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 fo rm are used to accurate ly maintain the EIA list of electric utilities, to draw samples for other el ectric 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 elec tric 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 se cure internet data collection system (e-file). This system uses security protocols to protec t 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.gov2 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 coordi nate 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, divi de 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 poi nts), except where exp licitly 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 pr ograms 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 fo r public-street and highway lighting should be one customer per community.

 Please do not count each pole as a separ ate 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, revi se the incorrect entry and provide the correct3 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 prin cipal 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 No rth American Electric Reliability Corporation (NERC), in which your organization co nducts operations.

The Regional Councils are:

TRE.................... Texas Regional Entity FRCC ................. Florida Reliability Coor dinating Council

MRO................... Midwest Re liability Organization

NPCC................. Northeast Po wer Coordinating Council RFC................. Reliability First Corporation

SERC................. Southeastern El ectric Reliability Council

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

WECC ................ Western El ectric Coordinating Council

2. For line 3, Control Area Operator(s) , control area operator(s) responsible for your oversight will be already entered, from the previo us 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 othe r electrical systems. Types of support include customer billing, distribution system support charges fo r energy delivered, line maintenance, and/or equipment charges.

Wholesale power marketing. Wholesale transactions with other electric utilities, purchases from power producers, and transactio ns to export and/or import electricity to, or4 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 combinati on 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 l oad (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 in terval 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 th is question, an “alternative-fueled vehicle” is either designed or manufactured by an origin al equipment manufacturer or is a converted vehicle designed to operate in either dual-f uel, flexible-fuel, or dedicated modes on fuels other than gasoline or diesel. This does not in clude 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 a ll 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 us ed 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: nonutilit y power producers and power marketers (reported separately in previ ous years), municipal departments and power agencies, cooperatives, investor-o wned utilities, political subdi visions, 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 Aut hority (TVA), United States Army Corps of Engineers, the United States Bureau of Recl amation, United States Bureau of Indian Affairs, International Boundary and Water Co mmission, 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 ex change 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 y our system (wheeling) for delivery to other systems. Do not report as Wheeled Received, energy purchased or exchanged for consumption within your system, wh ich was wheeled to you by others.

8. For line 7, Wheeled Delivered (Out) , enter the total amount of en ergy 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 sy stem 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 pr ovided 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 ulti mate 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 requirement s 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. Th is 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 fo r. 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 prog rams allow electricity customers the opportunity to purchase electricity generated from renewable resources. R enewable resources include solar, wind, geothermal, hydroelectric power, and wood. Revenue should be reported in thousands of dollars to the nearest tenth (for example, re venue 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 cl ass. The sales volumes and the number of customers should not exceed the values report ed 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, typi cally 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 generatio n (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 repo rted 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 re venue 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, su ch as fuel or revenue from purchased power, from previous reporting periods whic h 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 el ectric 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 nonrequi rements (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 Unif orm 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 custom ers resulting from rate commission rulings delayed beyond the reporting year in which the funds were originally collected. Also,

include revenue distributions to customer s 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 electr icity. 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 transm ission 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 unde r 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 dol lars, 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 prov ides 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 agg regators, continue to count each customer separately. For instance, count a group of fr anchised 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 St ate 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 dol lars, 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 prov ides only the energy consumed, where another8 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 deliver y services, including, for ex ample, 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 dol lars, 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 AN Y 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 fr anchised commercial establishments aggregated through a single broker as separate customer s (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 Prov iders (REPs) should inclu de delivery revenues.)

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

1. For column a, Residential, enter the revenue, megawatt hours, 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, megawatthour s, 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

Dema nd-side management (DSM) programs are designed to modify patterns of electricity usage, including the timing and level of electric ity 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-administer ed demand-side management (DSM) program. However, companies with both sales to ultima te 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) re flect only activities that are undertaken9 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) gov ernment-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 t he reporting of DSM information with their power purchasing ut ilities to avoid double counting the e ffects and costs of DSM programs. Utilities that have their DSM activities repor ted 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 progr am category by major customer sector. It is divided into two subparts, Incremental Effects and Annual Effects

.

1. Incremental Effects: The changes in ene rgy 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 participa nts in your new DSM programs. Reported

Incremental Effects should be annualized to indi cate the program effects that would have occurred had these participants been initiated in to the program on January 1 of the current reporting year.

2. Annual Effects: The total changes in ene rgy use (measured in megawatthours) and peak load (measured in megawatts) caused in the curre nt 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 report ing 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 discontinu ed). 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 lif e of efficiency and load control measures by accounting for building demolition, equipment degradation, and program attrition. The effects of new participants in existing program s and all participants in new programs should be based on their start-up dates (i.e., if parti cipants 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 to tal DSM program effects of all programs and all participants for the current reporting year.

3. For Part A, under the appropriate customer se ctor: Residential, Commercial, Industrial, and Transportation, enter the aggregate Energy Effects (megawatthours, to the third decimal point, if possible) and Actual Peak Reducti on (megawatts to the third decimal point, if possible) attributable to Energy Efficiency and Load Management programs. For Load Management also enter the Potential Peak R eduction (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 informati on on a ctual 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, regar dless 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 adv ance of the actual load savings that result from operation of the devices.

Total Cost: In column (a), enter your actual Dire ct Costs, Incentive Pa yments, and Indirect Costs, incurred in the current reporting year. Report Energy Efficiency and Load Management Costs separately. Direct Costs are th ose 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 pe rcentage of those costs reported in column (a). If you are reporting program costs in mo re than four States, duplicate the sheet and attach the extra pages.

SCHEDULE 6. PART C. SUPPLEMENTAL INFORMATION

1. Please indicate, by checking “Yes” or “N o” on line 14, whether DSM program changes, tracking procedures, evaluations, or reporti ng methods have affected the data reported on this schedule (since 1992).

2. Please indicate, by checking “Yes” or “N o” on line 15, whether your company currently operates any incentive-based demand response programs, i.e. direct load control, interruptible programs, demand bidding/buybac k, emergency demand response, capacity market programs, and ancillary service market programs. If the answer is “Yes,” enter the number of participating custom ers, by class, on line 16.

3. Please indicate, by checking “Yes” or “N o” 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 answ er 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 retrie ved over monthly billing cycles for billing purposes only. Standard meters may also incl ude 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 t he distribution utilit y. Aggregated monthly kWh data captured on these meters ma y 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 AM R m eters by sector. If your meters are in more than one State, provide additional info rmation 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 a11 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 provid e 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. DISTRIBUTE D AND DISPERSED GENERATION

This schedule collects information from distribu tion 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, m eet 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 y our 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 act ual 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 repo rting distributed or dispersed generators for additional States, provide additi onal information on Schedule 9, Footnotes.

SCHEDULE 7. PART B, T YPES OF GENERATORS (%)

For each of the generator types listed in colu mns (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 comp rises. The total of lines 1 through 6 should equal 100 percent in each column, (a) and (b).

SCHEDULE 8 - DISTRIBU TION SYSTEM INFORMATION

Please verify the EIA provided names of the c ounties, parishes, etc. (dropdown menu), by State, where your utility-owned di stribution system’s electrical equipment are located. The information may have been reported by the respo ndent last year or the result of independent research by the EIA staff processing the Form EI A-861. If the information is incorrect, please provide the correct information in Schedule 9.

SCHEDULE 9 – COMMENTS

This schedule provides additional space for comm ents. For clarificat ion 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 thos e required to report is mandatory under Section 13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Pub lic 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 in formation is estimated to average 8.0 hours per response, including the time for reviewing in structions, searching existing data sources, gathering and maintaining the data needed, and completing and reviewing the collection of information. Send comments regarding this bur den 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 t he use of the information by EIA for statistical purposes, the information may be used for any no nstatistical purposes su ch 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 ot her 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 Unit ed States any false, fictiti ous, or fraudulent statements as to any matter within its jurisdiction.



### SCHEDULE 1. IDENTIFICATION
Survey Contact
First Name:________________ Las t Name:_________________
Title:___________

___________________ Telephone (include extension) :______________ Fax:

__________________ E-mail:____________

___________________ Supervisor of Contact Person for Survey
First Name:____________________ Las t Name:_____________________
Title:_____

______________________ Telephone (include extension) :______________ Fax:

__________________ E-mail:____________

____________________ Report For

Entity Name: _____________

________________________________ Entity ID:_________________ R eporting 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 P hone: (202) 586-5140 FAX Number: (202) 287-1938

E-mail: 

### EIA-861@eia.doe.gov14 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-0129

A pproval 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 distr i systems [ ] Transmission [ ] Wholesale p o [ ] Buying transmission services on other electrical systems [ ] Retail powe r 5 Identify the Activities Your Company Was Engaged in During the Year (check appropriate activities) [ ] Distribution using owned/leased

electrical wires [ ] Bundled Ser v other servi c 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 addre s15 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-0129

A pproval Expires: 1 1


### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

SCHEDULE 2. PART B. EN ERGY 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 Ch a

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, an d SCHEDULE 2, PART C. GREEN PRICING

Green Pricing programs are voluntary programs where customers pay an extra f ee to purchase electricity generated from renewable source s

STATE RESIDENTIAL (a) COMMERCIAL (b) INDUSTRIAL (c) TRANSP O ( 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) TRANSP O ( d Net Metering Displaced Energy (MWh)

Net Metering

Customers16 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-0129

A pproval Expires: 1 1 

### 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

A pproval Expires: 1 1


### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

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

RESIDENTIAL (a) COMMERCIAL (b) INDUSTRIAL (c) TRANSPO R (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 Customers18 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-012 9

A pproval Expires: 1


### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

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

RESIDENTIAL (a) COMMERCIAL (b) INDUSTRIAL (c) TRANSPO R (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 Customers19 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-012 9

A pproval Expires: 1


### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

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

RESIDENTIAL (a) COMMERCIAL (b) INDUSTRIAL (c) TRANSPO R (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 Customers20 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-012 9

A pproval Expires:


### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

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

“BUNDLED SERVICE”

RESIDENTIAL (a) COMMERCIAL (b) INDUSTRIAL (c) TR A NSPO R (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 Customers21 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-01

A pproval Expire s 

### 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 ul timate customers and sales fo r 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) [ ] Ye s

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 A NNU

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 [ ] No22 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Appr o OMB No. 1 9

A pproval E x 

### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

SCHEDULE 6. PART B. ANNUAL COST S (THOUSAND DOLLARS AND PERCENTAG E

(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 progra m 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- b ased demand response programs (e.g., direct load control, interr u programs, demand bidding/buyback, emergency demand response , capacity market programs, and ancillary service m a programs)? (check Yes or No)

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

Residential Commercial Industrial

17 Does your company currently operate any time-based rate progra ms (e.g., real-time pricing, critical peak pricing, vari a pricing and time-of-use rates)? (check Yes or No)

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

Residential Commercial Industrial23 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Appr o OMB No. 1 9

A pproval E x 

### Entity Name:_______

__________________ ________________ Entity ID:_______ R eporting Year:________________

SCHEDULE 6. PART D. ADVANCED METER ING

Only customers from Schedule 4A and 4C need to be reported on this schedule. AMR – data transmitted o can be transmitted in both direct ions, to the ut ility and customer.

Number of M eters (a) RESID EN

TIAL

(b) COMME R

CIAL

(c) IND

US

TRI

AL (d)

N ber of A

um MR

Meters

Number of A MI

Meters Energy Ser ved Through AMI

Me ters (MWh)

Number of M eters (a) RESID EN

TIAL

(b) COMME R

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 Appr o OMB No. 1 9

A pproval E x 

### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

SCHEDULE 7. DISTRIBUTED AND DISPERSED GENERATION

If your company owns and/or operates a distribution syst em, please report information on known distributed generatio n 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 INDUS T

CONNECTED/SYNCHR O (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 resp o

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 reported25 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-0

A pproval Expir e 

### 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 t h

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 3826 U.S. Department of Energy Energy Information Administration Form EIA-861 (2009) ANNUAL ELECTRIC POWER INDUSTRY

REPORT Form Approved

OMB No. 1905-012 9

A pproval Expires:


### Entity Name:_______

__________________________________ Entity ID:_______ Reporting Year:________________

SCHEDULE 9. COMMENTS

SCHEDULE (a) PART (b) LINE NO. (c) COLUMN (d) NOTE(S) (e)