1

F861 Datafile YR 2009

This file contains information pertaining to the column headings for the files deployed from f861yr09.exe, 

when unzipped. This file layout also contains other useful information on the fields and data presented. 

The file names are File1.xls, File1_cao.xls, File1a.xls, File2.xls, File3.xls, File3a.xls, File4.xls, File5.xls 

File6.xls, File7.xls, and File8.xls.

The file F861yr09.exe is a file of data collected on the Form EIA-861, Annual Electric Power Industry 

Report, for the reporting period, calendar year 2009. The zipped .exe file contains 11 .xls files and one 

Word file. The data file structure detailed here also applies to data files for prior years. Years prior to 2007

do not include File1a, File3a, File7 and File8. Executable (and zip) files for years prior to 2004 do not 

contain file6 (distributed generation data). Executable (and zip) files for 2001 do not contain file 5 (green 

pricing, net metering data). Data for years prior to 2001 are described in the applicable file layout 

documentation.

 File1 contains aggregate operational data such as control area operators (years prior to 2005), 

energy balance, and revenue information from each electric utility in the country, including power 

marketers, and Federal power marketing administrations. 

 File1_cao contains (2005 forward) data on control area operators.

 File1_a (2007 forward) contains data on the types of activities each utility engages in, the NERC 

regions of operation, whether the utility generates power, and if it operates alternative-fueled 

vehicles

 File2 contains information on retail revenue, sales, and customer counts, by State and class of 

service (including the Transportation sector, new in 2003), for each electric distribution utility, or 

energy service provider in all 50 States, the District of Columbia, the Dominion of Puerto Rico, 

and the Territories of American Samoa, Guam, and the Virgin Islands.

 File3 contains information on electric utility demand-side management programs, including 

energy efficiency and load management effects and expenditures, and (2007 forward) the number 

of customers in time- and incentive-based rate programs (peak data is in megawatts for 2001

forward – in previous years the data are in kilowatts).

 File3a (2007 forward) contains the cost percentages by state of energy efficiency and load 

management programs. 

 File4 contains the names of the counties, by State, in which the respondent has equipment for the 

distribution of electricity to ultimate consumers.

 File5 contains aggregate data of the number of customers by State and customer class for Green 

Pricing and Net Metering programs, as well as (for 2007 forward) the revenue and sales from 

Green Pricing programs and the energy displaced by Net Metering programs.

 File6 contains information on utility or customer-owned distributed and dispersed generation such 

as the number, capacity and types of generators.

 File7 (2007 forward) contains data on mergers and acquisitions

 File8 (2007 forward) contains data on advanced meters. 

Note: All sales, energy efficiency energy savings, and load management energy savings data are in 

megawatthours. Summer and winter system peak and peak reduction data (actual and potential) in 

File 3 are in megawatts for 2001 forward and kilowatts for previous years, all revenue and 

expenditure data are in thousand-dollar units. 

File1

Column Headings

COL A: YEAR Year of Data

COL B: UTIL_ID ID number of utility (reporting entity)

COL C: UTILITY_NAME Name of Utility

COL D: MAIL_STATE State in which the utility (entity) is located 
2

COL E: OWNERSHIP Ownership Type: One of 10 different types of 

ownership categories: Federal; Political 

Subdivision; Municipal Marketing Authority; 

Cooperative; State; Municipal; InvestorOwned; Retail Power Marketer (Energy Service

Provider); (Wholesale) Power Marketer; 

Transmission Company. “State” ownership 

refers to statewide organizations whose scope is 

larger than county level.

COL F: NERC_LOCATION NERC Location: The North American Electric 

Reliability Corporation (NERC) region where 

the utility has its primary business operations 

(service territory), electrical generation, 

transmission, and distribution equipment, and 

its administrative headquarters. Some utilities 

have business operations and service areas in 

more than one NERC region. Power marketers, 

because they generally have only office 

equipment, can have business operations in any 

NERC region. FRCC = Florida Reliability 

Coordinating Council; MRO = Midwest 

Reliability Organization; NPCC = Northeast 

Power Coordinating Council; RFC = Reliability 

First Corporation (formerly MAAC, MAIN and 

ECAR); SERC = SERC Reliability 

Corporation; SPP = Southwest Power Pool, RE; 

TRE = Texas Regional Entity (formerly 

ERCOT); WECC = Western Electric 

Coordinating Council. AK = Alaska; AS = 

American Samoa; GU = Guam; HI = Hawaii; 

PR = Puerto Rico; VI = Virgin Islands.

 COL G: PEAK_DEMAND_SUMMER Summer Peak Demand: The one hour during 

the months of June, July, August or September 

when the utility sold the most power, including 

full and partial requirements wholesale 

consumers. Peak data is in megawatts (2000 

and previous years in kilowatts).

COL H: PEAK_DEMAND_WINTER Winter Peak Demand: The one hour during the 

months of December (prior), January, February, 

March (current year) when the utility sold the 

most power, including full and partial 

requirements wholesale consumers. Peak data 

is in megawatts (2000 and previous years in 

kilowatts).

COL I: NET_GENERATION Net Generation: Gross generation minus plant 

use from all electric utility owned plants.

Energy data is in megawatthours.

COL J: WHOLESALE_PURCHASES Wholesale Power Purchases (in 

megawatthours): Energy purchased and 

supplied to other electric utilities, cooperatives, 

municipals, and Federal and state electric 

agencies for resale to ultimate consumers.

COL K: EXCHANGED_RECEIVED Exchange Energy Received (in 

megawatthours): Specific energy transactions 
3

between electric utilities, where electricity 

received is returned in kind at a later time or 

accumulated as energy balances until the end of 

the stated period, after which settlement may be 

by monetary payment. This is the portion of 

energy reported as received.

COL L: EXCHANGED_DELIVERED Exchange Energy Delivered (in 

megawatthours): Specific energy transactions 

between electric utilities, where electricity 

received is returned in kind at a later time or 

accumulated as energy balances until the end of 

the stated period, after which settlement may be 

by monetary payment. This is the portion of 

energy reported as delivered.

COL M: EXCHANGED_NET Net Power Exchanged (in megawatthours): 

Specific energy transactions between electric 

utilities, where electricity received is returned 

in kind at a later time or accumulated as energy 

balances until the end of the stated period, after 

which settlement may be by monetary payment. 

This is the Net difference between the energy 

reported as received and delivered.

COL N: WHEELED__RECEIVED Wheeled Power Received (in megawatthours): 

The reported volume of electricity received, 

transmitted over an electric utility’s system for 

compensation, which the electric utility 

received from one system and delivered to 

another system.

COL O: WHEELED_ DELIVERED Wheeled Power Delivered (in megawatthours): 

The reported volume of electricity delivered, 

transmitted over an electric utility’s system for 

compensation, which the electric utility 

received from one system and delivered to 

another system.

COL P: WHEELED_NET Net Wheeled Power (in megawatthours): The 

reported net volume of electricity transmitted 

over an electric utility’s system for 

compensation, which the electric utility 

received from one system and delivered to 

another system.

COL Q: TRANSMISSION_BY_OTHERS_LOSSES Transmission By Others Losses (in 

megawatthours): The amount of energy losses 

associated with the wheeling of electricity 

provided to the respondent’s system by other 

utilities. This should always be expressed as a 

negative value.

COL R: TOTAL_SOURCES Total Sources (in megawatthours): The sum of 

all sources of energy (Sum of columns I 

through P).

COL S: RETAIL_SALES Retail Sales (in megawatthours): Sales to 

ultimate consumers. The amount of electricity 

sold to customers purchasing electricity for 

their own use and not for resale.

COL T: SALES_FOR_RESALE Sales For Resale (in megawatthours): 
4

Wholesale sales. The amount of electricity sold 

for resale purposes. This includes sales for 

resale to power marketers, full and partial 

requirements customers, firm power customers 

and nonfirm customers, and sales through 

tolling agreements.

COL U: FURNISHED_WITHOUT_CHARGE Furnished Without Charge (in megawatthours): 

The amount of electricity furnished by the 

electric utility without charge, such as a 

municipality under a franchise agreement or for 

public street and highway lighting. This entry 

does not include data entered in Column V, 

Consumed_By_Respondent

COL V: CONSUMED_BY_RESPONDENT Consumed By Respondent without charge (in 

megawatthours): The amount of electricity 

furnished by the electric utility without charge, 

such as to a municipality under a franchise 

agreement or for public street and highway 

lighting. This entry does not include data 

entered in Column U, 

Furnished_Without_Charge

COL W: TOTAL_LOSSES Total Energy Losses (in megawatthours): The 

total amount of electricity lost from 

transmission, distribution, and/or unaccounted 

for (sum of columns S through V). This must 

be a positive number.

COL X: TOTAL_DISPOSITION Total Disposition (in megawatthours): The total 

amount of electricity disposed (The difference 

between Column R “TOTAL_SOURCES” and 

the sum of columns S through W).

COL Y: RETAIL_REVENUES Electric Operating Revenue from Sales to 

Ultimate Customers, Schedule 4, Parts A and B 

(in thousand dollars): The amount of revenue 

from sales of electricity to those customers 

purchasing electricity for their own use and not 

for resale.

COL Z: UNBUNDLED_REVENUES Revenue from Unbundled (Delivery) 

Customers, Schedule 4, part C (in thousand 

dollars): The amount of revenue from 

unbundled customers who purchase their 

energy from a supplier other than the electric 

utility that distributes the power to their 

premises. This electric operating revenue does 

not include the charges for electric energy but 

does include the revenue required to cover 

power delivery.

COL AA: RESALE_REVENUES Electric Operating Revenue from Sales for 

Resale (in thousand dollars): The amount of 

revenue from sales of electricity sold for resale 

purposes. This includes revenue from sales for 

resale to wholesale or retail power marketers, 

full and partial requirements customers (firm) 

and to nonrequirements (nonfirm) customers. 
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COL AB: REVENUE_CREDITS_AND_ADJUSTMENT Electric Credits/Other Adjustments (in 

thousand dollars): Funds included in this entry 

consist of refunds to customers resulting from 

rate commission rulings delayed beyond the 

reporting year in which the funds were 

originally collected. This also includes revenue 

distributions to customers from rate 

stabilizations funds where the distribution 

occurred during the current reporting year but 

the funds were collected during the previous 

reporting years.

COL AC: OTHER_REVENUES Other Electric Operating Revenue (in thousand 

dollars): The amount of revenue received from 

electric activities other than selling electricity. 

This may include revenue from selling or 

servicing electric appliances, revenue from the 

sale of water and water power for irrigation, 

domestic, industrial or hydroelectric operations, 

revenue from electric plants leased to others, 

revenue from the transmission of electricity to 

others (wheeling), revenue from the sale of 

steam, but not including sales made by a steam 

heating department or transfers of steam under 

joint facility operations, revenue from 

interdepartmental rents or sale of electric 

property, revenue from late fees, penalties or 

reconnections, and revenue from interest.

COL AD: TOTAL_REVENUES Total Electric Operating Revenues (in thousand 

dollars): The sum of columns Y through AC. 

COL AE: DATA_TYPE O=observed; I=imputed

File1_CAO

Column Headings:

COL A: YEAR Data Year

COL B: UTILITY_ID Utility ID Number

COL C: CONTROL_AREA_OPERATOR_CODE ID Code of Control Area Operator

COL D: CONTROL_AREA_OPERATOR_NAME Entity Name of Control Area Operator.

The entity (usually electric utility) responsible for 

the application of a common, automatic generation 

and transmission control scheme within a specific 
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electrically bordered area. Control Area Operators 

balance demand with available capacity, maintain 

system frequency and voltage within strict 

parameters and control power flows into, and out of, 

the region. A utility may have major electrical 

generation, transmission and distribution equipment 

in more than one control area.

File1a (2007 forward)

Column Headings

COL A: YEAR Year of Data

COL B: UTIL_ID ID number of utility (reporting entity)

COL C: UTILITY_NAME Name of Utility

COL D: MAIL_STATE State in which the utility (entity) is located 

COL E: OWNERSHIP Ownership Type: One of 10 different types of 

ownership categories: F=Federal; P=Political 

Subdivision; A=Municipal Marketing 

Authority; C=Cooperative; State; 

M=Municipal; I=Investor-Owned; R=Retail 

Power Marketer (Energy Service Provider); 

W=(Wholesale) Power Marketer; 

T=Transmission Company. S=State 

(ownership refers to statewide organizations 

whose scope is larger than county level).

COL F: NERC_LOCATION NERC Location: The North American Electric 

Reliability Corporation (NERC) region where 

the utility has its primary business operations 

(service territory), electrical generation, 

transmission, and distribution equipment, and 

its administrative headquarters. Some utilities 

have business operations and service areas in 

more than one NERC region. Power marketers, 

because they generally have only office 

equipment, can have business operations in any 

NERC region. FRCC = Florida Reliability 

Coordinating Council; MRO = Midwest 

Reliability Organization; NPCC = Northeast 

Power Coordinating Council; RFC = Reliability 

First Corporation (formerly MAAC, MAIN and 

ECAR); SERC = SERC Reliability 

Corporation; SPP = Southwest Power Pool, RE; 

TRE = Texas Regional Entity (formerly 

ERCOT); WECC = Western Electric 

Coordinating Council. AK = Alaska; AS = 

American Samoa; GU = Guam; HI = Hawaii; 

PR = Puerto Rico; VI = Virgin Islands.

COL G: NERC_ERCOT Entity conducts business operations within the 

TRE region (TRE=Texas Regional Entity 

(formerly ERCOT) (Y or N)

COL H: NERC_FRCC Entity conducts business operations within the 

FRCC region (Y or N)

COL I: NERC_MRO Entity conducts business operations within the 

MRO region (Y or N)
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COL J: NERC_NPCC Entity conducts business operations within the 

NPCC region (Y or N)

COL K: NERC_RFC Entity conducts business operations within the 

RFC region (Y or N)

COL L: NERC_SERC Entity conducts business operations within the 

SERC region (Y or N)

COL M: NERC_SPP Entity conducts business operations within the 

SPP region (Y or N)

COL N: NERC_WECC Entity conducts business operations within the 

WECC region (Y or N)

COL O: OPERATES_GENERATING_PLANT Entity operates power generating plants (Y or 

N)

COL P: ACTIVITY_GENERATION Entity engages in power generation activity (Y 

or N)

COL Q: ACTIVITY_TRANSMISSION Entity engages in power transmission activity 

(Y or N)

COL R: ACTIVITY_BUYING_TRANSMISSION Entity buys transmission service (Y or N)

COL S: ACTIVITY_DISTRIBUTION Entity engages in power distribution activity (Y 

or N)

COL T: ACTIVITY_BUYING_DISTRIBUTION Entity buys distribution service (Y or N)

COL U: ACTIVITY_WHOLESALE_MARKETING Entity engages in wholesale power marketing 

(Y or N)

COL V: ACTIVITY_RETAIL_MARKETING Entity engages in retail power marketing (Y or 

N)

COL W: ACTIVITY_BUNDLED_SERVICES Entity provides bundled services (Y or N)

COL X: ALT_FUEL_VEHICLE Entity operated alternative-fueled vehicles 

during the year (Y or N) 

COL Y: ALT_FUEL_VEHICLE2 Entity plans to operate alternative-fueled 

vehicles next year (Y or N)

File2

Column Headings

COL A: YEAR Year of Data

COL B: UTIL_ID ID number of utility (reporting entity) “99999” is not a 

utility ID; it represents an adjustment factor.

COL C: UTILITY_NAME Name of Utility

COL D: SCHED4PART A=Bundled Service, B=Energy Only Service, 

C=Delivery Only Service, D=TX Energy Service 

Providers

COL E: SERVICE_TYPE Provider Type. Designates electric service types as either 

Bundled (reported on Schedule 4 Part A or D), Energy 

(reported on Schedule 4 Part B) or Delivery (reported on 

Schedule 4 Part C). Total revenue nationally includes all 
8

components.

COL F: DATA_TYPE O=observed, I=imputed

 COL G: STATE_CODE 2-digit State Code; also includes US Territories: AS = 

American Samoa; GU = Guam; PR = Puerto Rico; VI = 

Virgin Islands.

COL H: OWNERSHIP Ownership Type: One of 10 different types of ownership 

categories: Federal; Political Subdivision; Municipal 

Marketing Authority; Cooperative; State; Municipal; 

Investor-Owned; Retail Power Marketer (Energy Service 

Provider); (Wholesale) Power Marketer; and 

Unregulated. “State” ownership refers to statewide 

organizations whose scope is larger than county level.

COL I: RESIDENTIAL_REVENUES Revenues from residential customers (in thousands of 

dollars). Residential revenue is the billed amount. 

COL J: RESIDENTIAL_SALES Electricity sales to residential customers (in 

megawatthours). Residential sales is the billed amount. 

COL K: RESIDENTIAL_CONSUMERS Number of residential consumers (meters, or customer 

accounts). Note: Each residential customer in an 

aggregated account (as for a residential buying 

cooperative) should be counted as a separate customer, if 

metered separately.

COL L: COMMERCIAL_REVENUES Revenues from commercial customers (in thousands of 

dollars). Commercial revenue is the billed amount 

including demand revenue. 

COL M: COMMERCIAL_SALES Electricity sales to commercial customers (in 

megawatthours). 

COL N: COMMERCIAL_CONSUMERS Number of commercial consumers (meters, or customer 

accounts). Note: Each location in an aggregated account 

(as all restaurants in a chain) should be counted as a 

separate customer, if metered separately.

COL O: INDUSTRIAL_REVENUES Revenues from industrial customers (in thousands of 

dollars. Industrial revenue is the billed amount including 

demand revenue, reactive demand charges (if 

applicable), high-voltage discounts (if applicable), etc. 

COL P: INDUSTRIAL_SALES Electricity sales to industrial customers (in 

megawatthours) 

COL Q: INDUSTRIAL_CONSUMERS Number of industrial consumers (meters, or customer 

accounts). Note: Each facility is counted as one 

customer even if power is taken and metered at more 

than one point.

COL R: TRANSPORTATION_REVENUES Transportation revenue. Beginning with the 2003 data 

cycle this sector replaces “Other” (thousand dollars). 

Revenues for the sales of power to electrified rail and 

urban transit systems whose primary propulsive energy 

source is electricity.

COL S: TRANSPORTATION_SALES Transportation sales. Beginning with the 2003 data cycle 

this sector replaces “Other” (megawatthours). Sales of 

power to electrified rail and urban transit systems whose 

primary propulsive energy source is electricity.

COL T: TRANSPORTATION_CONSUMERS Transportation consumers. Beginning with the 2003 data 

cycle this sector replaces “Other”. Customer counts for 

the sales of power to electrified rail and urban transit 

systems whose primary propulsive energy source is 

electricity.
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COL U: TOTAL_REVENUES Total revenues of all sectors

COL V: TOTAL_SALES Total electricity consumed by all sectors

(megawatthours)

COL W: TOTAL_CONSUMERS Total number of consumers in all sectors

File3

Contains information on electric utility Demand-Side Management (DSM) program information, including 

Energy Efficiency and Load Management Effects and Expenditures. Peak data is in megawatts for the 

periods 2001 through 2008. In previous years the data are in kilowatts. Energy savings are in 

megawatthours, actual and potential peak reductions are in megawatts, and expenditures are in thousanddollar units.

Demand –Side Management Actual Effects are split into two categories across each sector type: 

Incremental Effects and Annual Effects. The sectors are Residential, Commercial, Industrial, and 

Transportation (formerly “Other”, 2002 and prior years.) Data elements for each are as follows: Energy 

Efficiency, comprised of Energy Effects (in megawatthours); and Actual Peak Reduction (in megawatts).

Load Management, comprised of Energy Effects (in megawatthours); Potential Peak Reduction (in 

megawatts); and Actual Peak Reduction (in megawatts).

Incremental Effects: The annual effects in energy use (measured in megawatthours) and peak load 

(measured in megawatts) caused by new participants in existing DSM programs and all participants in new 

DSM programs during a given year. Reported incremental effects should be annualized to indicate the 

program effects that would have occurred had these participants been initiated into the program on January 

1 of the given year. Incremental effects are not simply the Annual Effects of a given year minus the 

Annual Effects of the prior year, since these net effects would fail to account for program attrition, 

degradation, demolition, and participant dropouts.

Annual Effects: The total effects in energy use (measured in megawatthours) and peak load (measured in 

megawatts) caused by all participants in the DSM programs that are in effect during a given year. It 

includes new and existing participants in existing programs (those implemented in prior years that are in 

place during the given year) and all participants in new programs (those implemented during the given 

year). The effects of new participants in existing programs and all participants in new programs should be 

based on their start-up dates (i.e., if participants enter a program in July, only the effects from July to 

December should be reported). If start-up dates are unknown and cannot be reasonably estimated, the 

effects can be annualized (i.e., assume the participants were initiated into the program on January 1 of the 

given year). The Annual Effects should consider the useful life of efficiency measures, by accounting for 

building demolition, equipment degradation and attrition.

Energy Efficiency: Refers to programs that are aimed at reducing the energy used by specific end-use 

devices and systems, typically without affecting the services provided. These programs reduce overall 

electricity consumption, often without explicit consideration for the timing of program-induced savings. 

Such savings are generally achieved by substituting technically more advanced equipment to produce the 

same level of end-use services using less electricity. Examples include high-efficiency appliances, efficient 

lighting programs, high efficiency heating, ventilating and air conditioning (HVAC) systems or control 

modifications, efficient building design, advanced electric motor drives, and heat recovery systems.
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Energy Effects: The changes in aggregate electricity use (measured in megawatthous) for 

customers that participate in a utility DSM program. Energy Effects should represent changes at 

the consumer meter (i.e. exclude transmission and distribution effects) and reflect only activities 

that are undertaken specifically in response to utility-administered programs, including those 

activities implemented by third parties under contract to the utility. To the extent possible, Energy 

Effects should exclude non-program related effects such as changes in energy usage attributable to 

nonparticipants, government-mandated energy-efficiency standards that legislate improvements in 

building and appliance energy usage, changes in consumer behavior that result in greater energy 

use after initiation in a DSM program, the natural operations of the marketplace, and weather and 

business-cycle adjustments.

Actual Peak Load Reduction: The actual reduction in annual peak load (measured in megawatts) 

achieved by consumers that participate in a utility DSM program. It reflects the real changes in 

the demand for electricity resulting from a utility DSM program that is in effect at the same time 

the utility experiences its annual peak load, as opposed to the installed peak load reduction 

capability (i.e., Potential Peak Load Reduction). It should account for the regular cycling of energy 

efficient units during the period of annual peak load.

Load Management: Refers to program activities that can interrupt consumer load at the time of annual 

peak load by direct control of the utility system operator by interrupting power supply to individual 

appliances or equipment on consumer premises. This type of control usually involves residential 

consumers. 

Energy Effects: The changes in aggregate electricity use (measured in megawatthous) for 

customers that participate in a utility Load Management program. Energy Effects should represent 

changes at the consumer meter (i.e. exclude transmission and distribution effects) and reflect only 

activities that are undertaken specifically in response to utility-administered programs, including 

those activities implemented by third parties under contract to the utility. To the extent possible, 

Energy Effects should exclude non-program related effects such as changes in energy usage 

attributable to nonparticipants, government-mandated energy-efficiency standards that legislate 

improvements in building and appliance energy usage, changes in consumer behavior that result in 

greater energy use after initiation in a Load Management program, the natural operations of the 

marketplace, and weather and business-cycle adjustments.

Potential Peak Reduction: The amount of peak load reduction capability (measured in 

megawatts) that can be deployed from Direct Load Control, Interruptible Load, Other Load 

Management, and other DSM Program activities. It represents the load that can be reduced either 

by the direct control of the utility system operator or by the consumer in response to a utility 

request to curtail load. It reflects the installed load reduction capability, as opposed to the Actual 

Peak Reduction achieved by participants, during the time of annual system peak load.

Actual Peak Reduction: The actual reduction in annual peak load (measured in megawatts) 

achieved by consumers that participate in a utility DSM program. It reflects the real changes in 

demand for electricity resulting from a utility DSM program that is in effect at the same time the 

utility experiences its annual peak load, as opposed to the installed peak load reduction capability 

(i.e., Potential Peak Load Reduction). 

Direct Costs, excluding incentive payments - Energy Efficiency: The cost for implementing energy 

efficiency programs (in thousand dollars) incurred by the utility. 
11

Direct Costs, excluding incentive payments – Load Management: The cost for implementing load 

management programs (in thousand dollars) incurred by the utility. 

Incentive Payment Energy Efficiency: Payment by the utility to the customer (in thousand dollars) for 

energy efficiency incentives. Examples of incentives are zero or low-interest loans, rebates, and direct 

installation of low cost measures, such as water heater wraps or duct work.

Incentive Payment Load Management: Payment by the utility to the customer (in thousand dollars) for 

load management incentives. 

Indirect Cost: A utility cost that may not be meaningfully identified with any particular DSM program 

category. Indirect costs could be attributable to one of several accounting cost categories (i.e., 

Administrative, Marketing, Monitoring & Evaluation, Utility-Earned Incentives, Other). Accounting costs 

that are known DSM program costs should not be reported under Indirect Utility Cost, rather those costs 

should be reported as Direct Utility Costs under the appropriate DSM program category.

Total Cost: The sum of the total Direct and Indirect Utility Costs for the year. Utility costs should reflect 

the total cash expenditures for the year, reported in nominal dollars, that flowed out to support DSM 

programs. They should be reported in the year they are incurred, regardless of when the actual effects 

occur.

Column Headings

COL A: YEAR Year of Data

COL B: UTIL_ID ID number of utility (reporting entity)

COL C: UTILITY_NAME Name of Utility

COL D: OWNERSHIP Ownership Type: One of 8 different types of ownership 

categories: Federal; Political Subdivision; Municipal 

Marketing Authority; Cooperative; State; Municipal; 

Investor-Owned; Retail Power Marketer (Energy Service 

Provider). “State” ownership refers to statewide organizations 

whose scope is larger than county level.

COL E: NERC_LOCATION NERC Location: The North American Electric Reliability 

Corporation (NERC) region where the utility has its primary

business operations (service territory), electrical generation, 

transmission, and distribution equipment, and its 

administrative headquarters. Some utilities have business 

operations and service areas in more than one NERC region. 

Power marketers, because they generally have only office 

equipment, can have business operations in any NERC 

region. FRCC = Florida Reliability Coordinating Council; 

MRO = Midwest Reliability Organization; NPCC = 

Northeast Power Coordinating Council; RFC = Reliability 

First Corporation (formerly MAAC, MAIN and ECAR); 

SERC = SERC Reliability Corporation; SPP = Southwest 

Power Pool, RE; TRE = Texas Regional Entity (formerly 

ERCOT); WECC = Western Electric Coordinating Council. 

AK = Alaska; AS = American Samoa; GU = Guam; HI = 

Hawaii; PR = Puerto Rico; VI = Virgin Islands.

COL F: RETAIL_SALES Sales to retail (ultimate) consumers (megawatthours)
12

 COL G: SALES_FOR_RESALE Sales for Resale (wholesale) (megawatthours)

COL H: ENERGYEFFINCRES Residential Incremental Energy Efficiency Energy Effects

(megawatthours).

COL I: ENERGYEFFINCCOMM Commercial Incremental Energy Efficiency Energy Effects

(megawatthours).

COL J: ENERGYEFFINCIND Industrial Incremental Energy Efficiency Energy Effects

(megawatthours).

COL K: ENERGYEFFINCOTH Transportation Incremental Energy Efficiency Energy Effects

(megawatthours).

COL L: ENERGYEFFANNRES Residential Annual Energy Efficiency Energy Effects

(megawatthours).

COL M: ENERGYEFFANNCOM Commercial Annual Energy Efficiency Energy Effects

(megawatthours).

COL N: ENERGYEFFANNIND Industrial Annual Energy Efficiency Energy Effects

(megawatthours).

COL O: ENERGYEFFANNOTH Transportation Annual Energy Efficiency Energy Effects

(megawatthours).

COL P: EEFACTUALPEAKINCRES Residential Incremental Energy Efficiency Actual Peak 

Reduction (megawatts).

COL Q: EEFACTUALPEAKINCCOM Commercial Incremental Energy Efficiency Actual Peak 

Reduction (megawatts).

COL R: EEFACTUALPEAKINCIND Industrial Incremental Energy Efficiency Actual Peak 

Reduction (megawatts).

COL S: EEFACTUALPEAKINCOTH Transportation Incremental Energy Efficiency Actual Peak 

Reduction (megawatts).

COL T: EEFACTUALPEAKANNRES Residential Annual Energy Efficiency Actual Peak Reduction

(megawatts).

COL U: EEFACTUALPEAKANNCOM Commercial Annual Energy Efficiency Actual Peak 

Reduction (megawatts).

COL V: EEFACTUALPEAKANNIND Industrial Annual Energy Efficiency Actual Peak Reduction

(megawatts).

COL W: EEFACTUALPEAKANNOTH Transportation Annual Energy Efficiency Actual Peak 

Reduction (megawatts).

COL X: LOADMNGEFFINCRES Residential Incremental Load Management Energy Effects

(megawatthours).

COL Y: LOADMNGEFFINCCOM Commercial Incremental Load Management Energy Effects

(megawatthours).

COL Z: LOADMNGEFFINCCIND Industrial Incremental Load Management Energy Effects

(megawatthours).

COL AA: LOADMNGEFFINCOTH Transportation Incremental Load Management Energy 

Effects (megawatthours).

COL AB: LOADMNGEFFANNRES Residential Annual Load Management Energy Effects 

(megawatthours).

COL AC: LOADMNGEFFANNCOM Commercial Annual Load Management Energy Effects

(megawatthours).

COL AD: LOADMNGEFFANNIND Industrial Annual Load Management Energy Effects

(megawatthours).

COL AE: LOADMNGEFFANNOTH Transportation Annual Load Management Energy Effects

(megawatthours).

COL AF:

LMPOTENTPEAKREDINCRES

Residential Incremental Load Management Potential Peak 

Reduction (megawatts).

COL AG:

LMPOTENTPEAKREDINCCOM

Commercial Incremental Load Management Potential Peak 

Reduction (megawatts).
13

COL AH:

LMPOTENTPEAKREDINCIND

Industrial Incremental Load Management Potential Peak 

Reduction (megawatts).

COL AI:

LMPOTENTPEAKREDINCOTH

Transportation Incremental Load Management Potential Peak 

Reduction (megawatts).

COL AJ:

LMPOTENTPEAKREDANNRES

Residential Annual Load Management Potential Peak 

Reduction (megawatts).

COL AK:

LMPOTENTPEAKREDANNCOM

Commercial Annual Load Management Potential Peak 

Reduction (megawatts).

COL AL:

LMPOTENTPEAKREDANNIND

Industrial Annual Load Management Potential Peak 

Reduction (megawatts).

COL AM:

LMPOTENTPEAKREDINCOTH

Transportation Annual Load Management Potential Peak 

Reduction (megawatts).

COL AN:

LMACTUALPEAKREDINCRES

Residential Incremental Load Management Actual Peak 

Reduction (megawatts).

COL AO:

LMACTUALPEAKREDINCCOM

Commercial Incremental Load Management Actual Peak 

Reduction (megawatts).

COL AP:

LMACTUALPEAKREDINCIND

Industrial Incremental Load Management Actual Peak 

Reduction (megawatts).

COL AQ:

LMACTUALPEAKREDINCOTH

Transportation Incremental Load Management Actual 

Peak Reduction (megawatts).

COL AR:

LMACTUALPEAKREDANNRES

Residential Annual Load Management Actual Peak 

Reduction (megawatts).

COL AS:

LMACTUALPEAKREDANNCOM

Commercial Annual Load Management Actual Peak 

Reduction (megawatts).

COL AT:

LMACTUALPEAKREDANNIND

Industrial Annual Load Management Actual Peak Reduction

(megawatts).

COL AU:

LMACTUALPEAKREDANNOTH

Transportation Annual Load Management Actual Peak 

Reduction (megawatts).

COL AV: DIRECTCOSTEEF Annual Energy Efficiency Cost (in thousands of dollars).

COL AW: INCENTIVEEEF Annual Incentive Payment Energy Efficiency (in thousands 

of dollars).

COL AX: DIRECTCOSTLM Annual Load Management Cost (in thousands of dollars).

COL AY: INCENTIVELM Annual Incentive Payment Load Management (in thousands 

of dollars).

COL AZ: INDIRECTCOST Annual Indirect Utility Cost (in thousands of dollars).

COL BA: TOTALCOST Annual Total Utility Cost (in thousands of dollars).

COL BB: 

DEMAND_SIDE_MANAGEMENT

Entity has a company-administered DSM program (Y or N)

COL BC: 

REPORTED_AS_OTHER_COMP

Entity’s DSM activities are reported on Schedule 6 of another 

entity’s form EIA-861 (Y or N) 

COL BD: INDEPENDENT_VERIFY Entity’s energy savings are verified through an independent 

evaluation (Y or N)

COL BE: MAJOR_CHANGES Entity’s DSM programs have undergone major changes (Y or 

N)

COL BF: PRICERESPONSIVE Entity operates incentive-based DSM programs (Y or N)

COL BG: PRICERESPRES Number of residential consumers (meters, or customer 

accounts) in incentive-based DSM programs. Note: Each 

residential customer in an aggregated account (as for a 

residential buying cooperative) should be counted as a 

separate customer, if metered separately.

COL BH: PRICERESPCOM Number of commercial consumers (meters, or customer

accounts) in incentive-based DSM programs. Note: Each 

location in an aggregated account (as all restaurants in a 

chain) should be counted as a separate customer, if metered 

separately.
14

COL BI: PRICERESPIND Number of industrial consumers (meters, or customer 

accounts) in incentive-based DSM programs. Note: Each 

facility is counted as one customer even if power is taken and 

metered at more than one point.

COL BJ: PRICERESPOTH Number of transportation consumers in incentive-based DSM 

programs. Customer counts for the sales of power to

electrified rail and urban transit systems whose primary 

propulsive energy source is electricity.

COL BK: TIMERESPONSIVE Entity operates time-based DSM programs (Y or N)

COL BL: TIMERESPRES Number of residential consumers (meters, or customer 

accounts) in time-based DSM programs. Note: Each 

residential customer in an aggregated account (as for a 

residential buying cooperative) should be counted as a 

separate customer, if metered separately.

COL BM: TIMERESPCOM Number of commercial consumers (meters, or customer 

accounts) in time-based DSM programs. Note: Each location 

in an aggregated account (as all restaurants in a chain) should 

be counted as a separate customer, if metered separately.

COL BN: TIMERESPIND Number of industrial consumers (meters, or customer 

accounts) in time-based DSM programs. Note: Each facility 

is counted as one customer even if power is taken and 

metered at more than one point.

COL BO: TIMERESPTRANS Number of transportation consumers in time-based DSM 

programs. Customer counts for the sales of power to

electrified rail and urban transit systems whose primary 

propulsive energy source is electricity.

File3A

Contains the breakdown of costs by state for energy efficiency and load management programs (2008 

forward).

Column Headings:

COL A: YEAR Data Year

COL B: UTILITY_ID Utility ID Number

COL C: UTILITY_NAME Utility Name

COL D: OWNERSHIP Ownership Type: One of 10 different types of 

ownership categories: F=Federal; P=Political 

Subdivision; A=Municipal Marketing Authority; 

C=Cooperative; State; M=Municipal; I=InvestorOwned; R=Retail Power Marketer (Energy Service 

Provider); W=(Wholesale) Power Marketer; 

T=Transmission Company. S=State (ownership 

refers to statewide organizations whose scope is 

larger than county level).

COL E: STATE State in which the entity is operating a DemandSide Management (DSM) program

COL F: DIRECCOSTEEF State percentage share of Annual Direct Costs for 

Energy Efficiency

COL G: DIRECTCOSTLM State percentage share of Annual Direct Costs for 

Load Management

COL H: INCENTIVEEEF State percentage share of Annual Incentive 
15

Payments for Energy Efficiency

COL I: INCENTIVELM State percentage share of Annual Incentive 

Payments for Load Management

COL J: INDIRECTCOST State percentage share of Annual Indirect Utility 

Cost

COL K: TOTALCOST State percentage share of Annual Total Utility Cost

File4

Contains the names of the counties (parishes) in which the distribution utility has equipment for the 

distribution of electric energy to retail consumers.

Column Headings:

COL A: YEAR Data Year

COL B: UTILITY_ID Utility ID Number

COL C: UTILITY_NAME Utility Name

COL D: STATE State in which the utility (entity) is located 2-digit 

State Code. Also includes US Territories: AS = 

American Samoa; GU = Guam; PR = Puerto Rico; 

VI = Virgin Islands.

COL E: COUNTY County (or Parish) in which the utility (entity) is 

located

File5

The first worksheet contains green pricing data, and the second worksheet contains net metering data. 

Green Pricing Green Pricing programs allow customers to 

purchase power generated from renewable resources 

and to pay for renewable energy development

Column Headings

COL A: YEAR Data Year

COL B: UTILITY_ID Utility ID Number

COL C: UTILITY_NAME Utility Name

COL D: STATE State in which the utility (entity) is located

COL E: GREEN_CUST_RESIDENTIAL Number of Green Pricing Residential Consumers

COL F: GREEN_CUST_COMMERCIAL Number of Green Pricing Commercial Consumers

COL G: GREEN_CUST_INDUSTRIAL Number of Green Pricing Industrial Consumers

COL H: GREEN_CUST_TRANS Number of Green Pricing Transportation 

Consumers

COL I: GREEN_CUST_TOTAL Total number of Green Pricing Consumers

COL J: GREEN_REVENUES_RESIDENTIAL Revenue from green pricing programs (in thousand 

dollars) from residential customers

COL K: GREEN_REVENUES_COMMERCIAL Revenue from green pricing programs (in thousand 

dollars) from commercial customers
16

COL L: GREEN_REVENUES_INDUSTRIAL Revenue from green pricing programs (in thousand 

dollars) from industrial customers

COL M: GREEN_REVENUES_TRANS Revenue from green pricing programs (in thousand 

dollars) from transportation customers

COL N: GREEN_REVENUES_TOTAL Total revenue from green pricing programs

COL O: GREEN_SALES_RESIDENTIAL Electricity sales (in MWh) to residential customers 

in green pricing programs

COL P: GREEN_SALES_COMMERCIAL Electricity sales (in MWh) to commercial customers 

in green pricing programs

COL Q: GREEN_SALES_INDUSTRIAL Electricity sales (in MWh) to industrial customers in 

green pricing programs

COL R: GREEN_SALES_TRANS Electricity sales (in MWh) to transportation 

customers in green pricing programs

COL S: GREEN_SALES_TOTAL Electricity sales (in MWh) to all customers in green 

pricing programs

Net Metering Net Metering programs allow customers to sell 

excess power they generate back to the electrical 

grid to offset consumption. 

Column Headings

COL A: YEAR Data Year

COL B: UTILITY_ID Utility ID Number

COL C: UTILITY_NAME Utility Name

COL D: STATE State in which the utility (entity) is located

COL E: NET_METERING_CUST_RESIDENTIAL Number of Net Metering Residential Consumers

COL F:

NET_METERING_CUST_COMMERCIAL

Number of Net Metering Commercial Consumers

COL G: NET_METERING_CUST_INDUSTRIAL Number of Net Metering Industrial Consumers

COL H: NET_METERING_CUST_ TRANS Number of Net Metering Transportation Consumers

COL I: NET_METERING_CUST_TOTAL Total number of Net Metering Consumers

COL J: NET_METERING_DISP_RESIDENTIAL Energy displaced (MWh) by Residential Net 

Metering Customers

COL K: NET_METERING_DISP_COMMERCIAL Energy displaced (MWh) by Commercial Net 

Metering Customers

COL L: NET_METERING_DISP_INDUSTRIAL Energy displaced (MWh) by Industrial Net 

Metering Customers

COL M: NET_METERING_DISP_TRANS Energy displaced (MWh) by Transportation Net 

Metering Customers

COL N: NET_METERING_DISP_TOTAL Total energy displaced (MWh) by Net Metering 

Customers

File6

The first worksheet presents information on distributed generation (grid-connected) for companies that 

own or operate a distribution system. The second worksheet presents dispersed generation information

(NOT grid-connected) for companies that own or operate a distribution system. 
17

Distributed Generation Distributed generation (grid-connected)

for companies that own or operate a distribution system.

Distributed generators could be utility-owned or 

customer-owned. Data include number of generators, 

number of generators less than one megawatt, total 

aggregate capacity, percent of aggregate capacity used 

only for backup, and percent of capacity by technology 

type. Respondents specify whether data are actual or 

estimated.

Column Headings

COL A: YEAR Year of Data

COL B: UTIL_ID ID number of utility (reporting entity)

COL C: UTILITY_NAME Name of Utility

COL D: DISTNUMGEN Total number of distributed generators

COL E: DISTNUMGENLMW Number of distributed generators < 1 MW (megawatts)

COL F: DISTTOTALCAP Total capacity of all distributed generators (megawatts)

 COL G: DISTTOTALCAPLMW Capacity of distributed generators < 1 MW (megawatts)

COL H: DISTPERCBACKUP Percentage of backup distributed generators

COL I: DISTDATATYPE1 Data Type 1. A=actual, E=estimated

COL J: DISTINTERNAL Percent capacity of distributed internal combustion/

reciprocating engines

COL K: DISTCOMBTURB Percent capacity of distributed combustion turbine 

generators

COL L: DISTSTEAMTURB Percent capacity of distributed steam turbine generators

COL M: DISTHYDROELEC Percent capacity of distributed hydroelectric generators

COL N: DISTWINDTURB Percent capacity of distributed wind turbine generators

COL O: DISTOTHERTURN Percent capacity of distributed other generators

COL P: DISTDATATYPE2 Data Type 2. A=actual, E=estimated

COL Q: DISTSTATE State in which the generators are located

COL R: DISTPERCOWNED Percent of distributed generator capacity owned by 

respondent

Dispersed Generation Dispersed generation (NOT grid-connected) for 

companies that own or operate a distribution system. 

Dispersed generators could be utility-owned or customerowned. Data include number of generators, number of 

generators less than one megawatt, total aggregate 

capacity, percent of aggregate capacity used only for 

backup, and percent of capacity by technology type. 

Respondents specify whether data are actual or estimated.

Column Headings

COL A: YEAR Year of Data

COL B: UTIL_ID ID number of utility (reporting entity)

COL C: UTILITY_NAME Name of Utility

COL D: DISPNUMGEN Total number of dispersed generators

COL E: DISPNUMGENLMW Number of dispersed generators < 1MW (megawatts)

COL F: DISPTOTALCAP Total capacity of all dispersed generators (megawatts)
18

 COL G: DISPTOTALCAPLMW Capacity of dispersed generators < 1MW (megawatts)

COL H: DISPPERCBACKUP Percentage of backup dispersed generators

COL I: DISPDATATYPE1 Data Type 1. A=actual, E=estimated

COL J: DISPINTERNAL Percent capacity of dispersed internal combustion/

reciprocating engines

COL K: DISPCOMBTURB Percent capacity of dispersed combustion turbine 

generators

COL L: DISPSTEAMTURB Percent capacity of dispersed steam turbine generators

COL M: DISPHYDROELEC Percent capacity of dispersed hydroelectric generators

COL N: DISPWINDTURB Percent capacity of dispersed wind turbine generators

COL O: DISPOTHERTURN Percent capacity of dispersed other generators

COL P: DISPDATATYPE2 Data Type 2. A=actual, E=estimated

COL Q: DISPSTATE State in which the generators are located

COL R: DISPERCOWNED Percent of dispersed generator capacity owned by

respondent

File7

File7 (2007 forward) contains data on mergers and acquisitions

Column Headings

COL A: YEAR Year of Data

COL B: UTILITY_ID ID number of utility (reporting entity)

COL C: UTILITY_NAME Name of Utility

COL D: MAIL_STATE State in which the utility (entity) is located 

COL E: OWNERSHIP Ownership Type: One of 10 different types of ownership 

categories: F=Federal; P=Political Subdivision; 

A=Municipal Marketing Authority; C=Cooperative; 

State; M=Municipal; I=Investor-Owned; R=Retail Power 

Marketer (Energy Service Provider); W=(Wholesale) 

Power Marketer; T=Transmission Company. S=State 

(ownership refers to statewide organizations whose 

scope is larger than county level).

COL F: MERGERDATE Date of merger or acquisition

 COL G: MERGERCOMPANY Company the entity has merged with or acquired

COL H: NEWPARENT Name of new parent company

COL I: MERGERADDRESS New address

COL J: MERGERCITY New city

COL K: MERGERSTATE New state

COL L: MERGERZIP5 New 5-digit zip code

COL M: MERGERZIP4 New 4-digit zip code adder

File8

File8 (2007 forward) contains data on advanced meters. 
19

Column Headings

COL A: YEAR Year of Data

COL B: UTILITY_ID ID number of utility (reporting entity)

COL C: UTILITY_NAME Name of Utility

COL D: OWNERSHIP Ownership Type: One of 10 different types of ownership 

categories: F=Federal; P=Political Subdivision; 

A=Municipal Marketing Authority; C=Cooperative; 

State; M=Municipal; I=Investor-Owned; R=Retail Power 

Marketer (Energy Service Provider); W=(Wholesale) 

Power Marketer; T=Transmission Company. S=State 

(ownership refers to statewide organizations whose 

scope is larger than county level).

COL E: STATE_CODE State in which customers with advanced meters are 

located

COL F: AMR_METERING_RESIDENTIAL Number of AMR meters serving residential customers

 COL G: AMR_METERING_COMMERCIAL Number of AMR meters serving commercial customers

COL H: AMR_METERING_INDUSTRIAL Number of AMR meters serving industrial customers

COL I: AMR_METERING_TRANS Number of AMR meters serving transportation 

customers

COL J: AMR_METERING_TOTAL Total number of AMR meters 

COL K: AMI_METERING_RESIDENTIAL Number of AMI meters serving residential customers

COL L: AMI_METERING_COMMERCIAL Number of AMI meters serving commercial customers

COL M: AMI_METERING_INDUSTRIAL Number of AMI meters serving industrial customers

COL N: AMI_METERING_TRANS Number of AMI meters serving transportation customers

COL O: AMI_METERING_TOTAL Total number of AMI meters 

COL P: ENERGY_SERVED_RESIDENTIAL Energy served through residential AMI meters (MWh)

COL Q: ENERGY_SERVED_COMMERCIAL Energy served through commercial AMI meters (MWh)

COL R: ENERGY_SERVED_INDUSTRIAL Energy served through industrial AMI meters (MWh)

COL S: ENERGY_SERVED_TRANS Energy served through transportation AMI meters 

(MWh)

COL T: ENERGY_SERVED_TOTAL Total energy served through AMI meters (MWh)