1

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

PURPOSE Form EIA-861 collects information on the status of electric power industry participants involved 

in the generation, transmission, and distribution of electric energy in the United States, its 

territories, and Puerto Rico. The data from this form are used to accurately maintain the EIA list 

of electric utilities, to draw samples for other electric power surveys, and to provide input for the 

following EIA reports: Electric Power Monthly, Monthly Energy Review, Electric Power Annual, 

Annual Energy Outlook, and Annual Energy Review. The data collected on this form are used 

to monitor the current status and trends of the electric power industry and to evaluate the future 

of the industry.

REQUIRED 

RESPONDENTS 

The Form EIA-861 is to be completed by electric industry distributors including: electric utilities, 

wholesale power marketers (registered with the Federal Energy Regulatory Commission), 

energy service providers (registered with the States), and electric power producers. Responses 

are collected at the business level (not at the holding company level).

RESPONSE DUE 

DATE 

Submit the completed Form EIA-861 to the EIA by April 30, following the end of the calendar 

year. 

METHODS OF 

FILING RESPONSE

Submit your data electronically using EIA’s secure internet data collection system (e-file). This 

system uses security protocols to protect information against unauthorized access during 

transmission. 

 If you have not registered with EIA’s Single Sign-On system, send an e-mail requesting 

assistance to: EIA-861@eia.doe.gov. 

 If you have registered with Single Sign-On, log on at 

https://signon.eia.doe.gov/ssoserver/login

 If you are having a technical problem with logging into e-file or using e-file contact the 

Help Desk for further information. Contact the Help Desk at: 

E-Mail: CNEAFhelpcenter@eia.doe.gov

Phone: 202-586-9595 

 If you need an alternate means of filing your response, contact the Help Desk. 

Please retain a completed copy of this form for your files. 

CONTACTS Internet System Questions: For questions related to e-file, see the help contact information 

immediately above. 

Data Questions: For questions about the data requested on Form EIA-861, contact the Survey 

Manager: 

Karen McDaniel Stephen Scott 

 (202) 586-4280 (202) 586-5140 

FAX Number: (202) 287-1938 

E-mail: EIA-861@eia.doe.gov 
2

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

GENERAL 

INSTRUCTIONS 

Submit the completed Form EIA-861 to the EIA by April 30, following the end of the 

calendar year.

1. Respondents, who also submit the Form EIA-826, “Monthly Electric Sales and Revenue 

Report with State Distributions," should coordinate the information submitted on the Form 

EIA-861, and Form EIA-826 to ensure consistency. 

2. Complete the information at the top portion of the form with the name, telephone and FAX 

number, and e-mail address, of the current contact person, and the contact person’s 

supervisor. 

3. Report peak demand in megawatts and energy values (e.g., generation and sales) in 

megawatthours, except where noted. One megawatthour equals 1,000 kilowatthours. To 

convert kilowatthours to megawatthours, divide by 1,000 and round to the nearest whole 

number. For example, sales of 5,245,790 kilowatthours should be reported as 5,246 

megawatthours. 

4. Report in whole numbers (i.e., no decimal points), except where explicitly instructed to 

report otherwise. For example: revenue of $8,459,688.42 should be reported as 8,460 

(thousand dollars). Revenue on Schedules 2C, 3 and 4 has one decimal place as well as 

lines 4, 6 and 7 on Schedule 6A. 

5. For number of customers, enter the average of the 12 close-of-month customer accounts. 

 All respondents having end-use customers, including retail power marketers selling 

power in deregulated, competitive State programs must use the average of the 12 

close-of-month customer counts when reporting on Schedule 4, even if your 

company began business after the beginning of the reporting year, or ended 

business before the close of the year. 

 Count each meter as a separate customer in cases where commercial franchise, or 

residential customer-buying groups have been aggregated under one buyer 

representative. The customer counts for public-street and highway lighting should 

be one customer per community. 

 Please do not count each pole as a separate customer even if billing is by a flat 

rate per pole per month. 

6. Use a minus sign for reporting negative numbers. There are only four lines where a 

negative number can be entered: Schedule 2B lines 1 & 9 and Schedule 3 lines 4 & 5. 

7. Where exact data are unavailable, report estimated data. 

8. See the Glossary for terms used in this survey. The financial and accounting terms are 

consistent as outlined in the Uniform System of Accounts for Public Utilities and 

Licensees (U.S. of A.) (18 CFR Part 101). 

ITEM-BY-ITEM 

INSTRUCTIONS 

SCHEDULE 1. IDENTIFICATION 

1. Survey Contact: Verify contact name, title, address, telephone number, fax number, and 

e-mail address. 

2. Supervisor of Contact Person for Survey: Verify the contact’s supervisor’s name, title, 

address, telephone number, Fax number and e-mail address. Supervisor contact must 

be different than the survey contact.

3. Report For: Verify all information, including entity name, entity identification number, and 

reporting year for which data are being reported. These fields cannot be revised online. 

Contact EIA if corrections are needed. 

If any of the above information is incorrect, revise the incorrect entry and provide the correct 
3

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

information. Provide any missing information. 

Entity and Preparer Information 

4. Legal Name of Entity: Enter the legal name of the entity for which this form is being 

prepared. 

5. Current Address of Entity’s Principal Business Office: Enter the complete address, 

excluding the legal name, of the entity’s principal business office (i.e., headquarters, main 

office, etc.). 

6. Preparer’s Legal Name: Enter the legal name of the company, which prepares this form, if 

different from the Legal Name of Entity. 

7. Current Address of Preparer’s Office: Enter the address to which this form should be 

mailed, if different from the Current Address of Entity’s Principal Business Office. 

Include an attention line, room number, building designation, etc. to facilitate the future 

handling and processing of the Form EIA-861. 

SCHEDULE 2, PART A. GENERAL INFORMATION 

1. For line 1, please check all of the Regional Councils within the North American Electric 

Reliability Corporation (NERC), in which your organization conducts operations. 

The Regional Councils are: 

 

 TRE.................... Texas Regional Entity 

 FRCC ................. Florida Reliability Coordinating Council 

 MRO................... Midwest Reliability Organization 

 NPCC................. Northeast Power Coordinating Council 

 RFC................. ReliabilityFirst Corporation 

 SERC................. Southeastern Electric Reliability Council 

 SPP.................... Southwest Power Pool 

 WECC ................ Western Electric Coordinating Council 

2. For line 3, Control Area Operator(s), control area operator(s) responsible for your 

oversight will be already entered, from the previous year. To switch control area operators, 

use the drop down menu to make a selection (double click in the field); if your choice is not 

on the list, please select “Other” and enter your control area operator name in the footnotes 

(Schedule 9). 

3. For line 4, Operate Generating Plant(s), Check Yes to indicate that organization operated 

a generating plant(s) during the reporting period. Otherwise, Check No. 

4. For line 5, Activities, Check the appropriate activities the electric entity was engaged in 

during the reporting year. You must check at least one.

Generation from company owned plant. Owned power generation only. 

Transmission. Owned or leased transmission lines. 

Buying transmission services on other electrical systems. Types of services include 

borderline customers, transmission line rental, transmission capacity, transmission 

wheeling, and system operational services. 

Distribution using owned/leased electrical wires. Power delivery to your own end-use 

customers over distribution facilities. 

Buying distribution on other electrical systems. Types of support include customer 

billing, distribution system support charges for energy delivered, line maintenance, and/or 

equipment charges. 

Wholesale power marketing. Wholesale transactions with other electric utilities, 

purchases from power producers, and transactions to export and/or import electricity to, or 
4

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

from, Canada or Mexico. Also includes electrical sales and purchases among Federal 

Energy Regulatory Commission registered power marketers and similar participation in 

transactions with electric utilities. 

Retail power marketing. Provision of electrical energy to end-use customers in areas 

where the customer has been given the legal right to select a power supplier other than 

the “traditional electric utility.” 

Bundled services. Provision of electricity in combination with gas, water, cable, Internet, 

and/or telephone for a single price.

5. For line 6, Highest Hourly Electrical Peak System Demand, electric utility companies 

should enter the maximum hourly summer load (for months of June through September) 

based on net energy for the system during the reporting year. Net energy for the system is 

the sum of energy an electric utility needs to satisfy their service area and includes full and 

partial wholesale requirements customers, and the losses experienced in delivery. The 

maximum hourly load is determined by the interval in which the 60-minute integrated 

demand is the greatest. If such data are unavailable, adjust available data to approximate 

a 60-minute demand interval and explain the adjustment on Schedule 9, Footnotes. If 

adjustments cannot be made, furnish data as available and explain on Schedule 9, 

Footnotes. For winter enter the maximum hourly winter load (for months of January 

through March, and the previous December) based on the net energy for the system during 

the reporting year. Please note: These data elements should be provided in megawatts, to 

the nearest tenth. 

6. For line 7, Alternative Fueled Vehicles, Check Yes to indicate that your company 

owns/operates, or plans to own and operate, alternative fueled vehicles; otherwise Check 

No. If “Yes,” provide the name, title, FAX number, telephone number and e-mail address of 

a contact person. Note: For the purpose of this question, an “alternative-fueled vehicle” is 

either designed or manufactured by an original equipment manufacturer or is a converted 

vehicle designed to operate in either dual-fuel, flexible-fuel, or dedicated modes on fuels 

other than gasoline or diesel. This does not include a conventional vehicle that is limited to 

operation on blended or reformulated gasoline fuels. 

SCHEDULE 2, PART B. ENERGY SOURCES AND DISPOSITION 

1. Enter the annual megawatthours (MWh) for all sources of energy and disposition of energy 

listed. 

2. For line 1, Net Generation, enter the net generation (gross generation minus station use) 

from all respondent-owned plants. If a plant is jointly owned, enter only the reporting 

party’s share of generation. Include generation used to replace system losses arising from 

wheeling transactions. Include net generation supplied as part of a tolling arrangement. 

3. For line 2, Purchases from Electricity Suppliers, enter the total amount of energy 

purchased from electricity suppliers including: nonutility power producers and power 

marketers (reported separately in previous years), municipal departments and power 

agencies, cooperatives, investor-owned utilities, political subdivisions, State agencies and 

power pools, and marketing agencies of the United States Government and Canada; these 

agencies include Bonneville Power Administration (BPA), Southeastern Power 

Administration (SEPA), Southwestern Power Administration (SWPA), Western Area Power 

Administration (WAPA), Tennessee Valley Authority (TVA), United States Army Corps of 

Engineers, the United States Bureau of Reclamation, United States Bureau of Indian 

Affairs, International Boundary and Water Commission, Hydro-Quebec, etc. This entry 

includes requirements power, firm power and all other non-firm service. Note: Please 

identify on Schedule 9, Footnotes, the portion of purchased power obtained through tolling 

arrangements, and any international purchases. 

4. For line 3, Exchanges Received (In), enter the amount of exchange energy received. Do 

not include power received through tolling arrangements. 

5. For line 4, Exchanges Delivered (Out), enter the amount of exchange energy delivered. 

Do not include power delivered as part of a tolling arrangement. 
5

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

 

6. For line 5, Exchanges (Net), enter the net amount of energy exchanged. Net exchange is 

the difference between the amount of exchange received and the amount of exchange 

delivered (lines 3-4). This entry should not include wholesale energy purchased from or 

sold to regulated companies or unregulated companies for other systems. 

7. For line 6, Wheeled Received (In), enter the total amount of energy entering your system 

from other systems for transmission through your system (wheeling) for delivery to other 

systems. Do not report as Wheeled Received, energy purchased or exchanged for 

consumption within your system, which was wheeled to you by others. 

8. For line 7, Wheeled Delivered (Out), enter the total amount of energy leaving your system 

that was transmitted through your system for delivery to other systems. If Wheeling 

Delivered is not precisely known, please estimate based on your system's known 

percentage of losses for wheeling transactions. 

9. For line 8, Wheeled (Net), enter the difference between the amount of energy entering 

your system for transmission through your system and the amount of energy leaving your 

system (line 6 minus line 7). Wheeled net represents the energy losses on your system 

associated with the wheeling of energy for other systems. 

10. For line 9, Transmission by Others, Losses, enter the amount of energy losses 

associated with the wheeling of electricity provided to your system by other utilities. 

Transmission by Others Losses should always be expressed as a negative value. 

11. For line 11, Sales to Ultimate Customers, enter the amount of electricity sold to 

customers purchasing electricity for their own use and not for resale. This entry should 

correspond to the revenue from sales to ultimate customers reported on Schedule 3, line 

1, and should be equal to the total megawatthours reported on Schedule 4, Parts A, and 

B, column e, when summed for all reported States. This entry should include all unbilled 

megawatthours sold during the reporting period. 

12. For line 12, Sales for Resale, enter the amount of electricity sold for resale purposes. 

This entry should include sales for resale to power marketers (reported separately in 

previous years), full and partial requirements customers, firm power customers and 

nonfirm customers. This entry should also correspond to the revenue from sales for 

resale reported in Schedule 3, line 3. Note: Please identify on Schedule 9, Footnotes, 

the portion of sales for resale power sold through tolling arrangements, and any 

international sales. 

13. For line 13, Energy Furnished Without Charge, enter 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 line 

14. 

14. For line 14, Energy Consumed by Respondent Without Charge, enter the amount of 

electricity used by the electric utility in its electric and other departments without charge. 

This entry does not include data entered in line 13. 

15. For line 15, Total Energy Losses, enter the total amount of electricity lost from 

transmission, distribution, and/or unaccounted for. This is the difference between line 10, 

"Total Sources," and the sum of lines 11, 12, 13, and 14. Total Energy Losses should 

always be expressed as a positive value. 
6

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

SCHEDULE 2, PART C. GREEN PRICING 

Green Pricing programs allow electricity customers the opportunity to purchase electricity 

generated from renewable resources. Renewable resources include solar, wind, 

geothermal, hydroelectric power, and wood. Revenue should be reported in thousands of 

dollars to the nearest tenth (for example, revenue of $6,586,887.82 should be reported as 

6586.9). Revenue should include revenue from the green pricing program plus the price 

of the electricity purchased. 

 

Example: For 1000 kWh of electricity sales, if the normal price for electricity is $0.10 per 

kWh: 

a) An Entity sells Green Energy for $5.50 per 100 kWh block: 

 Total cost = (1000kWh x $0.10/kWh) + ($5.50/100kWh block)(10-100 kWh 

blocks) 

 = $100.00 + $55.00 

 = $155.00 

b) An Entity sells Green Energy for an additional $0.02 per kWh: 

Total cost = (1000kWh x $0.10/kWh) + ($0.02/kWh)(1000kWh) 

 = $100.00 + $20.00 

 = $120.00 

For Green pricing sales (MWh), report the total amount of megawatthours purchased by 

customers in each green pricing customer class. The sales volumes and the number of 

customers should not exceed the values reported in Schedule 4, Parts A, B, or D. 

Complete all three lines for Schedule 2 Part C.

SCHEDULE 2, PART D. NET METERING 

Net Metering tariff arrangements permit a facility, typically generating electricity from a 

renewable resource, (using a meter that reads inflows and outflows of electricity) to sell 

any excess power it generates over its load requirement back to the electrical grid, 

typically at a rate equivalent to the retail price of electricity, to offset consumption. For Net 

Metering megawatthours, enter the amount of energy not served to the customer class as 

a result of customers’ power generation (the energy produced by the net metered 

generating facility). This energy may be metered at the customer’s meter, or estimated by 

the utility. For energy estimation purposes for photovoltaic facilities, please refer to PV 

Watts http://www.pvwatts.org/. The number of net metering customers should not exceed 

the values in Schedule 4 Parts A and C. Complete both lines for Schedule 2 Part D. 

Please provide the amount of net metered capacity in kW by technology (i.e. PV, 

wind, small hydro, etc.) in Schedule 9. 

SCHEDULE 3. ELECTRIC OPERATING REVENUE 

1. All electric operating revenue data should be rounded to the nearest tenth and reported in 

thousand dollars (for example, revenue of $8,461,688.42 should be reported as 8,461.7 

(thousand dollars). 

2. For line 1, Electric Operating Revenue from Sales to Ultimate Customers, enter the 

amount of revenue from sales of electricity to those customers purchasing electricity for 

their own use and not for resale. Revenue reported on Schedule 4, Part C, for delivery 

service (and all other charges) should not be reported on Schedule 3, line 1, but should 

be reported in Schedule 3, line 2, Revenue from Unbundled (Delivery) Customers. This 

entry is gross revenue and includes the revenue from State and local income taxes, 

energy or demand charges, customer service charges, environmental surcharges, 

franchise fees, fuel adjustments and other miscellaneous charges applied to end-use 

customers during normal billing operations. This entry should not include deferred 

charges, credits, or other adjustments, such as fuel or revenue from purchased power, 

from previous reporting periods which are included in Schedule 3, line 4, Electric Credits/ 
7

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

Other Adjustments. This entry should correspond to electricity sales reported in 

Schedule 2, Part B, line 11. (This entry should also be the same total revenue reported on 

Schedule 4, column e, Parts A and B, when summed for all reported States). This entry 

should include all unbilled revenue resulting from power sold during the reporting period. 

 

3. For line 2, Revenue from Unbundled (Delivery) Customers, enter the amount of 

revenue from unbundled customers who purchase their electricity from a supplier other 

than the electric utility that distributes 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. 

4. For line 3, Electric Operating Revenue from Sales for Resale, enter the amount of 

revenue from sales of electricity sold for resale purposes. This entry should include 

revenue from sales for resale to wholesale or retail power marketers, full and partial 

requirements customers (firm) and to nonrequirements (nonfirm) customers. This entry 

should also correspond to the sales for resale reported in Schedule 2, Part B, line 12. 

5. For line 4, Electric Credits/Other Adjustments, enter the amount of deferred revenue, 

which corresponds to Account 449.1 of the Uniform System of Accounts including revenue 

not applied to end-use or resale customers during the normal billing cycle. 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. Also, 

include revenue distributions to customers from rate stabilization funds where the 

distribution occurred during the current reporting year but the funds were collected during 

previous reporting years. 

6. For line 5, Other Electric Operating Revenue, enter 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 for 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. 

SCHEDULE 4. PART A. SALES TO ULTIMATE CUSTOMERS. 

FULL SERVICE – ENERGY AND DELIVERY SERVICE (BUNDLED) 

 

Please note that data for the Transportation Sector (see definitions) has replaced the 

“Other” Sector on all parts of Schedule 4. Non-Transportation customers previously 

reported under “Other,” including street and highway lighting, should now be 

included in the Commercial Sector. Irrigation customers should be reported in the 

Industrial Sector. 

 

Enter the reporting year revenue (thousand dollars, to the nearest tenth), megawatthours, 

and number of customers for sales of electricity to ultimate customers by State and customer 

class category for whom your company provides both energy and delivery service. Power 

marketers providing both energy and delivery service should report on Part D. Note: For 

sales to customer groups using brokers or aggregators, continue to count each customer 

separately. For instance, count a group of franchised commercial establishments aggregated 

through a single broker as separate customers (as reported in prior years). Enter the 2-letter 

U.S. Postal Service abbreviation for the State in which the electric sales occurred. 

SCHEDULE 4. PART B. SALES TO ULTIMATE CUSTOMERS. 

ENERGY – ONLY SERVICE (WITHOUT DELIVERY SERVICE) 

Enter the reporting year revenue (thousand dollars, to the nearest tenth), megawatthours, 

and number of customers for sales of electricity to ultimate customers by State and customer 

class category for whom your company provides only the energy consumed, where another 
8

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

electric utility provides delivery services, including, for example, billing, administrative 

support, and line maintenance. 

SCHEDULE 4. PART C. SALES TO ULTIMATE CUSTOMERS. 

DELIVERY – ONLY SERVICE (AND ALL OTHER CHARGES) 

 Enter the reporting year revenue (thousand dollars, to the nearest tenth), megawatthours 

delivered, and number of customers for sales of electricity to ultimate customers in your 

service territory by State and customer class category for whom your company provides only 

billing and related energy delivery services, where another company supplies the energy. 

SCHEDULE 4. PART D. SALES TO ULTIMATE CUSTOMERS. BUNDLED SERVICE BY 

RETAIL ENERGY PROVIDERS, OR ANY POWER MARKETER THAT PROVIDES 

“BUNDLED SERVICE” 

Enter the reporting period revenue (thousand dollars, to the nearest tenth), megawatthours, 

and number of customers for sales of electricity to ultimate customers by State and customer 

class category for whom your company provided both energy and delivery service. For public 

street and highway lighting, count all poles in a community as one customer. Note: For sales 

to customer groups using brokers or aggregators, continue to count each customer 

separately. For instance, count a group of franchised commercial establishments aggregated 

through a single broker as separate customers (as reported in prior years). Enter the twoletter U.S. Postal Service abbreviation (if not preprinted) for the State in which the electric 

sales occur. (Note: Texas Retail Energy Providers (REPs) should include delivery revenues.) 

Common Instructions: SCHEDULE 4. PARTS A, B, C, AND D 

1. For column a, Residential, enter the revenue, megawatthours, and number of customers 

for electric energy supplied for residential (household) purposes. For the residential class, 

do not duplicate the customer accounts due to multiple metering for special services 

(e.g., water heating, etc.). 

2. For column b, Commercial, enter the revenue, megawatthours, and number of 

customers for electric energy supplied for commercial purposes. 

3. For column c, Industrial, enter the revenue, megawatthours, and number of customers 

for electric energy supplied for industrial purposes. 

4. For column d, Transportation, enter the revenue, megawatthours, and number of 

customers for electric energy supplied for transportation purposes. 

SCHEDULE 5. MERGERS AND/OR ACQUISITIONS 

If a merger or acquisition has occurred during the reporting period, report those newlyacquired corporate entities whose operations are now included in this report. 

SCHEDULE 6. DEMAND-SIDE MANAGEMENT INFORMATION 

Demand-side management (DSM) programs are designed to modify patterns of electricity 

usage, including the timing and level of electricity demand. SCHEDULE 6 is divided into two 

parts: Part A, Actual Effects and Part B, Annual Costs. SCHEDULE 6 is to be completed 

by every company with a company-administered demand-side management (DSM) program. 

However, companies with both sales to ultimate customers and sales for resale which are 

less than 150,000 megawatthours are required to complete only the INCREMENTAL 

EFFECTS portion of Part A and annual cost to achieve in Part B, line 13, Total Cost. 

The DSM information provided should: 1) reflect only activities that are undertaken 
9

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

specifically in response to company-administered programs, including activities implemented 

by third parties under contract to the company; 2) account for the complete range of DSM 

programs, including energy efficiency and load management; and 3) represent the energy 

and load effects at the customer meter (i.e., transmission and distribution or reserve 

requirement savings should be excluded). The DSM information should exclude, to the 

extent possible, energy and load effects that are not attributable to DSM program activities. 

Non-program related effects include changes in energy and load attributable to: 1) nonparticipants (e.g., customers known as free-riders, who would adopt program-recommended 

actions even without the program); 2) government-mandated energy-efficiency standards 

that legislate improvements in building and appliance energy usage; 3) natural operations of 

the marketplace (e.g., reductions in customer energy usage due to higher prices); and 4) 

weather and business-cycle fluctuations. 

Power supply cooperatives, municipal joint action agencies, and Federal Power Marketing 

Administrations are encouraged to coordinate the reporting of DSM information with their 

power purchasing utilities to avoid double counting the effects and costs of DSM programs. 

Utilities that have their DSM activities reported on the schedule 6 of another company should 

name that company in the space provided on line 2 of the schedule and not complete the 

schedule 6 themselves. 

SCHEDULE 6. PART A. ACTUAL EFFECTS 

This part of the Schedule collects information on the energy and load effects of DSM programs 

implemented, and measures installed, for each program category by major customer sector. It 

is divided into two subparts, Incremental Effects and Annual Effects. 

 

1. Incremental Effects: The changes in energy use (measured in megawatthours) and peak 

load (measured in megawatts) caused in the current reporting year by new participants in 

your existing DSM programs and all participants in your new DSM programs. 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 current 

reporting year. 

2. Annual Effects: The total changes in energy use (measured in megawatthours) and peak 

load (measured in megawatts) caused in the current reporting year by all participants in all 

of your DSM programs. This includes new and existing participants in existing programs 

(those implemented prior to the current reporting year that were in place during prior 

reporting year), all participants in new programs (those implemented during current 

reporting year), and participants in programs terminated since 1992 (those effects continue 

even though the programs have been discontinued). DSM programs have a useful life, and 

the net effects of these programs will diminish over time. To the extent possible, the 

Annual Effects should consider the useful life of efficiency and load control measures by 

accounting for building demolition, equipment degradation, and program attrition. 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 are to 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). Please note that Annual Effects are not a 

summation of 12 monthly peaks, but are the total DSM program effects of all programs and 

all participants for the current reporting year. 

3. For Part A, under the appropriate customer sector: Residential, Commercial, Industrial, and 

Transportation, enter the aggregate Energy Effects (megawatthours, to the third decimal 

point, if possible) and Actual Peak Reduction (megawatts to the third decimal point, if 

possible) attributable to Energy Efficiency and Load Management programs. For Load 

Management also enter the Potential Peak Reduction (megawatts to the third decimal 

point, if possible) attributable to each customer sector. 
10

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

SCHEDULE 6. PART B. ANNUAL COSTS 

This part of the schedule collects information on actual DSM program costs in the current 

reporting year. Program costs consist of the cash expenditures, reported in thousands of 

dollars, incurred by the company. Costs should reflect the total cash expenditures for the 

year, reported in thousands of dollars that flow out to support DSM programs. They should 

be reported in the year they are incurred, regardless of when the actual effects occurred. For 

example, the cash expenditures to purchase 1,000 load control devices for installation in 

customers' homes could be incurred a year in advance of the actual load savings that result 

from operation of the devices. 

Total Cost: In column (a), enter your actual Direct Costs, Incentive Payments, and Indirect 

Costs, incurred in the current reporting year. Report Energy Efficiency and Load 

Management Costs separately. Direct Costs are those costs that are directly attributable to a 

particular DSM program (e.g., Energy Efficiency or Load Management). Indirect Costs are 

costs that may not be meaningfully included in any program category, but could be identified 

with an accounting cost category (e.g., Administrative, Marketing, Monitoring & Evaluation, 

Company-Earned Incentives, Other). 

Percentage of Cost: If you are reporting DSM program costs for more than one State, in 

columns (b) through (e) provide the estimated percentage of those costs reported in column 

(a). If you are reporting program costs in more than four States, duplicate the sheet and 

attach the extra pages. 

SCHEDULE 6. PART C. SUPPLEMENTAL INFORMATION 

1. Please indicate, by checking “Yes” or “No” on line 14, whether DSM program changes, 

tracking procedures, evaluations, or reporting methods have affected the data reported on 

this schedule (since 1992). 

2. Please indicate, by checking “Yes” or “No” on line 15, whether your company currently 

operates any incentive-based demand response programs, i.e. direct load control, 

interruptible programs, demand bidding/buyback, emergency demand response, capacity 

market programs, and ancillary service market programs. If the answer is “Yes,” enter the 

number of participating customers, by class, on line 16. 

3. Please indicate, by checking “Yes” or “No” on line 17, whether your company currently 

operates any time-based rate programs, e.g., real-time pricing, critical peak pricing, variable 

peak pricing and time-of-use rates. If the answer is “Yes,” enter the number of participating 

customers, by class, on line 18.

SCHEDULE 6. PART D. ADVANCED METERING 

This schedule should only include customers from Schedule 4 Part A or Part C. 

Standard (Electric) Meters are electromechanical or solid state meters measuring 

aggregated kWh where data are manually retrieved over monthly billing cycles for billing 

purposes only. Standard meters may also include functions to measure time-of-use and/or 

demand with data manually retrieved over monthly billing cycles. 

Automated Meter Reading (AMR): Meters that collect data for billing purposes only and 

transmit this data one way, usually from the customer to the distribution utility. Aggregated 

monthly kWh data captured on these meters may be retrieved by a variety of methods 

including drive-by vans with short-distance remote reading capabilities and communication 

over a fixed network such as a cellular network. 

Enter the state and report the total number of AMR meters by sector. If your meters are in 

more than one State, provide additional information on Schedule 9, Footnotes. The number 

of AMR meters may be equal to the number of customers on Schedule 4. 

 

Advanced Metering Infrastructure (AMI): Meters that measure and record usage data at a 
11

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

minimum, in hourly intervals, and provide usage data to both consumers and energy 

companies at least once daily. Data are used for billing and other purposes. Advanced 

meters include basic hourly interval meters and extend to real-time meters with built-in twoway communication capable of recording and transmitting instantaneous data. 

Enter the state and report the total number of AMI meters by sector. If your AMI meters are 

in more than one State, provide additional information on Schedule 9, Footnotes. 

 For AMI meters that are only being used as AMR, report meters as AMR. 

Energy Served Through AMI (MWh) should be entered in megawatthours for customers 

served. 

SCHEDULE 7. DISTRIBUTED AND DISPERSED GENERATION

This schedule collects information from distribution companies on industrial and commercial 

generators of less than 1 megawatt (1000 kilowatts) installed at or near a customer’s site, or 

other sites within the system. Provide all of the requested information for grid 

connected/synchronized distributed generators in column a, and for dispersed generators that 

are not grid connected/synchronized in column b. Provide actual data if available, otherwise 

provide best estimates, and indicate the nature of the data by checking the appropriate box on 

the form. 

Schedule 7 is intended to collect information about generators on the system that are 

NOT reported on Form EIA-860, “Annual Electric Generator Report.” Plants with capacity 

of 1 MW or greater which ARE grid-connected, meet the threshold criteria for reporting on the 

860 and as such, need not be reported on Schedule 7 of the EIA-861. Residential applications 

should not be reported. 

SCHEDULE 7. PART A. NUMBER AND CAPACITY 

1. For line 1, Number of generators, provide in column (a), the number of distributed generators 

in the area served by your distribution system. (Total and less than 1 megawatt) In column 

(b), provide the number of dispersed generators. (Total and less than 1 megawatt) If you 

are unable to provide the breakout, please explain in Schedule 9, Footnotes. The total 

number must be greater than or equal to the number less than 1 MW. 

2. For line 2, Nameplate capacity, columns (a) and (b), provide the total and the sum of the 

generators with less than 1 megawatt nameplate capacity (to the nearest tenth) for all 

generators reported on line 1. The total capacity must be greater than or equal to the 

capacity less than 1 MW. 

3. For line 3, columns (a) and (b), Percent of nameplate capacity that consists of backup-only 

units, provide the percentage of the nameplate capacity listed in line 2 that is comprised of 

generators that are used only for emergency backup service. 

4. For Line 4, columns (a) and (b), Percent of capacity owned by respondent, provide the 

percentage of the nameplate capacity listed in line 2 that the respondent owns. 

5. For Line 5, columns (a) and (b), Nature of data reported, provide actual data if available, 

otherwise provide best estimates, and indicate the nature of the data by checking the 

appropriate box on the form. 

6. For Line 6, columns (a) and (b), State, provide the 2-letter U.S. Postal Service abbreviation 

for the State in which the generators are located. If you are reporting distributed or dispersed 

generators for additional States, provide additional information on Schedule 9, Footnotes. 

SCHEDULE 7. PART B, TYPES OF GENERATORS (%) 

For each of the generator types listed in columns (a) and (b), lines 1 through 6, provide the 

percentage (to the nearest tenth) of the total capacity (reported in Part A, line 2, columns (a) 
12

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER 

INDUSTRY REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

and (b), respectively) that each generator type comprises. The total of lines 1 through 6 should 

equal 100 percent in each column, (a) and (b). 

 SCHEDULE 8 - DISTRIBUTION SYSTEM INFORMATION 

Please verify the EIA provided names of the counties, parishes, etc. (dropdown menu), by 

State, where your utility-owned distribution system’s electrical equipment are located. The 

information may have been reported by the respondent last year or the result of independent 

research by the EIA staff processing the Form EIA-861. If the information is incorrect, please 

provide the correct information in Schedule 9. 

SCHEDULE 9 – COMMENTS 

This schedule provides additional space for comments. For clarification purposes, identify 

schedule, part, line number and column (if applicable) for each comment. 

GLOSSARY The glossary for this form is available online at the following URL: 

http://www.eia.doe.gov/glossary/index.html

SANCTIONS The timely submission of Form EIA-861 by those required to report is mandatory under Section 

13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as 

amended. Failure to respond may result in a penalty of not more than $2,750 per day for each 

civil violation, or a fine of not more than $5,000 per day for each criminal violation. The 

government may bring a civil action to prohibit reporting violations, which may result in a 

temporary restraining order or a preliminary or permanent injunction without bond. In such civil 

action, the court may also issue mandatory injunctions commanding any person to comply with 

these reporting requirements. Title 18 U.S.C. 1001 makes it a criminal offense for any 

person knowingly and willingly to make to any Agency or Department of the United 

States any false, fictitious, or fraudulent statements as to any matter within its 

jurisdiction. 

REPORTING 

BURDEN 

Public reporting burden for this collection of information is estimated to average 8.0 hours per 

response, including the time for reviewing instructions, searching existing data sources, 

gathering and maintaining the data needed, and completing and reviewing the collection of 

information. Send comments regarding this burden estimate or any other aspect of this 

collection of information, including suggestions for reducing this burden, to the Energy 

Information Administration, Statistics and Methods Group, EI-70, 1000 Independence Avenue 

S.W., Forrestal Building, Washington, D.C. 20585-0670; and to the Office of Information and 

Regulatory Affairs, Office of Management and Budget, Washington, D.C. 20503. A person is 

not required to respond to the collection of information unless the form displays a valid OMB 

number. 

PROVISIONS 

REGARDING 

CONFIDENTIALITY 

OF INFORMATION 

Information reported on Form EIA-861 will be treated as non-sensitive and may be publicly 

released in identifiable form. In addition to the use of the information by EIA for statistical 

purposes, the information may be used for any nonstatistical purposes such as administrative, 

regulatory, law enforcement, or adjudicatory purposes. 
13

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT 

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/30/2010 

NOTICE: This report is mandatory under the Federal Energy Administration Act of 1974 (Public Law 93-275). Failure to 

comply may result in criminal fines, civil penalties and other sanctions as provided by law. For further information 

concerning sanctions and data protections see the provisions on sanctions and the provisions concerning the confidentiality 

of information in the instructions. Title 18 U.S.C. 1001 makes it a criminal offense for any person knowingly and 

willingly to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements 

as to any matter within its jurisdiction.

SCHEDULE 1. IDENTIFICATION 

Survey Contact

First Name:________________ Last Name:_________________ 

Title:______________________________ 

Telephone (include extension):______________ Fax:__________________ 

E-mail:_______________________________ 

Supervisor of Contact Person for Survey

First Name:____________________ Last Name:_____________________ 

Title:___________________________ 

Telephone (include extension):______________ Fax:__________________ 

E-mail:________________________________ 

Report For

Entity Name: _____________________________________________

Entity ID:_________________ Reporting Year:________________ 

Entity and Preparer Information

Legal Name of Entity: _________________________________________________ 

Current Address of Entity’s Principal 

Business Office: _________________________________________________ 

Preparer's Legal Name (If Different 

From Entity’s Legal Name): _________________________________________________ 

Current Address of Preparer's Office 

(If Different From Current Address of 

Entity’s Principal Business Office): _________________________________________________ 

Respondent 

Type 

(check one) 

[ ] Federal 

[ ] Political Subdivision 

[ ] Municipal Marketing Authority 

[ ] Cooperative 

[ ] Independent Power Producer or 

Qualifying Facility 

[ ] Transmission 

[ ] State 

[ ] Municipal 

[ ] Investor-Owned 

[ ] Retail Power Marketer (or Energy 

Service Provider) 

[ ] Wholesale Power Marketer 

For questions or additional information about the Form EIA-861 contact the Survey Managers: 

 Karen McDaniel Stephen Scott 

 Phone: (202) 586-4280 Phone: (202) 586-5140 

FAX Number: (202) 287-1938 

E-mail: EIA-861@eia.doe.gov
14

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-0129 

Approval Expires: 11/

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________

SCHEDULE 2, PART A. GENERAL INFORMATION 

LINE 

NO. 

[ ] TRE (formerly ERCOT) [ ] MRO

[ ] FRCC [ ] NPCC 1 

Regional North American Electric 

Reliability Council 

(not applicable for power marketers) 

(mark all that apply) ( ) RFC (formerly ECAR, M

2 

(For EIA Use Only) Identify the North 

American Electric Reliability Council 

where you are physically located 

3 Enter Control Area Operator(s) 

Responsible for Your Oversight 

4 Did Your Company Operate 

Generating Plant(s)? (check one) 

[ ] Yes [ ] No 

[ ] Generation from company owned plant [ ] Buying distri

 systems

[ ] Transmission [ ] Wholesale po

[ ] Buying transmission services on other 

 electrical systems [ ] Retail power 5 

Identify the Activities Your Company 

Was Engaged in During the Year 

(check appropriate activities) 

[ ] Distribution using owned/leased 

 electrical wires 

[ ] Bundled Serv

 other servic

addition to electric 

Summer (Megawatts)

6 

Highest Hourly Electrical Peak System 

Demand Winter (Megawatts)

Did Your Company Operate 

Alternative-Fueled Vehicles During the 

Year? 

[ ] Yes [ ] No

Does Your Company Plan to Operate 

Such Vehicles During the Coming 

Year? 

[ ] Yes [ ] No

Name: 

Title: 

7 

 If "Yes", Please Provide Additional 

Contact Information. 

Telephone: ( ) Fax: ( ) E-mail addres
15

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-0129

Approval Expires: 11

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 2. PART B. ENERGY SOURCES AND DISPOSITION 

LINE 

NO. SOURCE OF ENERGY MEGAWATTHOURS 

LINE 

NO. DISPOSITION OF ENERGY 

1 Net Generation 11 Sales to Ultimate Customers 

2 Purchases from Electricity Suppliers 12 Sales for Resale 

3 Exchanges Received (In) 13 Energy Furnished Without Charge 

4 Exchanges Delivered 

(Out) 14 Energy Consumed By Respondent Without Cha

5 Exchanges (Net) 15 Total Energy Losses (positive number)

6 Wheeled Received (In) 

7 Wheeled Delivered (Out) 

8 Wheeled (Net) 

9 Transmission by Others, Losses 

(negative number) 

10 Total Sources (sum of lines 1, 2, 5, 8, and 9) 16 Total Disposition (sum of lines 11, 12, 13, 14, and

SCHEDULE 2, PART C. GREEN PRICING 

Green Pricing programs are voluntary programs where customers pay an extra fee to purchase electricity generated from renewable sources

STATE RESIDENTIAL 

(a) 

COMMERCIAL 

(b) 

INDUSTRIAL 

(c) 

TRANSPO

(d

Green Pricing Revenue 

(thousand dollars) 

Green Pricing Sales 

(MWh) 

Green Pricing 

Customers 

SCHEDULE 2, PART D. NET METERING 

Net Metering programs allow customers to sell excess power they generate back to the electrical grid to offset consumption. Provide the info

and customer class. 

STATE RESIDENTIAL 

(a) 

COMMERCIAL 

(b) 

INDUSTRIAL 

(c) 

TRANSPO

(d

Net Metering Displaced 

Energy (MWh) 

Net Metering 

Customers 
16

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT 

Form Approved 

OMB No. 1905-0129

Approval Expires: 11

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 3. ELECTRIC OPERATING REVENUE 

LINE 

NO. TYPE OF OPERATING REVENUE THOUSAND DOLLARS 

1 Electric Operating Revenue From Sales to Ultimate Customers 

(Schedule 4, Parts A and B) 

2 Revenue From Unbundled (Delivery) Customers (Schedule 4, Part C) 

3 Electric Operating Revenue from Sales for Resale 

4 Electric Credits/Other Adjustments 

5 Other Electric Operating Revenue 

6 Total Electric Operating Revenue (sum of lines 1, 2, 3, 4, and 5) 
17

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-0129

Approval Expires: 11

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 4. PART A. SALES TO ULTIMATE CUSTOMERS. FULL SERVICE – ENERGY AND DELIV

RESIDENTIAL 

(a) 

COMMERCIAL 

(b) 

INDUSTRIAL 

(c) 

TRANSPOR

(d)

STATE / 

TERRITORY 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers
18

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-0129

Approval Expires: 1

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 4. PART B. SALES TO ULTIMATE CUSTOMERS. ENERGY – ONLY SERVICE (WITHO

RESIDENTIAL 

(a) 

COMMERCIAL 

(b) 

INDUSTRIAL 

(c) 

TRANSPOR

(d)

STATE/ 

TERRITORY 

Revenue (thousand dollars) 

Megawatthours Sold

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold

Number of Customers
19

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-0129

Approval Expires: 1

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 4. PART C. SALES TO ULTIMATE CUSTOMERS. DELIVERY – ONLY SERVICE (AND

RESIDENTIAL 

(a) 

COMMERCIAL 

(b) 

INDUSTRIAL 

(c) 

TRANSPOR

(d)

STATE/ 

TERRITORY

Revenue (thousand dollars) 

Megawatthours Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Delivered

Number of Customers
20

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-0129

Approval Expires: 

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 4. PART D. BUNDLED SERVICE BY RETAIL ENERGY PROVIDERS, OR ANY POWER M

“BUNDLED SERVICE” 

RESIDENTIAL 

(a) 

COMMERCIAL 

(b) 

INDUSTRIAL 

(c) 

TRANSPOR

(d)

STATE / 

TERRITORY 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers

STATE 

Revenue (thousand dollars) 

Megawatthours Sold and 

Delivered

Number of Customers
21

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-01

Approval Expires

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 5. MERGERS AND/OR ACQUISITIONS 

Yes Mergers and/or acquisitions during the reporting period: No (If no, skip to Schedule 6) 

If Yes, Provide: 

Date of merger or acquisition ___________________________________ 

Company merged with or acquired ______________________________ 

Name of new parent company __________________________________ 

Address______________________________

New contact name ____________________

Email address ________________________

SCHEDULE 6. DEMAND-SIDE MANAGEMENT INFORMATION 

If your company is a small utility (end-use sales for ultimate customers and sales for resale less than 150,000 MWh) 

Effects, Part B, line 13 – Total Cost, and Parts C and D. 

LINE 

NO. 

1 Do you have company administered Demand-Side Management Programs? (check Yes or No) [ ] Yes

2 If your Demand-Side Management activities are reported on Schedule 6 of another company’s form, 

identify the company. 

NOTE If you answered "No," to Line 1 or another Company Reports your Demand-Side Management Activities on the

Schedule 6 Part D. 

SCHEDULE 6. PART A. ACTUAL EFFECTS 

INCREMENTAL EFFECTS ANNU

ENERGY EFFICIENCY RESIDENTIAL 

(a) 

COMMERCIAL 

(b) 

INDUSTRIAL 

(c) 

TRANSPORTATION 

(d) 

RESIDENTIAL 

(e) 

COMMERCIAL 

(f) 

3 Energy Effects 

(megawatthours) 

4 Actual Peak Reduction 

(megawatts) 

LOAD MANAGEMENT 

5 Energy Effects 

(megawatthours) 

6 Potential Peak Reduction 

(megawatts) 

7 Actual Peak Reduction 

(megawatts) 

7a Were these savings verified through an independent evaluation? [ ] Yes [ ] No 
22

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Appro

OMB No. 19

Approval Ex

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 6. PART B. ANNUAL COSTS (THOUSAND DOLLARS AND PERCENTAGE

(b) 

Percentage of 

costs by State 

(c) 

Percentage of 

costs by State 

State 1: State 2: 

(a) 

Costs 

(thousand dollars) 

8 Direct Costs, excluding incentive payments - 

Energy Efficiency 

9 Direct Costs, excluding incentive payments - 

Load Management 

10 Incentive Payments – Energy Efficiency 

11 Incentive Payments – Load Management 

12 Indirect Costs 

13 Total Cost (sum of all above) 

SCHEDULE 6. PART C. SUPPLEMENTAL INFORMATION

(To be completed by all respondents) 

14 

Have there been any major changes to your Demand-Side Management programs (e.g., terminated program

information or financing programs, or a shift to programs with dual load building objectives and energy effi

objectives), program tracking procedures, or reporting methods that affect the comparison of demand-side 

management data reported on this schedule to data from previous years? (check Yes or No) 

15 

Does your company currently operate any incentive-based demand response programs (e.g., direct load control, interru

programs, demand bidding/buyback, emergency demand response, capacity market programs, and ancillary service ma

programs)? (check Yes or No) 

16 If the answer to line 15 is “Yes”, please disclose the number of participating customers by class. 

Residential Commercial Industrial 

17 Does your company currently operate any time-based rate programs (e.g., real-time pricing, critical peak pricing, varia

pricing and time-of-use rates)? (check Yes or No) 

18 If the answer to line 17 is “Yes”, please disclose the number of participating customers by class. 

Residential Commercial Industrial 
23

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Appro

OMB No. 19

Approval Ex

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 6. PART D. ADVANCED METERING 

Only customers from Schedule 4A and 4C need to be reported on this schedule. AMR – data transmitted o

can be transmitted in both directions, to the utility and customer. 

Number of Meters 

(a) 

RESIDEN

TIAL 

(b)

COMMER

CIAL 

(c)

IND

US

TRI

AL 

(d) 

N ber of A um MR 

Meters 

Number of AMI 

Meters

Energy Served 

Through AMI 

Meters (MWh) 

Number of Meters 

(a) 

RESIDEN

TIAL 

(b)

COMMER

CIAL 

(c)

IND

US

TRI

AL 

(d) 

Number of AMR 

Meters 

Number of AMI 

Meters

Energy Served 

Through AMI 

Meters (MWh) 

Number of Meters 

(a) 

RESIDEN

TIAL 

(b)

COMMER

CIAL 

(c)

IND

US

TRI

AL 

(d) 

Number of AMR 

Meters 

Number of AMI 

Meters

Energy Served 

Through AMI 

Meters (MWh) 
24

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Appro

OMB No. 19

Approval Ex

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 7. DISTRIBUTED AND DISPERSED GENERATION

If your company owns and/or operates a distribution system, please report information on known distributed generation

capacity may be utility or customer-owned. 

SCHEDULE 7. PART A. NUMBER AND CAPACITY 

LINE 

NO. 

DISTRIBUTED GENERATORS 

(COMMERCIAL AND INDUSTRIAL GRID 

 CONNECTED/SYNCHRONIZED GENERATORS) 

(a) 

LINE 

NO. 

DISPERSED G

(COMMERCIAL AND INDUST

CONNECTED/SYNCHRO

(b

Total <1MW 

1 Number of generators (N) 1 Number of generators (N) 

2 Total combined capacity (MW) 2 Total combined capacity (MW) 

3 Percent of capacity that consists of backup-only 

units 3 Percent of capacity that consists of units

4 Percent of capacity owned by respondent 4 Percent of capacity owned by respo

Actual [ ] 5 Nature of data reported Estimated [ ] 

5 Nature of data reported

6 State 6 State 

SCHEDULE 7. PART B. TYPES OF GENERATORS (% of total capacity)

1 Internal combustion/reciprocating engines 1 Internal combustion/reciprocating e

2 Combustion turbine(s) 2 Combustion turbine(s) 

3 Steam turbine(s) 3 Steam turbine(s) 

4 Hydroelectric 4 Hydroelectric 

5 Wind turbine(s) 5 Wind turbine(s) 

6 Other 6 Other 

Actual [ ] 7 Nature of data reported Estimated [ ] 7 Nature of data reported 
25

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved

OMB No. 1905-0

Approval Expire

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 8. DISTRIBUTION SYSTEM INFORMATION 

If your company owns a distribution system, please identify the names of the counties (parish, etc.) by State in which th

located. 

LINE 

NO. 

STATE 

(U.S. POSTAL 

ABBREVIATION) 

(a) 

COUNTY 

(PARISH, ETC.) 

(b) 

LINE 

NO. 

STATE 

(U.S. POSTAL 

ABBREVIATION) 

(a) 

1 20 

2 21 

3 22 

4 23 

5 24 

6 25 

7 26 

8 27 

9 28 

10 29 

11 30 

12 31 

13 32 

14 33 

15 34 

16 35 

17 36 

18 37 

19 38 
26

U.S. Department of Energy 

Energy Information Administration 

Form EIA-861 (2009) 

ANNUAL ELECTRIC POWER INDUSTRY 

REPORT

Form Approved 

OMB No. 1905-0129

Approval Expires: 

Entity Name:_________________________________________ 

Entity ID:_______ Reporting Year:________________ 

SCHEDULE 9. COMMENTS 

SCHEDULE 

(a) 

PART 

(b) 

LINE NO. 

(c) 

COLUMN 

(d) 

NOTE(S) 

(e)