as a whole. These events aremore properly the concern of local and State authorities.By collecting data on major incidents, the Department isable to monitor the bulk power supply and provide afocus on those matters that may need investigation.
Suggestions regarding the reporting requirements,regulations, procedures, or any other phase of the PowerSystem Emergency Reporting elements are welcomed.Comments can be addressed to the Office of EnergyEmergency Operations (NN-63), Department of Energy,1000 IndependenceAvenue, SW, Washington, DC 20585.
Energy Information Administration/ Electric Power Monthly August 2001156
Table B1. Major Disturbances and Unusual Occurrences, 2001
DateUtility/Power Pool(NERC Council) Time Area
Type ofDisturbance
Loss(mega-watts)
Number ofCustomers
AffectedRestoration
Time
1/17/01 Calif. Indep. SystemOperator (WSCC)
1:45 a.m. California Firm Loadinterruption
500 NA 12:00 p.m. January 18
1/20/01 Calif. Indep. SystemOperator (WSCC)
8:15 a.m. California Firm Loadinterruption
300 NA 2:50 p.m. January 21
3/6/01 New England (ISO) 9:17 a.m.Boston &NortheastMassachusetts
Interruption ofFirm Power 340 130,000 11:00 a.m. March 6
3/14/01 Reliant Energy (ERCOT) 3:00 p.m.(CST)
Texas Gulf Coast Interruption ofFirm Power
NA 114,000 3:00 p.m. March 15
3/19/01 Southern CaliforniaEdison (WSCC)
11:50 a.m.(PST)
SouthernCalifornia Area
Interruption ofFirm Power
Various 430,984 March 19
3/19/01CA Independent SystemOperator (WSCC)
11:46 a.m.(PST)
SouthernCalifornia Area
Interruption ofFirm Power &Public Appeal
400-1,000 Undetermined 9:00 p.m. March 19
3/20/01 Southern CaliforniaEdison (WSCC)
11:50 a.m.(PST)
SouthernCalifornia Area
Interruption ofFirm Power
Various 25,000 per hour 2:11 p.m. March 20
3/20/01 CA Independent SystemOperator
9:17 a.m.(PST)
SouthernCalifornia Area
Interruption ofFirm Power
300-500 Undetermined 2:33 p.m. March 20
5/7/01CA Independent SystemOperator (WSCC) 4:45 p.m. California
Interruption ofFirm Power
(Public Appeal)300 Undetermined 6:00 p.m. May 7
5/8/01CA Independent SystemOperator (WSCC) 3:10 p.m. California
Interruption ofFirm Power
(Public Appeal)400 Undetermined 5:30 p.m. May 8
5/8/01 Southern CaliforniaEdison (WSCC)
3:12 p.m. California Interruption ofPower
225, 159 70,848, 56,718 5:00 p.m. May 8
Source: Emergency Operations Center, Form EIA-417R, "Electric Power System Emergency Report."
Energy Information Administration/Electric Power Monthly August 2001 157
Appendix C
Technical Notes
Data Sources
The Electric Power Monthly (EPM) is prepared by theElectric Power Division, Office of Coal, Nuclear, Electricand Alternate Fuels (CNEAF), Energy InformationAdministration (EIA), U.S. Department of Energy. Datapublished in the EPM are compiled from the followingdata sources: Form EIA-759, “Monthly Power PlantReport,” Form EIA-900 “Monthly Nonutility PowerReport,” FERC Form 423, “Monthly Report of Cost andQuality of Fuels for Electric Plants,” Form EIA-826,“MonthlyElectric Utility Sales and Revenue Report withState Distributions,” Form EIA-861, “Annual ElectricUtility Report,” Form EIA-860A, “Annual ElectricGenerator ReportBUtility,” Form EIA-860B, “AnnualElectric Generator ReportBNonutility,” and the FormEIA-906, “Power Plant Report” (Regulated andNonregulated).
Form EIA-759
The Form EIA-759 is a cutoff model sample of approxi-mately 240 electric utilities drawn from the frame of alloperators of electric utility plants (approximately 700electric utilities) that generate electric power for publicuse. Data will be collected on an annual basis from theremaining operators of electric utility plants. The newmonthly data collection is from all utilities with at leastone plant with a nameplate capacity of 50 megawatts ormore. (Note: includes all nuclear units). However, thefew utilities that generate electricity using renewablefuel sources other than hydroelectric are all included inthe sample. The Form EIA-759 is used to collectmonthly data on net generation; consumption of coal,petroleum, and natural gas; and end-of-the-monthstocks of coal and petroleum for each plant by fuel-typecombination. Summary data from the Form EIA-759 arealso contained in the Electric Power Annual (EPA),Monthly Energy Review (MER), and the Annual EnergyReview (AER). These reports present aggregate data esti-mates for electric utilities at the U.S., Census division,and North American Electric Reliability Council Region(NERC) levels.
Instrument and Design History. Prior to 1936, theBureau of the Census and the U.S. Geological Surveycollected, compiled, and published data on the electricpower industry. In 1936, the Federal Power Commission
(FPC) assumed all data collection and publicationresponsibilities for the electric power industry andimplemented the FPC Form 4. The Federal Power Act,Sections 311 and 312, and FPC Order 141 define thelegislative authority to collect power production data.The Form EIA-759 replaced the FPC Form 4 in January1982. In January 1996, the Form EIA-759 was changedto collect data from a cutoff model sample of plantswith a nameplate capacity of 25 megawatts or more. InJanuary 1999, the Form EIA-759 was changed to collectdata for a cutoff sample of plants with a nameplatecapacity of 50 megawatts or more.
Data Processing. The Form EIA-759, along with areturn envelope, is mailed to respondents approxi-mately 4 working days before the end of the month. Thecompleted forms are to be returned to the EIA by the10th day after the end of the reporting month. Afterreceipt, data from the completed forms are manuallylogged in and edited before being keypunched forautomatic data processing. An edit program checks thedata for errors not found during manual editing. Theelectric utilities are telephoned to obtain data in cases ofmissing reports and to verify data when questions ariseduring editing. After all forms are received from therespondents, the final automated edit is submitted.Following verification of the data, text and tables ofaggregated data are produced for inclusion in the EPM.Following EIA approval of the EPM, the data are madeavailable for public use, on a cost-recovery basis,through custom computer runs, data tapes, or inpublications.
FERC Form 423
The Federal Energy Regulatory Commission (FERC)Form 423 is a monthly record of delivered-fuel pur-chases, submitted by approximately 230 electric utilitiesfor each electric generating plant with a total steam-elec-tric and combined-cycle nameplate capacity of 50 ormore megawatts. Summary data from the FERC Form423 are also contained in the EPA, MER, and the Costand Quality of Fuels for Electric Utility Plants B Annual.These reports present aggregated data on electricutilities at the U.S., Census division, and State levels.
Instrument and Design History. On July 7, 1972, theFPC issued Order Number 453 enacting the New Code
Energy Information Administration/Electric Power Monthly August 2001158
of Federal Regulations, Section 141.61, legally creatingthe FPC Form 423. Originally, the form was used to col-lect data only on fossil-steam plants, but was amendedin 1974 to include data on internal combustion andcombustion turbines. The FERC Form 423 replaced theFPC Form 423 in January 1983. The FERC Form 423eliminated peaking units, which were previously col-lected on the FPC Form 423. In addition, the generatornameplate capacity threshold was changed from 25megawatts to 50 megawatts. This reduction in coverageeliminated approximately 50 utilities and 250 plants. Allhistorical FPC Form 423 data in this publication wererevised to reflect the new generator nameplate capacitythreshold of 50 or more megawatts reported on theFERC Form 423. In January 1991, the collection of dataon the FERC Form 423 was extended to include com-bined-cycle units. Historical data have not been revisedto include these units. Starting with the January 1993data, the FERC began to collect the data directly fromthe respondents.
Data Processing. The FERC processes the data throughedits and each month provides the EIA with a diskettecontaining the data. The EIA reviews the data foraccuracy. Beginning with May 1994 data, an additionalquality check began in which coal data are comparedwith data prepared by Resource Data International, Inc.,of Boulder, Colorado. Following verification of thedata, text and tables of aggregated data are producedfor inclusion in the EPM. After the EPM is cleared bythe EIA, the data become available for public use, on acost-recovery basis, through custom computer runs orin publications.
Form EIA-826
The Form EIA-826 is a monthly collection of data fromapproximately 350 of the largest primarily inves-tor-owned and publicly owned electric utilities. Amodel is then applied to estimate for the entire universeof U.S. electric utilities. The electric power sales dataare used by the Federal Reserve Board in their economicanalyses.
Instrument and Design History. The collection of elec-tric power sales, revenue, and income data began in theearly 1940's and was established as FPC Form 5 by FPCOrder 141 in 1947. In 1980, the report was revised withonly selected income items remaining and became theFERC Form 5. The Form EIA-826 replaced the FERCForm 5 in January 1983. In January 1987, the FormEIA-826 was changed to the “Monthly Electric UtilitySales and Revenue Report with State Distributions.” Itwas formerly titled, “Electric Utility Company MonthlyStatement.” The Form EIA-826 was revised in January
1990, and some data elements were eliminated. In 1993,EIA for the first time used a model sample for the FormEIA-826. A stratified-random sample, employing auxil-iary data, was used for each of the 4 previous years.(See previous issues of this publication, and (Knaub, 12)for details.) The current sample for the Form EIA-826,which was designed to obtain estimates of electricitysales and revenue per kilowatthour at the State level byend-use sector, was chosen to be in effect for theJanuary 1993 data.
Frame. The frame for the Form EIA-826 was originallybased on the 1989 submission of the Form EIA-861(Section 1.4), which consisted of approximately 3,250electric utilities selling retail and/or sales for resale.Note that for the Form EIA-826, the EIA is onlyinterested in retail sales. Updates have been made tothe frame to reflect mergers that affect data processing.Some electric utilities serve in more than one State.Thus, the State-service area is actually the samplingunit. For each State served by each utility, there is autility State-part, or “State-service area.” This approachallows for an explicit calculation of estimates for sales,revenue, and revenue per kilowatthour by end-usesector (residential, commercial, industrial and other) atState, Census division, and the U.S. level. Regressordata came from the Form EIA-861. (Note that estimatesat the “State level” are for sales for the entire State, andsimilarly for “Census division” and “U.S.” levels.)
The preponderance of electric power sales to ultimateconsumers in each State are made by a few largeutilities. Ranking of electric utilities by retail sales on aState-by-State basis revealed a consistent pattern ofdominance by a few electric utilities in nearly all 50States and the District of Columbia. These dominantelectric utilities were selected as a model sample. Theseelectric utilities constitute about 8 percent of thepopulation of U.S. electric utilities, but providethree-quarters of the total U.S. retail electricity sales.The procedures used to derive electricity sales, revenue,revenue per kilowatthour, and associated relativestandard error (RSE) estimates are provided in the FormEIA-826 subsection of the Formulas Data Section. See(Knaub, 12) for a study of RSE estimates for this survey.
Data Processing. The forms are mailed each year to theelectric utilities with State-parts selected in the sample.The completed form is to be returned to the EIA by thelast calendar day of the month following the reportingmonth. Nonrespondents are telephoned to obtain thedata. Imputation, in model sampling, is an implicit partof the estimation. That is, data that are not available,either because it was not part of the sample or becausethe data are missing, are estimated using a model. The
Energy Information Administration/Electric Power Monthly August 2001 159
data are edited and entered into the computer whereadditional checks are completed. After all forms havebeenreceived from the respondents, the finalautomatededit is submitted. Following verification, tables and textof the aggregated data are produced for inclusion in theEPM. After the EPM receives clearance from the EIA,the data are made available for public use throughcustom computer runs, data tapes, or in publications(EPA, AER) on a cost-recovery basis.
Form EIA-900
The Form EIA-900, “MonthlyNonutility Power Report,”is a cutoff model sample drawn from the frame for theForm EIA-860B, “Annual Electric Generator Report BNonutility.” Members of the Form EIA-860B frame withnameplate capacity greater than or equal to 50 mega-watts constitute the sample for the Form EIA-900. TheForm EIA-900 currently is used to collect monthly dataon net generation; consumption of coal, petroleum, andnatural gas; and end-of-the month stocks of coal andpetroleum.
Instrument and Design History. The Form EIA-900was implemented to collect monthly data, starting withJanuary 1996. The reason for its inception was to fill, inpart, a “data gap” that existed on a monthly basis whencomparing utility sales to end users (from the FormEIA-826) with utility generation (from the FormEIA-759). This data gap occurred because utility salesdata include electricity purchased from nonutilities andbecause of other factors such as transmission losses andimports/exports. In light of sampling and nonsamplingerror, a more complete description of events may begleaned by including results based on the FormEIA-900.
Data Processing. The Form EIA-900 is mailed to alloperating Form EIA-860B respondent facilities withmore than 50 megawatts of total operating capacity. In1996, there were approximately 380 respondents for theForm EIA-900. Data submission is allowed by Internete-mail, postal mail, telephone or facsimile (FAX) trans-mission. In the near future, the EIA plans to allowtouchtone data entry. At first submission, the numberfor the one datum element collected is compared to apreviously submitted number, through the use of aninteractive edit. Later, batch edits are applied. One editis used to compare total sales, generation, line lossesand imports/exports to determine if the results arereasonable. Another edit is applied on an individual,annual basis, to compare 12 month totals for the FormEIA-900 submissions to the corresponding FormEIA-860B submissions.
Form EIA-861
The Form EIA-861 is a mandatory census of electricutilities in the United States. The survey is used tocollect information on power production and sales datafrom approximately 3,250 electric utilities. The datacollected are used to maintain and update the EIA'selectric utility frame data base. This data base sup-ports queries from the Executive Branch, Congress,other public agencies, and the general public. Summarydata from the Form EIA-861 are also contained in theElectric Sales and Revenue; the Electric Power Annual; theFinancial Statistics of Selected Publicly Owned ElectricUtilities; the Financial Statistics of Selected Investor-OwnedElectric Utilities; the AER; and, the Annual Outlook forU.S. Electric Power. These reports present aggregatetotals for electric utilities on a national level, by State,and by ownership type.
Instrument and Design History. The Form EIA-861was implemented in January 1985 to collect data as ofyear-end 1984. The Federal Administration Act of 1974(Public Law 93-275) defines the legislative authority tocollect these data.
Data Processing. The Form EIA-861 is mailed to therespondents in February of each year to collect data asof the end of the preceding calendar year. The data aremanually edited before being entered into theinteractive on-line system. Internal edit checks are per-formed to verify that current data total across andbetween schedules, and are comparable to datareported the previous year. Edit checks are also per-formed to compare data reported on the Form EIA-861and similar data reported on the Forms EIA-826;EIA-412, “Annual Report of Public Electric Utilities;”and FERC Form 1, “Annual Report of Major ElectricUtilities, Licensees, and Others.” Respondents are tele-phoned to obtain clarification of reported data and toobtain missing data.
Form EIA-860A
The Form EIA-860A is a mandatory census of electricutilities in the United States that operate power plantsor plan to operate a power plant within 5 years of thereporting year. The survey is used to collect data onelectric utilities' existing power plants and their 5-yearplans for constructing new plants, generating unitadditions, modifications, and retirements in existingplants. Data on the survey are collected at the gen-erating unit level. These data are then aggregated toprovide totals by energy source (coal, petroleum, gas,water, nuclear, other) and geographic area (State, NERC
Energy Information Administration/Electric Power Monthly August 2001160
region, Federal region, Census division). Additionally,at the national level, data are aggregated to providetotals by prime mover. Data from the Form EIA-860 arealso summarized in the Inventory of Power Plants in theUnited States and the EPA, and as input to publications(AER) and studies by other offices in the Department ofEnergy.
Instrument and Design History. The Form EIA-860Awas implemented in January 1999 to collect data as ofJanuary 1, 1999. The Federal Energy AdministrationAct of 1974 (Public Law 93-275) defines the legislativeauthority to collect these data. Form EIA-860A replacedForm EIA-860, “Annual Electric Generating Report.”The difference in the data requirements of Form EIA-860A and those of the Form EIA-860 that preceded it isthat respondents are required to report 5-year plans onForm EIA-860A instead of 10-year plans previouslyrequired to be reported on Form EIA-860.
Data Processing. The Form EIA-860A is mailed toapproximately 900 respondents in November orDecember to collect data as of January 1 of the reportingyear, where the reporting year is the calendar year inwhich the report was filed. Effective with the 1996reporting year, respondents have the option of filingForm EIA-860A directly with the EIA or through anagent, such as the respondent's regional electricreliability council. Data reported through the regionalelectric reliability councils are submitted to the EIAelectronically from the North American Electric Relia-bility Council (NERC). Data for each respondent arepreprinted from the applicable data base. Respondentsare instructed to verify all preprinted data and tosupply missing data. The data are manually editedbefore being keypunched for automatic data processing.Computer programs containing additional edit checksare run. Respondents are telephoned to obtain correc-tion or clarification of reported data and to obtainmissing data, as a result of the manual and automaticediting process.
Form EIA-860B
The Form EIA-860B is a mandatory survey of allexisting and planned nonutility electric generating facili-ties in the United States with a total generatornameplate capacity of 1 or more megawatts. In 1992,the reporting threshold of the Form EIA-860B waslowered to include all facilities with a combined name-plate capacity of 1 or more megawatts. Previously, datawere collected every 3 years from facilities with a name-plate capacity between 1 and 5 megawatts. Plannedgenerators are defined as a proposal by a company toinstall electric generating equipment at an existing or
planned facility. The proposal is based on the ownerhaving obtained (1) all environmental and regulatoryapprovals, (2) a contract for the electric energy, or (3)financial closure on the facility. The Form consists ofSchedules I, “Identification and Certification;” ScheduleII, “Facility Information”; Schedule III, “StandardIndustrial Classification Code Designation”; ScheduleIVA, “Facility Fuel Information”; Schedule IVB, “FacilityThermal and Generation Information”; Schedule V,“Facility Environmental Information”; and Schedule VI,“Electric Generator Information.”
Submission of the Form EIA-860B is required from allfacilities that have a combined facility nameplatecapacity of 1 megawatt or more. Schedule V, “FacilityEnvironmental Information” is only required of thosefacilities of 25 megawatts or more.
The form is used to collect data on the installed capa-city, energy consumption, generation, and electricenergy sales to electric utilities and other nonutilities byfacility. Additionally, the form is used to collect data onthe quality of fuels burned and the types of environ-mental equipment used by the respondent. These dataare aggregated to provide geographic totals for selectedStates and at the Census division and national levels.Since the Form EIA-860B data are considered con-fidential, suppression of some data is necessary toprotect the confidentiality of the individual respondentdata. See “Confidentiality of the Data” in this sectionfor further information.
Instrument and Design History. The Form EIA-867,“Annual Nonutility Power Producer Report,” wasimplemented in December 1989 to collect data as ofyear-end 1989. The Federal Energy Administration Actof 1984 (Public Law 93-275) defines the legislativeauthority to collect these data. Form EIA-860B, “AnnualElectric Generating Report BNonutility,” replaced FormEIA-867 in 1998.
Data Processing. The Form EIA-860B is mailed to therespondents in January to collect data as of the end ofthe preceding calendar year. Static data for eachrespondent are preprinted from the previous year, andthe respondents are instructed to verify all preprintedinformation and to supply the missing data. Thecompleted forms are to be returned to the EIA by April30. The response rate for all facilities for whichaddresses were confirmed was 100 percent. The dataare manually edited before being keyed for automaticdata processing. Computer programs containing addi-tional edit checks are run. Respondents are telephonedto obtain corrections or clarifications of reported data
Energy Information Administration/Electric Power Monthly August 2001 161
x (t2) & x (t1)
x (t1)× 100,
and to obtain missing data as a result of the manual andautomated editing.
Form EIA-906
In January 2001, Form EIA-906 superseded Forms EIA-759 and 900. The Form EIA-906 collects monthly plant-level data on generation, fuel consumption, stocks anduseful thermal output from electric utilities andnonutilities. It is a model-based sample of approxi-mately 240 electric utilities and 800 nonutilities.
The census data from Form EIA-860B are used asregressors in a regression model that estimates (im-putes) values for those not collected on the sample. Therelationship between the data that are collected on thesample and the corresponding regressor data is neededto impute these values and arrive at aggregate levelestimates. The modeling is described in detail in theInternet statistics journal, InterStat, August 1999, “UsingPrediction-Oriented Software for Survey Estimation,”http://interstat.stat.vt.edu/InterStat/ARTICLES/1999/abstracts/G99001.html-ssi. For a more general dis-cussion of model-based sampling and estimation, pleasesee the EIA website at http://www.eia.doe.gov/cneaf/electricity/forms/eiawebme.pdf. Note that thereare times when a model may not apply, such as for anew plant, when the relationship between the variableof interest and the regressor data does not hold. In sucha case, the new information represents only itself, andsuch numbers are added to model results whenestimating totals. Further, there are times when sampledata may be known to be in error, or are not reported.Such cases are treated as if they were never part of themodel-based sample, and values are imputed.
The data processing procedures for Form EIA-906 arethe same as those described for Forms EIA-759 and EIA-900.
Note that there are times when a model may not apply,such as in the case of a substantial reclassification ofsales, when the relationship between the variable ofinterest and the regressor data does not hold. In such acase, the new information represents only itself, andsuch numbers are added to model results whenestimating totals. Further, there are times when sampledata may be known to be in error, or are not reported.Such cases are treated as if they were never part of themodel-based sample, and values are imputed.
Formulas/Methodologies
The following formula is used to calculate percentdifferences.
Percent Difference =
where x (t1) and x (t2) denote the quantity at year t1 andsubsequent year t2.
Form EIA-826
The Form EIA-826 data are collected at the utility levelby sector and State. Data from the Form EIA-826 areused to determine estimates by sector at the State,Census division, and national level for the entire cor-responding State, Census division, or national category.Form EIA-861 data were used as the frame from whichthe sample was selected, and also as regressor data.
The sample consists of approximately 340 electricutilities. This includes a somewhat larger number ofState-service areas for electric utilities. Estimation pro-cedures include imputation to account for nonresponse.Nonsampling error must also be considered. Thenonsampling error is not estimated directly, althoughattempts are made to minimize it.
State-level sales and revenue estimates are calculated.Also, a ratio estimation procedure is used for estimationof revenue per kilowatthour at the State level. Theseestimates are accumulated separately to produce theCensus division and U.S. level estimates.
The relative standard error (RSE) statistic, usually givenas a percent, describes the magnitude of sampling errorthat might reasonably be incurred. The RSE is thesquare root of the estimated variance, divided by thevariable of interest. The variable of interest may be theratio of two variables (for example, revenue perkilowatthour), or a single variable (for example, sales).
The sampling error may be less than the nonsamplingerror. Nonsampling errors may be attributed to manysources, including the response errors, definitional diffi-culties, differences in the interpretation of questions,mistakes in recording or coding data obtained, andother errors of collection, response, or coverage. Thesenonsamplingerrors also occur in complete censuses. Ina complete census, this problem may become unman-ageable. One indicator of the magnitude of possiblenonsampling error may be gleaned by examining thehistory of revisions to data for a survey (Table B2).
Relative standard errors (RSEs) are indicators of errordue to sampling. (RSEs do not account for nonsamplingerrors, such as errors of misclassification or transposeddigits. However, estimates of RSEs, although not
Energy Information Administration/Electric Power Monthly August 2001162
designed to measure nonsampling error, are affected bythem). In fact, large RSE estimates found in preliminarywork with these data have often indicated nonsamplingerrors, which were then identified and corrected. Usingthe Central Limit Theorem, which applies to sums andmeans such as are applicable here, there is approxi-mately a 68-percent chance that the true sampling erroris less than the corresponding RSE. Note that reportedRSEs are always estimates, themselves, and are usually,as here, reported as percents. As an example, supposethat a revenue-per-kilowatthour value is estimated to be5.13 cents per kilowatthour with an estimated RSE of 1.6percent. This means that, ignoring any nonsamplingerror, there is approximately a 68-percent chance thatthe true average revenue per kilowatthour is withinapproximately 1.6 percent of 5.13 cents per kilowatthour(that is, between 5.05 and 5.21 cents per kilowatthour).There is approximately a 95-percent chance of a truesampling error being 2 RSEs or less.
The basic approach used is shown in (Royall, 6) withadditional discussion of variance estimation in (Royalland Cumberland, 7), (Royall and Cumberland, 8), and(Knaub, 5).
The detailed methodology for estimation for this surveyis described in InterStat, June 2000, “Using Predic-tion-Oriented Software for Survey Estimation - Part II:RatiosofTotals,” http://interstat.stat.vt.edu/InterStat/ARTICLES/2000/abstracts/U00002.html-ssi.
Note that there are times when a model may not apply,such as in the case of a substantial reclassification ofsales, when the relationship between the variable ofinterest and the regressor data does not hold. In such acase, the new information represents only itself, andsuch numbers are added to model results whenestimating totals. Further, there are times when sampledata may be known to be in error, or are not reported.Such cases are treated as if they were never part of themodel-based sample, and values are imputed.
As a final adjustment based on our most complete data,use is made of final Form EIA-861 data, when available.The annual totals for Form EIA-826 data by State andend-use sector are compared to the corresponding FormEIA-861 values for sales and revenue. The ratio of thesetwo values in each case is then used to adjust eachcorresponding monthly vale.
Additional informationor clarification can be addressedto the Energy Information Administration as indicatedin the “Contacts” section of this publication.
Form EIA-900
The Form EIA-900 data are collected at the facility level,which is roughly the nonutility equivalent of plant level.The cutoff sample uses generation to determine the esti-mated total nonutility monthly generation based on theannual Form EIA-860B, “Annual Generator Report BNonutility,” data available. Fuel consumption estimatesare based on relating the estimated monthly generationto the consumption data for the Form EIA-860B.
Form EIA-759
Data for the Form EIA-759 are collected at the plantlevel. Estimates are then provided for geographic levels.Consumption of fuel(s) is converted from quantities (inshort tons, barrels, or thousand cubic feet) to Btu at theplant level. End-of-month fuel stocks for a singlegenerating plant may not equal beginning-of-the-monthstocks plus receipts less consumption, for many reasons,including the fact that several plants may share thesame fuel stock.
A cutoff model sampling and estimation are employed,using the same multiple regression model. Once again,as described under the corresponding subsection on theForm EIA-900, details of the estimation of totals andvariances of totals are published on the Internet in apaper entitled “Weighted Multiple Regression Esti-mation for Survey Model Sampling (Knaub, 13).”
At the fuel and State level (i.e., lowest aggregate level),there are a number of cases where the minimal samplesize of three is not met, when using a 25 MW cutoff.Imputation of historic values for the smallest plants isused to supplement actual values for the largest ones.However, at the NERC level, this is not necessary. Dataelement totals for each NERC region, by fuel type, areestimated using model sampling. These samples arecomposed solely of data reported for the plants actuallyin the sample. The national level estimate from this isthen considered our best estimate, and all otherestimates are apportioned accordingly.
As a final adjustment based on our most complete data,use is made of final Form EIA-759 annual census, whenavailable. The annual census for Form EIA-759 data byState and energy source are compared to the corres-ponding monthly Form EIA-759 values. The ratio ofthese two values in each case is then used to adjust eachcorresponding monthly value.
Energy Information Administration/Electric Power Monthly August 2001 163
ji
(Ri × Ai × U),
ji
(Ri × Ai)
ji
Ri
,
ji
(Ri × Ai × Ci)
ji
(Ri × Ai),
Uji
(Ri × Ai × Ci)
108j
i
Ri
,
FERC Form 423
Data for the FERC Form 423 are collected at the plantlevel. These data are then used in the followingformulas to produce aggregates and averages for eachfuel type at the State, Census division, and U.S. level.For these formulas, receipts and average heat contentare at the plant level. For each geographic region, thesummation G represents the sum of all plants in thatgeographic region. Additionally,
! For coal, units for receipts (R) are in tons, units foraverage heat content (A) are in Btu per pound, andthe unit conversion (U) is 2,000 pounds per ton;
! For petroleum, units for receipts (R) are in barrels,units for average heat content (A) are in Btu pergallon, and the unit conversion (U) is 42 gallonsper barrel;
! For gas, units for receipts (R) are in thousand cubicfeet (Mcf), average heat content (A) are in Btu percubic foot, and the unit conversion (U) is 1,000cubic feet per Mcf.
Total Btu =
where I denotes a plant; Ri = receipts for plant I;Ai = average heat content for receipts at plant I; and,U = unit conversion;
Weighted Average Btu =
where I denotes a plant; Ri = receipts for plant I; and, Ai
= average heat content for receipts at plant I.
The weighted average cost in cents per million Btu iscalculated using the following formula:
Weighted Average Cost =
where I denotes a plant; Ri = receipts for plant I;Ai average heat content for receipts at plant I;and Ci = cost in cents per million Btu for plant I.
The weighted average cost in dollars per unit is calcu-lated using the following formula:
Weighted Average Cost =
where I denotes a plant; Ri = receipts for plant I;Ai = average heat content for receipts at plant I;U = unit conversion; and, Ci = cost in cents per millionBtu for plant I.
Form EIA-861
Data for the Form EIA-861 are collected at the utilitylevel from all electric utilities in the United States, itsterritories, and Puerto Rico. Form EIA-861 data in thispublication are for the United States only. These dataare then aggregated to provide geographic totals at theState, NERC region, Census division, and national level.Sources and disposition of data are also provided byutility class of ownership and retail consumer class ofservice. Average revenue (nominal dollars) perkilowatthour of electricity sold is calculated by dividingtotal annual retail revenue (nominal dollars) by the totalannual retail sales of electricity.
Average revenue per kilowatthour is defined as the costper unit of electricity sold and is calculated by dividingretail electric revenue by the corresponding sales ofelectricity. The average revenue per kilowatthour iscalculated for all consumers and for each sector (resi-dential, commercial, industrial, and other sales).
Electric utilities typically employ a number of rateschedules within a single sector. These alternative rateschedules reflect the varying consumption levels andpatterns of consumers and their associated impact onthe costs to the electric utility for providing electricalservice. The average revenue per kilowatthour reportedin this publication by sector represents a weightedaverage of consumer revenue and sales within thatsector and across sectors for all consumers.
The electric revenue used to derive the average revenueper kilowatthour is the operating revenue reported bythe electric utility. Operating revenue includes energycharges, demand charges, consumer service charges,environmental surcharges, fuel adjustments, and othermiscellaneous charges.
Electric utility operating revenues cover, among othercosts of service, State and Federal income taxes andtaxes other than income taxes paid by the utility. TheFederal component of these taxes are, for the most part,“payroll” taxes. State and local authorities tax the valueof plant (property taxes), the amount of revenues (grossreceipts taxes), purchases of materials and services(sales and use taxes), and a potentially long list of otheritems that vary extensively by taxing authority. Taxesdeducted from employees' pay (such as Federal income
Energy Information Administration/Electric Power Monthly August 2001164
y
b
taxes and employees' share of social security taxes) arenot a part of the utility's “tax costs,” but are paid to thetaxing authorities in the name of the employees. Thesetaxes are included in the utility's cost of service (forexample, revenue requirements) and are included inthe amounts recovered from consumers in rates andreported in operating revenues.
Electric utilities, like many other business enterprises,are required by various taxing authorities to collect andremit taxes assessed on their consumers. In this regard,the electric utility serves as an agent for the taxingauthority. Taxes assessed on the consumer, such as agross receipts tax or sales tax, are called “pass through”taxes. These taxes do not represent a cost to the utilityand are not recorded in the operating revenues of theutility. However, taxing authorities differ as to whethera specific tax is assessed on the utility or the con-sumerCwhich, in turn, determines whether or not thetax is included in the operating revenue of the electricutility.
Form EIA-860A
Data from the Form EIA-860A are submitted at thegeneratingunit level and are then aggregated to providetotal capacity by energy source and geographic area. Inaddition, at the national level, data are aggregated byprime mover.
Estimated values for net summer and net winter capa-bility for electric generating units were developed byuse of a regression formula. The formula is used toestimate values for existing units where data aremissing and for projected units. It was found that azero-intercept linear regression works very well forestimating capability based on nameplate capacity. The
(b)only parameter then is the slope that is used to relatey ' bx,capacity to capability as follows: where is the
estimated capability, and x is the known nameplatecapacity. There will be a different value for fordifferent prime movers and for summer and wintercapabilities and it will also depend upon the age of thegenerator. For more details see the Inventory of PowerPlants.
Form EIA-860B
Gross electricity generation data from the FormEIA-860B, reported by generator, are aggregated toprovide totals by energy source and geographic area.Nonutility power producers report gross electricity
generated on the Form EIA-860B, unlike electric utilitiesthat report net generation on various EIA and FERCforms. Nonutilities generally do not measure and recordelectrical consumption used solely for the production ofelectricity. Nonutility generators and associated aux-iliary equipment are often an integral part of amanufacturing or other industrial process and indi-vidual watthour meters are not generally installed onauxiliary equipment.
Estimated values for net generation from nonutilitypower producers were developed by EIA using grossgeneration, prime mover, fuels, and type of air pollutioncontrol data reported on the Form EIA-860B. The differ-ence between gross and net generation is the electricityconsumed by auxiliary equipment and environmentalcontrol devices such as pumps, fans, coal pulverizers,particulate collectors, and flue gas desulfurization(FGD) units. The difference between gross and netgeneration is sometimes called parasitic load. In smallerpower plants rotating auxiliaries are almost alwayselectric motors. In large power plants that producesteam, rotating auxiliaries can be powered by eithersteam turbines or electric motors and sometimes bothbecause of cold startup requirements.
This methodology for estimating net generation fromgross generation is based on determining typical energyconsumption for auxiliary electrical equipment associ-ated with electrical generators. For instance, wind tur-bines have none of the auxiliaries common to acoal-burning power plant such as a coal pulverizers,fans, and emission controls. On the other hand,windfarms do consume electricity since automatic,computer-based control systems are used to controlblade pitch and speed thereby affecting generatorelectricity output.
Shown on the top of the following page are theconversion factors used to estimated net generation bynonutility generators. The factors are typical of amodern electric power plant but could vary significantlybetween individual plants. Net generation is calculatedby multiplying the appropriate conversion factor by thereported gross electrical generation.
These conversion factors were estimated by the staff ofthe Office of Coal, Nuclear, Electric and Alternate Fuels,Energy Information Administration. The primary refer-ence used in developing the conversion factors wasSteam, Its Generation and Use, 40th Edition, Babcock &Wilcox, Barberton, Ohio.
Energy Information Administration/Electric Power Monthly August 2001 165
aFactor reduced by .01 if the facility has flue gas particulate collectorsand another .03 if the facility has flue gas desulfurization (FGD)equipment. Facilities under 25 megawatts and burning coal in traditionalboilers (e.g., not fluidized bed boilers) are assumed to have particulateand FGD equipment.
Average Heat Content
Heat content values (Table C1) collected on the FERCForm 423 were used to convert the consumption datafrom the Form EIA-759 into Btu. Respondents to FERCForm 423 represent a subset of all generating plants(steam plants with a capacity of 50 megawatts orlarger), while Form EIA-759 respondents generallyrepresent generating plants with a combined capacity of25 or more megawatts. The results, therefore, may notbe completely representative.
Quality of Data
The CNEAF office is responsible for routine data im-provement and quality assurance activities. All oper-ations in this office are done in accordance with formalstandards established by the EIA. These standards arethe measuring rod necessary for quality statistics. Dataimprovement efforts include verification of data-keyedinput by automatic computerized methods, editing bysubject matter specialists, and follow-up on nonre-spondents. The CNEAF office supports the qualityassurance efforts of the data collectors by providingadvisory reviews of the structure of informationrequirements, and of proposed designs for new andrevised data collection forms and systems. Once imple-mented, the actual performance of working datacollection systems is also validated. Computerizedrespondent data files are checked to identify those whofail to respond to the survey. By law, nonrespondentsmay be fined or otherwise penalized for not filing amandatory EIA data form. Before invoking the law, theEIA tries to obtain the required information byencouraging cooperation of nonrespondents.
Completed forms received by the CNEAF office aresorted, screened for completeness of reported informa-
tion, and keyed onto computer tapes for storage andtransfer to random access data bases for computerprocessing. The information coded on the computertapes is manually spot-checked against the forms tocertify accuracy of the tapes. To ensure the qualitystandards established by the EIA, formulas that use thepast history of data values in the data base have beendesigned and implemented to check data input forerrors automatically. Data values that fall outside theranges prescribed in the formulas are verified bytelephoning respondents to resolve any discrepancies.
Conceptual problems affecting the quality of data arediscussed in the report, An Assessment of the Quality ofSelected EIA Data Series: Electric Power Data. Thisreport is published by the Energy Information Adminis-tration (Office of Statistical Standards). See item 2 inAppendix A.
Data Precision
Monthly sample survey data have both sampling andnonsampling errors. Sampling errors may be expectedsince all data are not collected and, therefore, must bemathematically estimated. (Note that the annual seriesfor a monthly sample is not subject to sampling errorbecause it is a census). Nonsampling errors are theresult of incorrect allocation of data (for example,transcriptions or misclassifications) and can be difficultto control and estimate. A study of coefficients ofvariance and data revisions was conducted so that theappropriate levels of precision, based on the accuracyand completeness of the data from which the estimatesare derived, is provided in this report for averagerevenue per kilowatthour of electricity sold. It wasjudged that three significant digits are justified foraverage revenue per kilowatthour of electricity sold atthe U.S. level except for monthly data prior to 1990where two significant digits are more appropriate.
Data Imputation
It may become necessary (as in March and April 1996FERC Form 423 data) to impute for some data, even ifa 100-percent census is normally collected withoutincident. In such cases, a modeling approach, similar towhat is done for the Form EIA-826, can be imple-mented. The estimation methodologies for modelsampling and model imputation are identical.
Data Editing System
Data from the form surveys are edited on a monthlybasis using automated systems. The edit includes both
Energy Information Administration/Electric Power Monthly August 2001166
deterministic checks, in which records are checked forthe presence of required fields and their validity; andstatistical checks, in which estimation techniques areused to validate data according to their behavior in thepast and in comparison to other current fields. When alldata have passed the edit process, the system buildsmonthly master files, which are used as input to theEPM.
Confidentiality of the Data
In general, the data collected on the forms used forinput to this report are not confidential. However, datafrom the Form EIA-900, “Monthly Nonutility PowerReport,” and from the Form EIA-860B, “Annual ElectricGenerator Report B Nonutility,” are considered con-fidential and must adhere to EIA's “Policy on theDisclosure of Individually Identifiable Energy Infor-mation in the Possession of the EIA” (45Federal Register59812 (1980)).
Rounding Rules for Data
Given a number with r digits to the left of the decimaland d+t digits in the fraction part, with d being theplace to which the number is to be rounded and t beingthe remaining digits which will be truncated, thisnumber is rounded to r+d digits by adding 5 to the(r+d+1)th digit when the number is positive or bysubtracting 5 when the number is negative. The t digitsare then truncated at the (r+d+1)th digit. The symbol fora rounded number truncated to zero is (*).
Data Correction Procedure
The Office of Coal, Nuclear, Electric and Alternate Fuelshas adopted the following policy with respect to therevision and correction of recurrent data in energypublications:
1. Annual survey data collected by this office arepublished either as preliminary or final when firstappearing in a data report. Data initially releasedas preliminary will be so noted in the report. Thesedata will be revised, if necessary, and declaredfinal in the next publication of the data.
2. All monthly and quarterly survey data collectedby this office are published as preliminary. These
data are revised only after the completion of the12-month cycle of the data. No revisions are madeto the published data before this.
3. The magnitudes of changes due to revisions ex-perienced in the past will be included in the datareports, so that the reader can assess the accuracyof the data.
4. After data are published as final, corrections willbe made only in the event of a greater than onepercent difference at the national level. Correc-tions for differences that are less than thebefore-mentioned threshold are left to the dis-cretion of the Office Director. Note that in thisdiscussion, changes or revisions are referred to as“errors.”
In accordance with policy statement number 3, themean value (unweighted average) for the absolutevalues of the 12 monthly revisions of each item are pro-vided at the U.S. level for the past 4 years (Table C2).For example, the mean of the 12 monthly absolute errors(absolute differences between preliminary and finalmonthly data) for coal-fired generation in 1995 was 49.That is, on average, the absolute value of the changemade each month to coal-fired generation was 49million kilowatthours.
The U.S. total net summer capability, updated monthlyin the EPM (Table 1), is based solely on new electricgenerating units and retirements which come to theattention of the EIA during the year through telephonecalls with electric utilities and on the Form EIA-759,“Monthly Power Plant Report,” and may not include allactivity for the month. Data on net summer capability,including new electric generating units, are collectedannually on the Form EIA-860A, “Annual ElectricGenerator Report B Utility,” and Form 860B “AnnualElectric Generator Report B Nonutility.”
Use of the Glossary
The terms in the glossary have been defined for generaluse. Restrictions on the definitions as used in these datacollection systems are included in each definition whennecessary to define the terms as they are used in thisreport.
Table C1. Average Heat Content of Fossil-Fuel Receipts, April 2001
Gas1 Census Division Coal1 Petroleum1
(Btu per thousandand State (Btu per ton) (Btu per barrel)
East North Central ........................................................ 20,963,879 5,932,779 1,021,582Illinois ............................................................................ 19,341,570 5,805,473 1,040,522Indiana ........................................................................... 21,146,288 5,756,718 1,034,208
U.S. Average ................................................................... 19,953,474 6,358,792 1,032,171
1 Data represents weighted values. a Consists mostly of blast furnace gas which has a heat content of 74,000 Btu per thousand cubic feet.
Note: Data for 2001 are preliminary. Source: Federal Energy Regulatory Commission, FERC Form 423, ‘‘Monthly Report of Cost and Quality of Fuels for Electric Plants.’’
Energy Information Administration/Electric Power Monthly August 2001 167
Table C2. Comparison of Preliminary Versus Final Published Data at the U.S.Level, 1995 Through 1999
Mean Absolute Value of Change Item 1995 1996 1997 1998 1999
NonutilityGeneration (million kilowatthours)
Coal ....................................................................................... NA NA NA NA 2,271Petroleum .............................................................................. NA NA NA NA 1,205Gas ......................................................................................... NA NA NA NA 811Hydroelectric ......................................................................... NA NA NA NA 949Nuclear .................................................................................. NA NA NA NA 28Other ...................................................................................... NA NA NA NA 382Total ...................................................................................... NA NA NA NA 4,425
ConsumptionCoal ....................................................................................... NA NA NA NA 588Petroleum .............................................................................. NA NA NA NA 1,332Gas ......................................................................................... NA NA NA NA 86,386
StocksCoal ....................................................................................... NA NA NA NA 316Petroleum .............................................................................. NA NA NA NA 40
1 Stocks are end of month values.2 Includes public street and highway lighting, other sales to public authorities, sales to railroads and railways, and interdepartmental sales.3 Data represents weighted values.* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.
NA = Not available. Notes: •Change refers to the difference between estimates or preliminary monthly data published in the Electric Power Monthly (EPM) and
the final monthly data published in the EPM. •Mean absolute value of change is the unweighted average of the absolute changes. Sources: •Energy Information Administration: Form EIA-900, ‘‘Monthly NonUtility Power Plant Report’’; Form EIA-759, ‘‘Monthly Power Plant Report’’;
Form EIA-826, ‘‘Monthly Electric Utility Sales and Revenue Report with State Distributions’’; and Form EIA-861, ‘‘Annual Electric Utility Report.’’
Energy Information Administration/Electric Power Monthly August 2001168
Table C3. Unit-of-Measure Equivalents for Electricity
All Sectors.............................................................................. 6.74 6.74 −.10 6.63 6.66 .40
1 Includes geothermal, wood, waste, wind, and solar.2 Stocks are end-of-month values.3 Includes public street and highway lighting, other sales to public authorities, sales to railroads and railways, and interdepartmental sales.4 Data represent weighted values.* = For detailed data, the absolute value is less than 0.5; for percentage calculations, the absolute value is less than 0.05 percent.
NA = Not available. Notes: •The average revenue per kilowatthour is calculated by dividing revenue by sales. •Totals may not equal sum of components because of
independent rounding. •Percent difference is calculated before rounding.Sources: Energy Information Administration, Form EIA-900, ‘‘Nonutility Sales for Resale Report;’’ Form EIA-867, ‘‘Annual Nonutility Power Producer
Report;’’ Form EIA-759, ‘‘Monthly Power Plant Report;’’ Form EIA-861, ‘‘Annual Electric Utility Report;’’ Form EIA-826, ‘‘Monthly Electric Utility Salesand Revenue Report with State Distributions.’’
Energy Information Administration/Electric Power Monthly August 2001170
Energy Information Administration/ Electric Power Monthly August 2001 171
WSCC
MAPP
MAIN
NPCC
SERC
MAAC
SPP
ECAR
FRCC
ERCOTERCOT
ASCC
Figure C1. North American Electric Reliability Council Regions for the Contiguous United States,Alaska and Hawaii
ECAR - East Central Area Reliability Coordination AgreementERCOT - Electric Reliability Council of TexasFRCC - Florida Reliability Coordinating CouncilMAAC - Mid-Atlantic Area CouncilMAIN - Mid-America Interconnected NetworkMAPP - Mid-Continent Area Power PoolNPCC - Northeast Power Coordinating CouncilSERC - Southeastern Electric Reliability CouncilSPP - Southwest Power PoolWSCC - Western Systems Coordinating Council
Note: The Alaska Systems Coordinating Council (ASCC) is an affiliate NERC member.Source: North American Electric Reliability Council.
Table C5. Estimated Coefficients of Variation for Electric Utility Net Generation by State,May 2001(Percent)
State Coal Petroleum Gas Hydroelectric Nuclear Other1
Alabama ......................... NA NA NA NA NA NAAlaska ............................ NA NA NA NA NA NAArizona .......................... NA NA NA NA NA NAArkansas ........................ NA NA NA NA NA NACalifornia ....................... NA NA NA NA NA NAColorado ........................ NA NA NA NA NA NAConnecticut .................... NA NA NA NA NA NADelaware ........................ NA NA NA NA NA NADistrict of Columbia ..... NA NA NA NA NA NAFlorida ............................ NA NA NA NA NA NAGeorgia .......................... NA NA NA NA NA NAHawaii ............................ NA NA NA NA NA NAIdaho .............................. NA NA NA NA NA NAIllinois ............................ NA NA NA NA NA NAIndiana ........................... NA NA NA NA NA NAIowa ............................... NA NA NA NA NA NAKansas ............................ NA NA NA NA NA NAKentucky ........................ NA NA NA NA NA NALouisiana ....................... NA NA NA NA NA NAMaine ............................. NA NA NA NA NA NAMaryland ........................ NA NA NA NA NA NAMassachusetts ................ NA NA NA NA NA NAMichigan ........................ NA NA NA NA NA NAMinnesota ...................... NA NA NA NA NA NAMississippi ..................... NA NA NA NA NA NAMissouri ......................... NA NA NA NA NA NAMontana ......................... NA NA NA NA NA NANebraska ........................ NA NA NA NA NA NANevada ........................... NA NA NA NA NA NANew Hampshire............. NA NA NA NA NA NANew Jersey .................... NA NA NA NA NA NANew Mexico .................. NA NA NA NA NA NANew York ...................... NA NA NA NA NA NANorth Carolina............... NA NA NA NA NA NANorth Dakota ................. NA NA NA NA NA NAOhio ............................... NA NA NA NA NA NAOklahoma ....................... NA NA NA NA NA NAOregon ........................... NA NA NA NA NA NAPennsylvania .................. NA NA NA NA NA NARhode Island.................. NA NA NA NA NA NASouth Carolina............... NA NA NA NA NA NASouth Dakota ................. NA NA NA NA NA NATennessee ....................... NA NA NA NA NA NATexas .............................. NA NA NA NA NA NAUtah ............................... NA NA NA NA NA NAVermont ......................... NA NA NA NA NA NAVirginia .......................... NA NA NA NA NA NAWashington .................... NA NA NA NA NA NAWest Virginia ................ NA NA NA NA NA NAWisconsin ...................... NA NA NA NA NA NAWyoming ....................... NA NA NA NA NA NA
1 Includes geothermal, wood, wind, waste, and solar.NA = Not available.
Notes: •For an explanation of coefficients of variation, see the technical notes. •Estimates for 2000 are preliminary.Source: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001172
Table C6. Estimated Coefficients of Variation for Electric Utility Fuel Consumption and Stocks byState, May 2001(Percent)
Consumption Stocks State Coal Petroleum Gas Coal Petroleum
Alabama .................................. NA NA NA NA NAAlaska ..................................... NA NA NA NA NAArizona .................................... NA NA NA NA NAArkansas .................................. NA NA NA NA NACalifornia ................................ NA NA NA NA NAColorado .................................. NA NA NA NA NAConnecticut ............................. NA NA NA NA NADelaware ................................. NA NA NA NA NADistrict of Columbia............... NA NA NA NA NAFlorida ..................................... NA NA NA NA NAGeorgia .................................... NA NA NA NA NAHawaii ..................................... NA NA NA NA NAIdaho ....................................... NA NA NA NA NAIllinois ..................................... NA NA NA NA NAIndiana ..................................... NA NA NA NA NAIowa ......................................... NA NA NA NA NAKansas ..................................... NA NA NA NA NAKentucky ................................. NA NA NA NA NALouisiana ................................. NA NA NA NA NAMaine ...................................... NA NA NA NA NAMaryland ................................. NA NA NA NA NAMassachusetts ......................... NA NA NA NA NAMichigan ................................. NA NA NA NA NAMinnesota ................................ NA NA NA NA NAMississippi .............................. NA NA NA NA NAMissouri .................................. NA NA NA NA NAMontana .................................. NA NA NA NA NANebraska ................................. NA NA NA NA NANevada .................................... NA NA NA NA NANew Hampshire ...................... NA NA NA NA NANew Jersey.............................. NA NA NA NA NANew Mexico ........................... NA NA NA NA NANew York ............................... NA NA NA NA NANorth Carolina ........................ NA NA NA NA NANorth Dakota .......................... NA NA NA NA NAOhio ......................................... NA NA NA NA NAOklahoma ................................ NA NA NA NA NAOregon ..................................... NA NA NA NA NAPennsylvania ........................... NA NA NA NA NARhode Island ........................... NA NA NA NA NASouth Carolina ........................ NA NA NA NA NASouth Dakota .......................... NA NA NA NA NATennessee ................................ NA NA NA NA NATexas ....................................... NA NA NA NA NAUtah ......................................... NA NA NA NA NAVermont .................................. NA NA NA NA NAVirginia ................................... NA NA NA NA NAWashington ............................. NA NA NA NA NAWest Virginia.......................... NA NA NA NA NAWisconsin ................................ NA NA NA NA NAWyoming ................................. NA NA NA NA NA
NA = Not available. Notes: •For an explanation of coefficients of variation, see the technical notes. •Estimates for 2000 are preliminary.
Source: Energy Information Administration, Form EIA-759, ‘‘Monthly Power Plant Report.’’
Energy Information Administration/Electric Power Monthly August 2001 173
Energy Information Administration/Electric Power Monthly August 2001 175
Glossary
Ampere: The unit of measurement of electrical currentproduced in a circuit by 1 volt acting through aresistance of 1 ohm.
Anthracite: A hard, black lustrous coal, often referred toas hard coal, containing a high percentage of fixedcarbon and a low percentage of volatile matter.Comprises three groups classified according to thefollowing ASTM Specification D388-84, on a drymineral-matter-free basis:
Average Revenue per Kilowatthour: The average reve-nue per kilowatthour of electricity sold by sector(residential, commercial, industrial, or other) and geo-graphic area (State, Census division, and national), iscalculated by dividing the total monthly revenue by thecorresponding total monthly sales for each sector andgeographic area.
Barrel: A volumetric unit of measure for crude oil andpetroleum products equivalent to 42 U.S. gallons.
Baseload: The minimum amount of electric powerdelivered or required over a given period of time at asteady rate.
Baseload Capacity: The generating equipment normallyoperated to serve loads on an around-the-clock basis.
Baseload Plant: A plant, usually housing high-efficiencysteam-electric units, which is normally operated to takeall or part of the minimum load of a system, and whichconsequently produces electricity at an essentially con-stant rate and runs continuously. These units areoperated to maximize system mechanical and thermalefficiency and minimize system operating costs.
Bcf: The abbreviation for 1 billion cubic feet.
Bituminous Coal: The most common coal. It is denseand black (often with well-defined bands of bright and
dull material). Its moisture content usually is less than 20percent. It is used for generating electricity, makingcoke, and space heating. Comprises five groupsclassified according to the following ASTM SpecificationD388-84, on a dry mineral-matter-free (mmf) basis forfixed-carbon and volatile matter and a moist mmf basisfor calorific value.
LV = Low-volatile bituminous coalMV = Medium-volatile bituminous coalHVA = High-volatile A bituminous coalHVB = High-volatile B bituminous coalHVC = High-volatile C bituminous coal
Boiler: A device for generating steam for power, pro-cessing, or heating purposes or for producing hot waterfor heating purposes or hot water supply. Heat from anexternal combustion source is transmitted to a fluidcontained within the tubes in the boiler shell. This fluidis delivered to an end-use at a desired pressure, temper-ature, and quality.
Btu (British Thermal Unit): A standard unit formeasuring the quantity of heat energy equal to thequantity of heat required to raise the temperature of 1pound of water by 1 degree Fahrenheit.
Capability: The maximum load that a generating unit,generating station, or other electrical apparatus cancarry under specified conditions for a given period oftime without exceeding approved limits of temperatureand stress.
Capacity: The full-load continuous rating of a generator,prime mover, or other electric equipment underspecified conditions as designated by the manufacturer.It is usually indicated on a nameplate attached to theequipment.
Energy Information Administration/Electric Power Monthly August 2001176
Capacity (Purchased): The amount of energy andcapacity available for purchase from outside the system.
Census Divisions: The nine geographic divisions of theUnited States established by the Bureau of the Census,U.S. Department of Commerce, for the purpose ofstatistical analysis. The boundaries of Census divisionscoincide with State boundaries. The Pacific Division issubdivided into the Pacific Contiguous and PacificNoncontiguous areas.
Circuit: A conductor or a system of conductors throughwhich electric current flows.
Coal: A black or brownish-black solid combustible sub-stance formed by the partial decomposition of vegetablematter without access to air. The rank of coal, which in-cludes anthracite, bituminous coal, subbituminous coal,and lignite, is based on fixed carbon, volatile matter, andheating value. Coal rank indicates the progressivealteration from lignite to anthracite. Lignite containsapproximately 9 to 17 million Btu per ton. The contentsof subbituminous and bituminous coal range from 16 to24 million Btu per ton and from 19 to 30 million Btu perton, respectively. Anthracite contains approximately 22to 28 million Btu per ton.
Coincidental Demand: The sum of two or moredemands that occur in the same time interval.
Coincidental Peak Load: The sum of two or more peakloads that occur in the same time interval.
Coke (Petroleum): A residue high in carbon content andlow in hydrogen that is the final product of thermaldecomposition in the condensation process in cracking.This product is reported as marketable coke or catalystcoke. The conversion factor is 5 barrels (42 U.S. gallonseach) per short ton.
Combined Pumped-Storage Plant: A pumped-storagehydroelectric power plant that uses both pumped waterand natural streamflow to produce electricity.
Commercial Operation: Commercial operation beginswhen control of the loading of the generator is turnedover to the system dispatcher.
Compressor: A pump or other type of machine using aturbine to compress a gas by reducing the volume.
Consumption (Fuel): The amount of fuel used for grossgeneration, providing standby service, start-up and/orflame stabilization.
Contract Receipts: Purchases based on a negotiatedagreement that generally covers a period of 1 or moreyears.
Cost: The amount paid to acquire resources, such asplant and equipment, fuel, or labor services.
Crude Oil (including Lease Condensate): A mixture ofhydrocarbons that existed in liquid phase inunderground reservoirs and that remains liquid atatmospheric pressure after passing through surfaceseparating facilities. Included are lease condensate andliquid hydrocarbons produced from tar sands, gilsonite,and shale oil. Drip gases are also included, but toppedcrude oil (residual oil) and other unfinished oils areexcluded. Liquids produced at natural gas processingplants and mixed with crude oil are likewise excludedwhere identifiable.
Current (Electric): A flow of electrons in an electricalconductor. The strength or rate of movement of theelectricity is measured in amperes.
Demand (Electric): The rate at which electric energy isdelivered to or by a system, part of a system, or piece ofequipment, at a given instant or averaged over anydesignated period of time.
Demand Interval: The time period during which flow ofelectricity is measured (usually in 15-, 30-, or 60-minuteincrements.)
Electric Plant (Physical): A facility containing primemovers, electric generators, and auxiliary equipment forconverting mechanical, chemical, and/or fission energyinto electric energy.
Electric Utility: An enterprise that is engaged in thegeneration, transmission, or distribution of electricenergy primarily for use by the public and that is themajor power supplier within a designated service area.Electric utilities include investor-owned, publiclyowned, cooperatively owned, and government-owned(municipals, Federal agencies, State projects, and publicpower districts) systems.
Energy: The capacity for doing work as measured by thecapability of doing work (potential energy) or the con-version of this capability to motion (kinetic energy).Energy has several forms, some of which are easilyconvertible and can be changed to another form usefulfor work. Most of the world's convertible energy comesfrom fossil fuels that are burned to produce heat that is
Energy Information Administration/Electric Power Monthly August 2001 177
then used as a transfer medium to mechanical or othermeans in order to accomplish tasks. Electrical energy isusually measured in kilowatthours, while heat energy isusually measured in British thermal units.
Energy Deliveries: Energy generated by one electricutility system and delivered to another system throughone or more transmission lines.
Energy Receipts: Energy generated by one electricutility system and received by another system throughone or more transmission lines.
Energy Source: The primary source that provides thepower that is converted to electricity through chemical,mechanical, or other means. Energy sources includecoal, petroleum and petroleum products, gas, water,uranium, wind, sunlight, geothermal, and other sources.
Fahrenheit: A temperature scale on which the boilingpoint of water is at 212 degrees above zero on the scaleand the freezing point is at 32 degrees above zero atstandard atmospheric pressure.
Failure or Hazard: Any electric power supplyequipment or facility failure or other event that, in thejudgment of the reporting entity, constitutes a hazard tomaintaining the continuity of the bulk electric powersupply system such that a load reduction action maybecome necessary and a reportable outage may occur.The imposition of a special operating procedure, theextended purchase of emergency power, other bulkpower system actions that may be caused by a naturaldisaster, a major equipment failure that would impactthe bulk power supply, and an environmental and/orregulatory action requiring equipment outages are typesof abnormal conditions that should be reported.
Firm Gas: Gas sold on a continuous and generallylong-term contract.
Fossil Fuel: Any naturally occurring organic fuel, suchas petroleum, coal, and natural gas.
Fossil-Fuel Plant: A plant using coal, petroleum, or gasas its source of energy.
Fuel: Any substance that can be burned to produce heat;also, materials that can be fissioned in a chain reaction toproduce heat.
Fuel Emergencies: An emergency that exists when sup-plies of fuels or hydroelectric storage for generation areat a level or estimated to be at a level that wouldthreaten the reliability or adequacy of bulk electricpower supply. The following factors should be taken
into account to determine that a fuel emergency exists:(1) Fuel stock or hydroelectric project water storagelevels are 50 percent or less of normal for that particulartime of the year and a continued downward trend infuel stock or hydroelectric project water storage level areestimated; or (2) Unscheduled dispatch or emergencygeneration is causing an abnormal use of a particularfuel type, such that the future supply or stocks of thatfuel could reach a level which threatens the reliability oradequacy of bulk electric power supply.
Gas: A fuel burned under boilers and by internal com-bustion engines for electric generation. These includenatural, manufactured and waste gas.
Generation (Electricity): The process of producingelectric energy by transforming other forms of energy;also, the amount of electric energy produced, expressedin watthours (Wh).
Gross Generation: The total amount of electric energyproduced by the generating units at a generating stationor stations, measured at the generator terminals.
Net Generation: Gross generation less the electric energyconsumed at the generating station for station use.
Generator: A machine that converts mechanical energyinto electrical energy.
Generator Nameplate Capacity: The full-load con-tinuous rating of a generator, prime mover, or otherelectric power production equipment under specificconditions as designated by the manufacturer. Installedgenerator nameplate rating is usually indicated on anameplate physically attached to the generator.
Geothermal Plant: A plant in which the prime mover isa steam turbine. The turbine is driven either by steamproduced from hot water or by natural steam thatderives its energy from heat found in rocks or fluids atvarious depths beneath the surface of the earth. Theenergy is extracted by drilling and/or pumping.
Gigawatt (GW): One billion watts.
Gigawatthour (GWh): One billion watthours.
Gross Generation: The total amount of electric energyproduced by a generating facility, as measured at thegenerator terminals.
Heavy Oil: The fuel oils remaining after the lighter oilshave been distilled off during the refining process.Except for start-up and flame stabilization, virtually allpetroleum used in steam plants is heavy oil.
Energy Information Administration/Electric Power Monthly August 2001178
Horsepower: A unit for measuring the rate of work (orpower) equivalent to 33,000 foot-pounds per minute or746 watts.
Hydroelectric Plant: A plant in which the turbinegenerators are driven by falling water.
Instantaneous Peak Demand: The maximum demandat the instant of greatest load.
Integrated Demand: The summation of the continuouslyvarying instantaneous demand averaged over aspecified interval of time. The information is usuallydetermined by examining a demand meter.
Internal Combustion Plant: A plant in which the primemover is an internal combustion engine. An internalcombustion engine has one or more cylinders in whichtheprocess of combustion takes place, converting energyreleased from the rapid burning of a fuel-air mixtureinto mechanical energy. Diesel or gas-fired engines arethe principal types used in electric plants. The plant isusually operated during periods of high demand forelectricity.
Interruptible Gas: Gas sold to customers with aprovision that permits curtailment or cessation of serviceat the discretion of the distributing company undercertain circumstances, as specified in the servicecontract.
Kilowatt (kW): One thousand watts.
Kilowatthour (kWh): One thousand watthours.
Light Oil: Lighter fuel oils distilled off during therefining process. Virtually all petroleum used in internalcombustion and gas-turbine engines is light oil.
Lignite: A brownish-black coal of low rank with highinherent moisture and volatile matter (used almost ex-clusively for electric power generation). It is alsoreferred to as brown coal. Comprises two groupsclassified according to the following ASTM SpecificationD388-84 for calorific values on a moistmaterial-matter-free basis:
Limits Btu/lb.
GE LTLignite A 6300 8300Lignite B - 6300
Maximum Demand: The greatest of all demands of theload that has occurred within a specified period of time.
Mcf: One thousand cubic feet.
Megawatt (MW): One million watts.
Megawatthour (MWh): One million watthours.
MMcf: One million cubic feet.
Natural Gas: A naturally occurring mixture of hydro-carbon and nonhydrocarbon gases found in porousgeological formations beneath the earth's surface, oftenin association with petroleum. The principal constituentis methane.
Net Energy for Load: Net generation of main generatingunits that are system-owned or system-operated plusenergy receipts minus energy deliveries.
Net Generation: Gross generation minus plant use fromall electric utility owned plants. The energy required forpumpingat a pumped-storage plant is regarded as plantuse and must be deducted from the gross generation.
Net Summer Capability: The steady hourly output,which generating equipment is expected to supply tosystem load exclusive of auxiliary power, asdemonstrated by tests at the time of summer peakdemand.
Noncoincidental Peak Load: The sum of two or morepeak loads on individual systems that do not occur inthe same time interval. Meaningful only whenconsidering loads within a limited period of time, suchas a day, week, month, a heating or cooling season, andusually for not more than 1 year.
North American Electric Reliability Council (NERC):A council formed in 1968 by the electric utility industryto promote the reliability and adequacy of bulk powersupply in the electric utility systems of North America.The NERC Regions are:
ASCC B Alaskan System Coordination CouncilECAR B East Central Area Reliability CoordinationAgreementERCOT B Electric Reliability Council of TexasFRCC B Florida Reliability Coordinating CouncilMAIN B Mid-America Interconnected NetworkMAAC B Mid-Atlantic Area CouncilMAPP B Mid-Continent Area Power PoolNPCC B Northeast Power Coordinating CouncilSERC B Southeastern Electric Reliability CouncilSPP B Southwest Power PoolWSCC B Western Systems Coordinating Council
Nuclear Fuel: Fissionable materials that have beenenriched to such a composition that, when placed in a
Energy Information Administration/Electric Power Monthly August 2001 179
nuclear reactor, will support a self-sustaining fissionchain reaction, producing heat in a controlled mannerfor process use.
Nuclear Power Plant: A facility in which heat producedin a reactor by the fissioning of nuclear fuel is used todrive a steam turbine.
Off-Peak Gas: Gas that is to be delivered and taken ondemand when demand is not at its peak.
Ohm: The unit of measurement of electrical resistance.The resistance of a circuit in which a potential differenceof 1 volt produces a current of 1 ampere.
Operable Nuclear Unit: A nuclear unit is "operable"after it completes low-power testing and is grantedauthorization to operate at full power. This occurs whenit receives its full power amendment to its operatinglicense from the Nuclear Regulatory Commission.
Other Gas: Includes manufactured gas, coke-oven gas,blast-furnace gas, and refinery gas. Manufactured gasis obtained by distillation of coal, by the thermaldecomposition of oil, or by the reaction of steam passingthrough a bed of heated coal or coke.
Other Generation: Electricity originating from thesesources: biomass, fuel cells, geothermal heat, solarpower, waste, wind, and wood.
Other Unavailable Capability: Net capability of maingenerating units that are unavailable for load for reasonsother than full-forced outrage or scheduledmaintenance. Legal restrictions or other causes makethese units unavailable.
Peak Demand: The maximum load during a specifiedperiod of time.
Peak Load Plant: A plant usually housing old,low-efficiency steam units; gas turbines; diesels; orpumped-storagehydroelectric equipment normally usedduring the peak-load periods.
Peaking Capacity: Capacity of generating equipmentnormally reserved for operation during the hours ofhighest daily, weekly, or seasonal loads. Somegenerating equipment may be operated at certain timesas peaking capacity and at other times to serve loads onan around-the-clock basis.
Percent Difference: The relative change in a quantityover a specified time period. It is calculated as follows:the current value has the previous value subtracted fromit; this new number is divided by the absolute value ofthe previous value; then this new number is multipliedby 100.
Petroleum: A mixture of hydrocarbons existing in theliquid state found in natural underground reservoirs,often associated with gas. Petroleum includes fuel oilNo. 2, No. 4, No. 5, No. 6; topped crude; Kerosene; andjet fuel.
Petroleum Coke: See Coke (Petroleum).
Petroleum (Crude Oil): A naturally occurring, oily,flammable liquid composed principally of hydrocarbons.Crude oil is occasionally found in springs or pools butusually is drilled from wells beneath the earth's surface.
Plant: A facility at which are located prime movers, elec-tric generators, and auxiliary equipment for convertingmechanical, chemical, and/or nuclear energy intoelectric energy. A plant may contain more than one typeof prime mover. Electric utility plants exclude facilitiesthat satisfy the definition of a qualifying facility underthe Public Utility Regulatory Policies Act of 1978.
Plant Use: The electric energy used in the operation ofa plant. Included in this definition is the energyrequired for pumping at pumped-storage plants.
Plant-Use Electricity: The electric energy used in theoperation of a plant. This energy total is subtractedfrom the gross energy production of the plant; forreporting purposes the plant energy production is thenreported as a net figure. The energy required forpumping at pumped-storage plants is, by definition,subtracted, and the energy production for these plantsis then reported as a net figure.
Power: The rate at which energy is transferred.Electrical energy is usually measured in watts. Also usedfor a measurement of capacity.
Price: The amount of money or consideration-in-kind forwhich a service is bought, sold, or offered for sale.
Prime Mover: The motive force that drives an electricgenerator (e.g., steam engine, turbine, or water wheel).
Production (Electric): Act or process of producingelectric energy from other forms of energy; also, theamount of electric energy expressed in watthours (Wh).
Pumped-Storage Hydroelectric Plant: A plant thatusually generates electric energy during peak-loadperiods by using water previously pumped into anelevated storage reservoir during off-peak periods whenexcess generating capacity is available to do so. Whenadditional generating capacity is needed, the water canbe released from the reservoir through a conduit toturbine generators located in a power plant at a lowerlevel.
Energy Information Administration/Electric Power Monthly August 2001180
Pure Pumped-Storage Hydroelectric Plant: A plant thatproduces power only from water that has previouslybeen pumped to an upper reservoir.
Qualifying Facility (QF): This is a cogenerator or smallpower producer that meets certain ownership, operatingand efficiency criteria established by the Federal EnergyRegulatory Commission (FERC) pursuant to the PURPA,and has filed with the FERC for QF status or hasself-certified. For additional information, see the Codeof Federal Regulation, Title 18, Part 292.
Railroad and Railway Electric Service: Electricity sup-plied to railroads and interurban and street railways, forgeneral railroad use, including the propulsion of cars orlocomotives, where such electricity is supplied underseparate and distinct rate schedules.
Receipts: Purchases of fuel.
Reserve Margin (Operating): The amount of unusedavailable capability of an electric power system at peakload for a utility system as a percentage of totalcapability.
Restoration Time: The time when the major portion ofthe interrupted load has been restored and theemergency is considered to be ended. However, some ofthe loads interrupted may not have been restored due tolocal problems.
Restricted-Universe Census: This is the complete enum-eration of data from a specifically defined subset ofentities including, for example, those that exceed a givenlevel of sales or generator nameplate capacity.
Retail: Sales covering electrical energy supplied forresidential, commercial, and industrial end-usepurposes. Other small classes, such as agriculture andstreet lighting, also are included in this category.
Running and Quick-Start Capability: The net capabilityof generating units that carry load or have quick-startcapability. In general, quick-start capability refers togenerating units that can be available for load within a30-minute period.
Sales: The amount of kilowatthours sold in a givenperiod of time; usually grouped by classes of service,such as residential, commercial, industrial, and other.Other sales include public street and highway lighting,other sales to public authorities and railways, andinterdepartmental sales.
Sales for Resale: Energy supplied to other electric utili-ties, cooperatives, municipalities, and Federal and Stateelectric agencies for resale to ultimate consumers.
Scheduled Outage: The shutdown of a generating unit,transmission line, or other facility, for inspection ormaintenance, in accordance with an advance schedule.
Short Ton: A unit of weight equal to 2,000 pounds.
Spot Purchases: A single shipment of fuel or volumes offuel, purchased for delivery within 1 year. Spotpurchases are often made by a user to fulfill a certainportion of energy requirements, to meet unanticipatedenergy needs, or to take advantage of low-fuel prices.
Standby Facility: A facility that supports a utilitysystem and is generally running under no-load. It isavailable to replace or supplement a facility normally inservice.
Standby Service: Support service that is available, asneeded, to supplement a consumer, a utility system, orto another utility if a schedule or an agreementauthorizes the transaction. The service is not regularlyused.
Steam-Electric Plant (Conventional): A plant in whichthe prime mover is a steam turbine. The steam used todrive the turbine is produced in a boiler where fossilfuels are burned.
Stocks: A supply of fuel accumulated for future use.This includes coal and fuel oil stocks at the plant site, incoal cars, tanks, or barges at the plant site, or at separatestorage sites.
Subbituminous Coal: Subbituminous coal, or blacklignite, is dull black and generally contains 20 to 30percent moisture. The heat content of subbituminouscoal ranges from 16 to 24 million Btu per ton as receivedand averages about 18 million Btu per ton.Subbituminous coal, mined in the western coal fields, isused for generating electricity and space heating.
Substation: Facility equipment that switches, changes,or regulates electric voltage.
Sulfur: One of the elements present in varying quantitiesin coal which contributes to environmental degradationwhen coal is burned. In terms of sulfur content byweight, coal is generally classified as low (less than orequal to 1 percent), medium (greater than 1 percent and
Energy Information Administration/Electric Power Monthly August 2001 181
less than or equal to 3 percent), and high (greater than 3percent). Sulfur content is measured as a percent byweight of coal on an "as received" or a "dry"(moisture-free, usually part of a laboratory analysis)basis.
Switching Station: Facility equipment used to tietogether two or more electric circuits through switches.The switches are selectively arranged to permit a circuitto be disconnected, or to change the electric connectionbetween the circuits.
System (Electric): Physically connected generation,transmission, and distribution facilities operated as anintegrated unit under one central management, oroperating supervision.
Transformer: An electrical device for changing thevoltage of alternating current.
Transmission: The movement or transfer of electricenergy over an interconnected group of lines andassociated equipment between points of supply andpoints at which it is transformed for delivery to con-sumers, or is delivered to other electric systems. Trans-mission is considered to end when the energy istransformed for distribution to the consumer.
Transmission System (Electric): An interconnectedgroup of electric transmission lines and associated
equipment for moving or transferring electric energy inbulk between points of supply and points at which it istransformed for delivery over the distribution systemlines to consumers, or is delivered to other electricsystems.
Turbine: A machine for generating rotary mechanicalpower from the energy of a stream of fluid (such aswater, steam, or hot gas). Turbines convert the kineticenergy of fluids to mechanical energy through theprinciples of impulse and reaction, or a mixture of thetwo.
Watt: The electrical unit of power. The rate of energytransfer equivalent to 1 ampere flowing under apressure of 1 volt at unity power factor.
Watthour (Wh): An electrical energy unit of measureequal to 1 watt of power supplied to, or taken from, anelectric circuit steadily for 1 hour.
Wheeling Service: The movement of electricity fromonesystem to another over transmission facilities ofinter-vening systems. Wheeling service contracts can beestablished between two or more systems.
Year to Date: The cumulative sum of each month's valuestarting with January and ending with the current monthof the data.