1 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

PURPOSE Form EIA-860 collects data on the status of ex isting electric generating plants and associated equipment (including generators, boilers, cooling systems and flue gas desulfurization systems) in the United States, and those scheduled for initial comme rcial operation within 5 years of the filing of this report. The data from this form app ear in several EIA publications; including the Electric Power Monthly, Electric Power Annual, and the Annual Energy Review. The data collected on this form are used to monitor the current status and trends of t he electric power industry and to evaluate the future of the industry.

REQUIRED RESPONDENTS All existing plants and proposed (5-year plans) pl ants that: 1) have a total generator nameplate capacity (sum for generators at a single site) of 1 MW or greater; and 2) where the generator(s), or the facility in which the generator(s ) resides, is connected to the loca l or regional electric power grid and has the ability to draw power from the grid or deliver power to the grid are reported on Form EIA-860.
In the case of generators located in Alaska and Hawaii which are not a part of the North American interconnected grid, generators that are connected to a “public grid,” meaning a local or regional transmission or distribution system that supplies power to the public, must be reported on Form EIA860.
The operator or planned operator of jointly-owned plants should be the only respondent for those plants.

RESPONSE DUE DATE Submit the completed Form EIA-860 directly to the EIA annually on or before February 15.

METHODS OF FILING RESPONSE Submit your data electronically using EIA’s secure Internet Data Collection system (IDC). 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-860@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 loggi ng into the IDC or using the IDC contact the IDC Help Center 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.

Retain a completed copy of this form for your files.
Internet System Questions : For questions related to the Internet Data Collection system, see the help contact information immediately above.

Data Questions: For questions about the data requested on Form EIA-860, contact either Survey Manager: CONTACTS

Patricia Hutchins Telephone Number: (202) 586-1029 FAX Number: (202) 287-1960 E-mail: Patricia.Hutchins@eia.doe.gov2 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

GENERAL INSTRUCTIONS 1. Verify all EIA provided information. If in correct, revise the incorrect entry and provide the correct information. State codes are two-letter U.S. Postal Service abbreviation. Provide any missing information. If filing a paper copy of th is form, typed or legible handwritten entries are acceptable. Allow the original entry to remain readable. See more specific instructions for correcting data in SCHEDULE 2, “Power Plant Data,” and SCHEDULE 3. “Generator Information.”

2. Check all data for consistency with the same or related data that appear in more than one schedule of this form or in other forms or report s submitted to EIA. Explain any inconsistencies under SCHEDULE 7, COMMENTS.

3. For planned power plants and/or planned equipment, use planning data to complete the form.

4. Report in whole numbers (i.e., no decimal point s), except where explicit ly instructed to report otherwise.

5. Indicate negative amounts by using a minus sign before the number.

6. Report date information as a two-digit month and four-digit year, e.g., “11 - 1980.”

7. Furnish the requested information to reflect the status of your current or planned operations as of the beginning of the reporting calendar year. If the company no longer operated a specific power plant as of December 31, report the name of the operator as of December 31 along with related contact information (including contact person’s name, telephone number and e-mail address, if known) in S CHEDULE 7, "COMMENTS.” Do not complete the form for that power plant.

8. To request additional blank schedules contact the Energy Information Administration using the contact information on page 1, or download the form from http://www.eia.doe.gov/cneaf/e lectri city/page/forms.html

.
9. For definitions of terms, refer to the E nergy Information Administration glossary at http://www.eia.doe.gov/glossary/index.html

. 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.

3. Report For: Verify all information, including operator name, operator identification number, and year for which data are being reported. These fi elds 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 correct information. Provide any missing information.

Operator and Preparer Information:

4. For Legal Name of Operator , verify the name. The operator of the power plant is the electric power producer owner/joint owner of the plant or a subsidiary of the electric power producer who has a working interest in the plant and who is responsible for making the strategic decisions related to the management and physical operation of the power plant. The operator entity may also be an electric power producer or a subsidiary of an electric power producer who operates a power plant that is wholly owned by anot her electric power producer. Operator excludes energy services companies under contract to operate the plant for the electric power producer;3 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

in these cases, the electric power producer should be reported as the legal operator. 5. For Current Address of Principal Business Office of Plant Operator , verify the principal name and address to which this form should be mailed. Include an attention line, room number, building designation, etc., to facilitate the future handling and processing of this form.

6. For Preparer's Legal Name, verify the name to which this fo rm should be mailed if different from Legal Name of Operator

.

7. For Current Address of Preparer's Office , verify the address to which this form should be mailed. Include an attention line, room number, bu ilding designation, etc., to facilitate the future handling and processing of this form, if preparer’s address is different from the address of the Legal Name of Operator

. 8. For Is the Operator an Electric Utility ; check “Yes” if so. Otherwise check “No.”

SCHEDULE 2. POWER PLANT DATA

Verify or complete one section for each existing power plant and each power plant planned for initial commercial operation within 5 years. To report a new plant or a plant that is not already identified, use a blank SCHEDULE 2.

1. For line 1 , Plant Name and EIA Plant Code, enter the name of the power plant, and enter or verify the EIA Plant Code for the power plant. Each power plant must be uniquely identified. The type of plant does not need to be a part of the plant name, e.g., “Plant x Hydro” needs to be reported as “Plant x” only. The type of plant is recognized by the prime mover code(s) reported in SCHEDULE 3. Generator Informat ion. There may be more than one prime mover type associated with a single plant name (single si te). Enter “NA 1,” “NA 2,” etc., for planned facilities that have no name(s).

2. For line 2 , Street Address , enter or verify the street address of the power plant.

3. For line 3, County Name and City Name , enter the county and city in which the plant is (will be) located. Enter “NA” for planned facilities that have not been sited. If a mobile power plant, indicate with a note in SCHEDULE 7, COMMENTS.

4. For line 4, State , enter the two-letter U.S. Postal Servic e abbreviation for the State in which the plant is located. Enter “NA” for planned facilitie s for which the State has not been determined. If the State is “NA,” the county name must be “NA.”

5. For line 5, Zip Code , enter the zip code of the plant. Provide, at a minimum, the five-digit zip code; however, the nine-dig it code is preferred.

6. For line 6, Latitude and Longitude , enter the latitude and longitude of the plant in degrees, minutes, and seconds.

7. For line 7, Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”:

The longitude and latitude measurement for a location depends in part on the coordinate system (or “datum”) the measurement is keyed to. “Datum systems” used in the United States, include the North American Datum 1927 (NAD27), North American Datum 1983 (NAD83) and World Geodetic Survey 1984 (WGS84).

If you know the datum system for the plant longi tude and latitude, enter the system name (e.g., NAD83) on line 7. If you do not know the datum system used, enter UNK. (For background information on datum and their uses, see: http://biology.usgs.gov/index.html 

### ).

8. For line 8, NERC Region , enter the NERC region in which the plant is located.4 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

9. For line 9, Name of Water Source , enter the name of the principal source from which cooling water for thermal-electric plants and water fo r generating power for hydroelectric plants is directly obtained. If more than one water source is (will be) used, enter the name(s) of the other sources of water in SCHEDULE 7, COMMENTS. Enter “Municipality” if the water is from a municipality. Enter “wells” if water is from we lls. Enter “NA” for planned facilities for which the water source is not known.

10. For line 10, Steam Plant Status , and line 11, Steam Plant Type, verify the appropriate status and type for completing Schedule 6, Boiler informatio n. If either is incorrect, contact EIA.

11. For line 12, Primary Purpose of the Plant , enter the North American Industry Classification System (NAICS) code that best describes the prim ary purpose of the reporting plant. Electric utility plants will generally use code 22. Indepen dent power producers whose sole or primary business is the sale of electricity will also genera lly use code 22. For industrial and commercial generators whose primary business is an industrial or commercial process (e.g., paper mills, refineries, chemical plants, etc.), use Table 2 in these instructions to determine the code.

12. Line 13, Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Cogenerator Status ? Check “Yes” or “No”; if “Yes” provide all QF docket numbers granted to the facility. Do not include prefixes (e.g. “QF” or “SPP” or “EWG”) before the docket number. Include only the numerical portion of the docket number, including dashes.

13. Line 14, Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Small Power Producer Status ? Check “Yes” or “No”; if “Yes” provide all QF docket numbers granted to the facility. . Do not include prefixes (e.g. “QF” or “SPP” or “EWG” before the docket number. Include only the numerical portion of the docket number, including dashes.

14. Line 15, Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Exempt Wholesale Generator Status ? Check “Yes” or “No”; if “Yes” provide all QF docket numbers granted to the facility. . Do not inclu de prefixes (e.g. “Q F” or “SPP” or “EWG” before the docket number. Include only the numerical portion of the docket number, including dashes.

15. For line 16, Owner of Transmission / Distribution Facilities , enter the name of the owner of the transmission or distribution facilities to wh ich the plant is interc onnected and the grid voltage at the point of interconnection. Report voltage in kilovolts (kV).

SCHEDULE 3. GENERATOR INFORMATION

1. Verify or complete for each existing or planned generator. Complete one column for each generator (up to three generators can be reported on one page) for all generators that are: (1) in commercial operation (whether active or in active), or (2) expected to be in commercial operation within 5 years and are either planned, und er construction, or in testing stage. Do not report auxiliary generators.

2. To report a new generator, use a separate (b lank) section of SCHEDULE 3. To report a new generator that has replaced one that is no longer in service, update the status of the generator that has been replaced along with other relat ed information (e.g., retirement date), then use a separate (blank) section of SCHEDULE 3 to r epo rt all of the applicable data about the new generator. Each generator must be uniquely identified within a plant. The EIA cannot use the same generator ID for the new generator that wa s used for the generator that was replaced.5 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

SCHEDULE 3. PART A. GENERA TOR INFORMATION – GENERATORS

1. For line 1, Plant Name , enter the official or legal name of the power plant as reported on SCHEDULE 2.

2. For line 2, EIA Plant Code , enter the EIA plant code as reported on SCHEDULE 2.

3. For line 3, Operator’s Generator Identification , enter the unique generator identification commonly used by plant management. Generator identification can have a maximum of four characters, and should be the same identification as reported on other EIA forms to be uniquely defined within a plant.

4. For line 4, for organic-fueled steam generato rs, including heat recovery steam generators with duct firing, enter the identification (ID) code for ea ch boiler that provides steam to the generator. The ID should match those provided in SCHEDU LE 6. The applicable parts of SCHEDULE 6must be completed for each boiler. Organic-fueled steam-electric generators include fossilfueled and combustible renewable-fueled generators.

5. For line 5 , Prime Mover , enter one of the prime mover codes below. For combined cycle units, a prime mover code must be entered for each generator.

Prime Mover Code Prime Mover Description

ST Steam Turbine, including nuclear, geothermal and solar steam (does not include combined cycle). GT Combustion (Gas) Turbine – Simple Cycle (includes jet engine design) IC Internal Combustion Engine (diesel, piston, reciprocating) CA Combined Cycle Steam Part CT Combined Cycle Combustion Turbine Part (type of coal or solid must be reported as energy source for integrated coal gasification). CS Combined Cycle Single Shaft (combustion turbine and steam turbine share a single generator) CC Combined Cycle Total Unit (use only for plants/generators that are in planning stage, for which specific gener ator details cannot be provided). HY Hydraulic Turbine (includes turbines associated with delivery of water by pipeline) PS Hydraulic Turbine – Reversible (pumped storage) BT Turbines Used in a Binary Cycle (such as used for geothermal applications) PV Photovoltaic WT Wind Turbine CE Compressed Air Energy Storage FC Fuel Cell OT Other (Describe in SCHEDULE 7, COMMENTS)

Combined heat and power systems often generate steam with multiple sources and generate electric power with multiple prime movers. For reporting purposes, a simple cycle prime mover should be distinguished from a combined cycle prime mover by determining whether the power generation part of the steam system can operate ind ependently of the rest of the steam system. If these system components cannot be operated independently, then the prime movers should be reported as combined cycle types.

6. For line 6, Unit Code (Multi-generator code), identify all generators that are op erated with other generators as a single unit. Generators operat ing as a single unit should have the same unit (multi-generator code) code or four-character id entifier. Identify combined cycle generators that operate as a unit with a unique four-charact er identifier. All generators that operate as a unit in combined cycle must have the same uniq ue identifier. If generat ors do not operate as a single unit, this space should be left blank.6 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

7. For line 7, Ownership , identify the ownership for each gener ator using the following codes: "S" for single ownership by respondent, "J" for jointly owned with another entity or "W" for wholly owned by an entity other than respondent.

8. For line 8, Is this generator an electric utility or non-utility generator? For each generator, check “electric utility” or non-utility. (See EIA Gl ossary for definition of electric utility generator.)

9. For line 9, Date of Sale, If Sold , enter the month and year of the sale of the generator (e.g., 12- 2007), if the generator has been sold in its entirety. For changes in shares of ownership only, with no change in operator, report in Sc hedule 4, OWNERSHIP OF GENERATORS OWNED JOINTLY OR BY OTHERS. . In SCHEDULE 7, provide the legal name, business address, contact person, phone number and e-mail address of the entity to which this generator was sold.

10. For line 10, Can This Generator Deliver Power to the Transmission Grid ?, indicate if the generator can or cannot deliver power to the transmission grid.

11. For line 11, if the prime mover is “CA,” (combined-cycle steam), “CS” or “CC” check “Yes” if the unit has duct-burners for supplementary firing of the turbine exhaust gas. Otherwise, check “No.” If “Yes” SCHEDULE 6 must be completed, as applicable.

SCHEDULE 3. PART B. GENERATOR INFORMATION – EXISTING GENERATORS

1. For line 1, Generator Nameplate Capacity , report the highest value on the nameplate in megawatts rounded to the nearest tenth. If the nam eplate capacity is expressed in kilovolt amperes (kVA), convert to kilowatts by multiply ing the corresponding power factor by the kVA, divide by 1,000 to express in megawatts to the nearest tenth. If generator nameplate capacity is exceeded by net summer capacity, provide the reason(s) in SCHEDULE 7.

2. For line 2, Net Capacity , enter the generator's (unit's) su mmer and winter net capacities for the primary energy sources. Report in megawatts, rounded to the nearest tenth. For generators that are out of service for an extended period or on standby or have no generation during the respective seasons, report the estimated capacities based on historical performance. For generators that are tested as a unit, a single aggregate net summer capacity and a single aggregate net winter capacity may be reported. For hydroelectric, report the instantaneous capacity at maximum waterflow.

3. For line 3a, Reactive Power Output (MVAR) Corresponding to Net Summer Capacity for generators with nameplate capacity of 10 MW or greater , based on the generator power capability curve for the generator
, enter the lagging reactive power output and the leading reactive power output that correspond to the net summer capacity (line 2), adjusted for any impacts of exciter limiters. A MVAR is a Mega Voltampere Reactive.

4. For line 3b , Reactive Power Output (MVAR) Corresponding to Net Winter Capacity for generators with nameplate capacity of 10 MW or greater, based on the generator power capability curve for the generator, enter the lagging reactive power output and the leading reactive power output that correspond to the net winter capacity (line 2), adjusted for any impacts of exciter limiters. A MVAR is a Mega Voltampere Reactive.

5. For line 4, Status Code , enter one of the following status codes:

Status Code Status Code Description OP Operating - in service (commercial operation) and producing some electricity. Includes peaking units t hat are run on an as needed (intermittent or seasonal) basis. SB Standby/Backup - available for service but not normally used (has little or no7 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010
generation during the year) for this reporting period. OA Out of service – was not used for some or all of the reporting period but was either returned to service on December 31 or will be returned to service in the next calendar year.

Note: Units undergoing maintenance or repair of less than 12 months duration and are expected to be returned to service upon completion of maintenance or repair should be given an operating status. OS Out of service – was not used for some or all of the reporting period and is NOT expected to be returned to service in the next calendar year. RE Retired - no longer in service and not expected to be returned to service.

6. For line 5, Synchronized to the Grid , if the status code entered on line 4 is standby (SB) please note if the generator is currently equipped such that, when operating, it can be synchronized to the grid.

7. For line 6, Initial Date of Operation , enter the month and year of initial commercial operation.

8. For Line 7, Retirement Date, enter the date the generator wa s retired, in month and year format.

9. For line 8, Is this generator associated with a Combined Heat and Power system (fuel input is used to produce both electricity and useful thermal output)? check either "Yes" or "No". If the answer is “Yes”, check either bottoming cycle or topping cycle, as applicable. In a topping cycle system, electricity is produced firs t and any waste heat from that production is used in a manufacturing process or for direct heating, and/or space heating/cooling. In a bottoming cycle system, thermal output is used in a process other than electricity production and any waste heat is then used to produce electricity.

10. For line 9, Predominant Energy Source , enter the energy source code for the fuel used in the largest quantity (Btus) during the reporting year to power the generator. For generators that are out of service for an extended period of time or on standby, report the energy sources based on the generator’s latest operating experience. Sele ct appropriate energy source codes from Table 1 in these instructions. For generators driven by turbines using steam that is produced from waste heat or reject heat, report the original energy source used to produce the waste heat (reject heat).
11. For line 9a, if the predominant energy source for powering the generator is coal or petroleum coke, check all types of technology and steam conditions that apply.
12. For line 10, report the Start-up and flame stabilization energy sources used by the combustion unit(s) associated with this gener ator. Prime mover = ST (steam units only)

13. For line 11, Second Most Predominant Energy Source , enter the energy source code for the energy source used in the second largest quantity (Btus) during the reporting year to power the generator. DO NOT include a fuel used only for start-up or flame stabilization. Select appropriate energy source codes from Table 1 in these instructions. For generators driven by turbines using steam that is produced from waste heat or reject heat, report the original energy source used to produce the waste heat (reject heat).

14. For line 12, Other Energy Sources , enter the codes for other energy sources: first, list the energy sources actually used in order of predomi nance (based on quantity of Btus), then list ones that the generator was capable of using but was not used to generate electricity during the last 12 months. For generators that are out of service for an extended period of time or on standby, report the energy sources based on the generator’s latest operating experience. Select appropriate energy source codes from Table 1 in these instructions. For generators driven by turbines using steam that is produc ed from waste heat or reject heat, report the original energy source used to produce the waste heat (reject heat)

15. Line 13, Is this generator part of a solid fuel gasification system, check yes or no as appropriate.8 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

16. For line 14, If Energy Source is Wind , enter the number of turbines.

17. For line 15, Tested Heat Rate , enter the tested heat rate under full load conditions for all generators that derive their energy from combustion or fission of fuel. Report the heat rate as the fuel consumed in British thermal units (Btu s) necessary to generate one net kilowatthour of electric energy. Report the tested heat rate under full load, not the actual heat rate, which is the quotient of the total Btu(s), consumed and total net generation. If generators are tested as a unit (not tested individually), report the same test result for each generator. For generators that are out of service for an extended period or on standby, report the heat rate based on the unit’s latest test. If the generator is associat ed with a combined heat and power (CHP) system and no tested heat rate data are available, report either the manufacturer’s specification for heat rate or an estimated heat rate. DO NOT repo rt a heat rate that includes the fuel used for the production of useful thermal output. Fo r Internal Combustion units, a manufacturer’s specification or estimated heat rate should be repo rted, if no tested heat rate is available. If the reported value is not a tested heat rate, explain in SCHEDULE 7, COMMENTS.

18. For line 16, Fuel Used for Heat Rate Test , enter the fuel code or “M” for multiple fuels. Select appropriate energy source codes from Table 1i n these instructions. For generators driven by turbines using steam that is produced from waste heat or reject heat, report the original energy source used to produce the waste heat (reject heat).

Proposed Changes to Existing Generators (within the next 5 years)
19. For line 17a, indicate whether there are any planned capacity up-rates/de-rates, re-powering, other modifications, or generator retirements scheduled for the next 5 years.

20. For line 17b, enter the increase in capacity expected to be realized from the modification to the equipment. Enter the planned effective date (M M-YYYY) that the generator is scheduled to enter operation after the modification.
21. For line 17c, enter the decrease in capacity ex pected to be realized from the modification to the equipment. Enter the planned effective date (M M-YYYY) that the generator is scheduled to enter operation after the modification.
22. For line 17d, if a re-powering of the generator is planned, enter the new prime mover and new energy source, as well as the planned effective date (MM-YYYY) that the generator is scheduled to enter operation after the re-powering is complete.
23. For line 17e, enter the pl anned effective date (MM-YYYY) that the generator is scheduled to enter commercial operation after any other planne d change is complete, that is not included in lines 17b through 17d. Please provide details of the planned change in SCHEDULE 7, COMMENTS. Other planned changes may include a second up-rate or de-rate to a unit or a reactivation of a previously retired generator,
24. For line 17f, if the generator is expected to be re tired within the next 5 years, enter the planned effective date (MM-YYYY) of t hat scheduled retirement.

25. For line 18, Ability to Use Multiple Fuels , indicate if the combustion system that powers each generator has both:

 The regulatory permits necessary to ei ther co-fire fuels or fuel switch, and

 The equipment, including fuel storage facilities, in working order, necessary to either co-fire fuels or fuel switch.
If the answer to this question is “N o”, go to SCHEDULE 3. PART C.

Note: Co-firing means the simultaneous use of two or more fuels by a single combustion system to meet load. Fuel switching means the ability of a combustion system running on one fuel to replace that fuel in its entirety with a substitute fuel. Co-firing and fuel switching exclude the limited use of a second fuel for start-up or flame stabilization

. 26. For line 19, Ability to Co-Fire , indicate whether or not the combustion system that powers the9 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

generator has, in working order, the equipment necessary to co-fire fuels and the regulatory permits to co-fire fuels.

27. For line 20, Fuel Options for Co-Firing , indicate up to six fuels that can be co-fired. Select appropriate energy source codes from Table 1in these instructions. (Note: fuel options listed for co-firing must also be included under either “Predominant Energy S ource” (line 9), “Second Most Predominant Energy S ource” (line 11), or “Other Energy Sources (line 12).

28. For line 21, Ability to Co-Fire Oil and Natural Gas , indicate if the combustion system that powers the generator can co-fir e fuel oil with natural gas. If it cannot, skip to line 23.

29. For line 22, Ability to Co-Fire Oil , indicate whether or not the combustion system that powers the generator can run on 100 percent oil. If the ans wer to this question is yes, skip to line 23. If no, indicate the maximum percentage of the heat input to the combustion system (percent of MMBtu) that can be supplied by oil when co-firi ng with natural gas. Also provide the maximum output (summer net MW) that the unit can achieve, taking into account all applicable technical limits, when making the maximum use of oil and co-firing natural gas.

30. For line 23, Ability to Fuel Switch , indicate whether or not the combustion system that powers the generator has, in working order, the equipment necessary to fuel switch and the regulatory permits to fuel switch.

31. For line 24, Oil – Natural Gas Fuel Switching , (a) indicate whether or not the combustion system that powers the generator has, in wo rking order, the equipment necessary to switch between oil and natural gas and the regulatory pe rmits to switch between oil and natural gas are in effect. If no, go to line 26. If yes:
a) Can the unit switch between oil and natural gas? If No, skip to line 26.
b) Can the unit switch fuels while operating (i.e., without shutting down the unit)? Check “Yes” or “No”.
c) Enter the maximum output (summer net M W) that the unit can achieve, taking into account all applicable legal, regulatory, and technical limits, when running on natural
gas. d) Enter the maximum output (summer net MW) that the unit can achieve, taking into account all applicable legal, regulatory, and te chnical limits, when running on oil.
e) Enter how long it takes to switch the generator from using 100 percent natural gas to 100 percent oil.

32. For line 25, Limits on Oil-fired Operation , indicate whether or not there are factors that limit the operation of the generator (e.g., limits on maximum output, limits on annual operating hours), when running on 100 percent oil. Check all fa ctors that limit the ab ility of this generator to switch from natural gas to oil.

33. For line 26, Fuel Switching Options , enter the codes for up to six fuels, including (if applicable) oil and natural gas, which can be used as a sole source of fuel to power the generator. Select appropriate energy source code s from the table in thes e instructions. (Note: fuel options listed for fuel switching must al so be included under either “Predominant Energy Source” (line 9), “Second Most Predominant E nergy Source” (line 11), or “Other Energy Sources (line 12).

SCHEDULE 3. PART C. GENERATOR INFORMATION – PROPOSED GENERATORS

1. For line 1, Generator Nameplate Capacity , enter the highest value on the nameplate in megawatts rounded to the nearest tenth. If the nam eplate capacity is expressed in kilovolt amperes (kVA), convert to kilowatts by multiply ing the corresponding power factor by the kVA, divide by 1,000 to express in megawatts to the nea rest tenth. If the generator nameplate is not known at this time, estimate the nameplate rating for the generator and note this as an estimate in SCHEDULE 7. COMMENTS.10 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

2. For line 2, Net Capacity , enter the net summer and net winter capacities in megawatts rounded to the nearest tenth that are expected when the generator goes into commercial operation.

3. For line 3a, Reactive Power Output (MVAR) Corresponding to Net Summer Capacity for generators with nameplate capacity 10 MW or greater , using manufacturer provided design data , enter the lagging reactive power outpu t and the leading reactive power output that correspond to the net summer capacity ( line 2). A MVAR is a Mega Voltampere Reactive.

4. For line 3b, Reactive Power Output (MVAR) Corresponding to Net Winter Capacity for generators with nameplate capacity 10 MW or greater , using manufacturer provided design data , enter the lagging reactive power outpu t and the leading reactive power output that correspond to the net winter capacity (li ne 2). A MVAR is a Mega Voltampere Reactive.

5. For line 4, Status Code , enter one of the following status codes:

Status Code Status Code Description IP Planned new generator canceled, indefin itely postponed, or no longer in resource plan TS Construction complete, but not yet in commercial operation (including low power testing of nuclear units) P Planned for installation but regulatory approvals not initiated; Not under construction L Regulatory approvals pending. Not under construction but site preparation could be underway T Regulatory approvals received. Not under construction but site preparation could be underway. U Under construction, less than or equal to 50 percent complete (based on construction time to date of operation) V Under construction, more than 50 percent complete (based on construction time to date of operation) OT Other (describe in SCHEDULE 7, COMMENTS)

6. For line 5, Planned Original Effective Date, enter the month and year of the original effective date that: 1) the generator was scheduled to start operation after construction is completed. (Please note that this date does not change on ce it has been reported the first time.)

7. For line 6, Planned Current Effective Date, enter the month and year of the current effective date that the generator is scheduled to start operation.

8. For line 7, Will this generator be associated with a Combined Heat and Power system (fuel input is used to produce both electricity and useful thermal output)? Check either "Yes" or "No."

9. For line 8 , Will this generator be part of a solid fuel gasification system, check yes or no, as appropriate.

10. For line 9, indicate if this generator is part of a site that was previously reported by either your company or a previous owner as an indefinitely postponed or cancelled plant.

11. For line 10, Expected Predominant Energy Source , enter the energy source code for the energy source expected to be used in the larg est quantity (Btus) when the generator starts commercial operation. Select appropriate energy source codes from Table 1 in these instructions.
12. For line 11, if the expected predominant energy source for powering the generator is coal or petroleum coke , check all the types of technology and steam conditions that apply.

13. For line 12, Expected Second Most Predominant Energy Source, enter the energy source code for the energy sources expected to be used in the second largest quantity (Btus) when the generator starts commercial operation. Select appro priate energy source codes from Table 1 in these instructions. Do not include fuels expected to be used only for start-up or flame11 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

stabilization.

14. For line 13, Other Energy Source Options , enter the codes for other energy sources that will be used at the plant to power the generator. Ente r up to four codes in order of their expected predominance of use, where predominance is based on quantity of Btu(s) to be consumed. Select appropriate energy source codes from Table 1 in these instructions.

15. For line 14, If Energy Source is Wind , enter the number of turbines.

16. For line 15, Ability to Use Multiple Fuels , indicate if the combustion system that will power each generator will have both:

 The regulatory permits necessary to ei ther co-fire fuels or fuel switch, and

 The equipment, including fuel storage facilities, in working order, necessary to either co-fire fuels or fuel-switch. If the answer is “No” or “Undetermined”, go to SCHEDULE 4.

Note: Co-firing means the simultaneous use of two or more fuels by a single combustion system to meet load. Fuel switching means the ability of a combustion system running on one fuel to replace that fuel in its entirety with a substitute fuel. Co-firing and fuel switching exclude the limited use of a second fuel for start-up or flame stabilization

. 17. For line 16, Ability to Co-Fire , indicate whether or not the combustion system that will power the generator will have the equipment necessary to co-fire fuels and the regulatory permits to co-fire fuels. If no, skip to line 20.

18. For line 17, Fuel Options for Co-Firing , indicate up to six fuels that the generator will be designed to co-fire. Select appropriate energy so urce codes from Table 1 in these instructions. Note: fuel options listed for co-firing must al so be included under either “Predominant Energy Source” (line 9a), “Second Most Predominant E nergy Source” (line 11), or “Other Energy Sources (line 13).

19. For line 18, Ability to Co-Fire Oil and Natural Gas , indicate if the combustion system that powers the generator will be able to co-fire fuel oil with natural gas. If it cannot, skip to line 20.

20. For line 19, Ability to Co-Fire Oil , indicate whether or not t he combustion system that will power the generator can run on 100 percent oil. If yes, skip to line 20, if no, indicate the maximum percentage of the heat input to the comb ustion system (percent of MMBtu) that will be able to be supplied by oil when co-firing with natural gas. Also provide the maximum output (summer net MW) that the unit is expected to achi eve, taking into account all applicable legal, regulatory, and technical limits, when making the maximum use of oil and co-firing natural gas.

21. For line 20, Ability to Fuel Switch , indicate whether or not the combustion system that will power the generator will have the equipment nece ssary to fuel switch and have the regulatory permits to fuel switch. If no, then skip to SCHEDULE 4.

22. For line 21, Oil – Natural Gas Fuel Switching , (a) indicate whether or not the combustion system that will power the generator will have t he equipment necessary to switch between oil and natural gas and the regulatory permits in plac e to switch between oil and natural gas. If no, skip to line 23. If yes: a) Will the unit be able to switch between oil and natural gas? If No, skip to line 23
b) Will the unit be able to switch fuels whil e operating (i.e., without shutting down the unit)?
c) Enter the maximum output (summer net M W) that the unit can achieve, taking into account all applicable legal, regulatory, and tec hnical limits, when running on natural gas.
d) Enter the maximum output (summer net MW) that the unit can achieve, taking into account all applicable legal, regulatory, and te chnical limits, when running on oil.
e) Enter how long it takes to switch the gene rator from using 100 percent natural gas to 100 percent oil.12 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

23. For line 22, Limits on Oil-fired Operation , indicate whether or not t here will be factors that will limit the operation of the generator (e.g., lim its on maximum output, limits on annual operating hours), when running on 100 percent oil. Check a ll factors that will limit the ability of this generator to switch from natural gas to oil.

24. For line 23, Fuel Switching Options , enter the codes for up to six fuels, including (if applicable) oil and natural gas, that can be used as a sole source of fuel to power each generator. Select appropriate energy source codes from Table 1 in these instructions. Note: fuel options listed for fuel switching must also be included under ei ther “Predominant Energy Source” (line 10), “Second Most Predominant Energy Source” (line 12), or “Other Energy Sources (line 13).

SCHEDULE 4. OWNERSHIP OF GENERATORS OWNED JOINTLY OR BY OTHERS

1. Complete a separate SCHEDULE 4 for each existing and planned generator operated by the respondent that is, or will be, jointly owned; and each generator that the respondent operates but is 100 percent owned by another entity. Only the current or planned operator of jointlyowned generators should complete this schedule. The total percentage of ownership must equal 100 percent.

2. For each generator, specify the Plant Name, EIA Plant Code, and Generator Identification

, as listed on SCHEDULE 3. PART A.

3. Enter the Owner/Joint Owner Name and Address, in order of percentage of ownership, of each generator. Enter the EIA Code for the owner, if known, otherwise leave blank. Enter the Percent Owned to two decimal places, i.e., 12.5 percent as “12.50.” If a generator is 100 percent owned by an entity other than the operat or, then enter the percentage ownership as “100.00.”
4. Include any notes or comment s in SCHEDULE 7, COMMENTS.

SCHEDULE 5. NEW GENERATOR INTERCONNECTION INFORMATION

1. Complete a separate SCHEDULE 5 for each gener at or that started commercial operation during the data year (calendar year for which th is survey is being filed). For example, if Reporting is as of December 31, 2007, then data year is 2007.

2. For line 1, enter the Nam e of the Power Plant and the EIA Power Plant Code , as previously reported in SCHEDULE 3. PART A.

3. For line 2, enter the Ope rator’s Generator Identification , as previously reported in SCHEDULE 3. PART A.

4. For Line 3 , Date o f Actual Generator Interconnection, report the month and year that the interconnection was put into place.

5. For line 4 , Date of the Initial Interconn ection Request, report the month and year that the first request for interconnection was filed with the grid operator.

6. For line 5 , Interconn ection Site Location, specify the nearest city or town, and the state, where the interconnection equipment is located.

7. For line 6, Grid Voltage at the Point of Interc onn ection, specify the grid voltage, in kV, at the point of interconnection between the generator and the grid.

8. For line 7, Ow ner of the Transmission or Distri bution Facilities to Which Generator is Interconnected, provide the name of the owner of the tr ansmission or distribution facilities to which the generator is interco nnected. If the name of the owne r of the facilities is unknown, provide the name of t he contracting party.

9. For line 8, Total Cost Incurred for the Di rect, Physical Interconnection , specify the total13 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

cost incurred, in thousands of dollars, to accomplish the physical interconnection.

10. For line 9, Equipment Included in the Direct Interconnection Cost , check each of the types of equipment that are included in the cost amount reported on line 8. If there are significant types of equipment that are not included in t he list, please specify what additional equipment was needed for the interconnection in SCHEDULE 7, COMMENTS.
11. For line 10, (a) Total Cost for Other Grid Enhanc ements/Reinforcements Needed to Accommodate Power Deliveries From the Generator , specify the amount incurred, in thousands of dollars, for any other grid enhance ments or reinforcements that were needed to accommodate power deliveries from the new gener ator. If these costs, or some portion of these costs, will be repaid to your company at some time in t he future by the owner of the grid, or by the party with whom you contracted for the interconnection, please check “yes” in line 10b; otherwise, check “no” in 10b.

12. For line 11, Were Specific Transmission Use Rights Secured As A Result Of The Interconnection Costs Incurred , check yes or no.

SCHEDULE 6. BOILER INFORMATION (This information was formerly collected on F orm EIA-767, Steam-Electric Plant Operation and Design Report )

This schedule is required to be completed for:

 All existing organic-fueled or combustible renewa ble-fueled steam-electric plants with a total generator nameplate capacity of at least 10 megawatts; and

 All planned (5-year plans) new organic-fuel ed or combustible renewable-fueled steamelectric plants with a total generator namepl ate capacity of at least 10 megawatts.

Some parts of SCHEDULE 6 are not required to be completed for plants with a total generator nameplate capacity less than 100 megawatts. These par ts are specifically noted in the form and/or the instructions.

SCHEDULE 6. PART A. PLANT CONFIGURATION

1. Identification information should be a code commonly used by plant management for that equipment (e.g., “2,” “A101,” “7B,” etc.). Select a code for each piece of equipment and use it for that equipment throughout this form. The code should be a maximum of six characters long and should conform to codes reported for the sa me equipment (especially generators) on other EIA forms. Do not use blanks in the code. Do not enter “NA” for those lines that are not applicable. Plants less than 100 MW should only complete lines 1, 2, 3, and if applicable, 5 and 6. Planned equipment that is on order and expect ed to go into commercial service within 5 years must be reported. If two or more pi eces of equipment (e.g., two generators) are associated with a single boiler, report each id entification code, separated by commas, under the appropriate boiler. Do not change preprinted equipment identification.

2. For line 1, using each boiler as a starting point, complete the entire column under the boiler identification with the requested information on each piece of associated existing or planned equipment (e.g., generators, cooling systems, etc. ). Report waste-heat boilers with auxiliary firing. Do not report waste-heat boilers without auxiliary firing, or auxiliary house or start-up boilers. A waste-heat boiler is a boiler that receives all or a substantial portion of its energy input from the noncombustible exhaust gases of a separate fuel-burning process. Combined cycle units with auxiliary firing report the heat recovery steam gen erators (HRSGs) on line1.

3. For lines 2, 4, 5, 6, 7, and 8, if a piece of equipment (e.g., a generator or a cooling system) serves two or more boilers, repeat the identific ation information for that equipment under each appropriate boiler.14 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

4. For line 2, Associated Generator(s) , do not report auxiliary generators. Multiple generators operated as a single unit (e.g., cross compound and topping generators) should be identified as a group with one identification code. Combined cycle units with auxiliary firing report only the steam generators. Do not report the combusti on turbine portion of the combined cycle unit.

5. For line 3, Generator Associations with Boiler as Actual or Theoretical, indicate “A” for actual association during year or “T” for theoretical associations.

6. For line 4, Associated Cooling System(s) , a cooling system is an equipment system that provides water to the condensers and includes water intakes and outlets, cooling towers and ponds, pumps, and pipes. Identify a single plant cooling system, not separate systems, unless systems are physically separated, e.g., have separate water intake and outlet structures, where each system can be operated independently.

7. For line 5, Associated Flue Gas Particulate Collector(s) , if a combination particulate collector is associated with a single boiler, identify the collectors as a single group. If the particulate collector also removes sulfur dioxide, identify the unit in lines 5 and 6 using the same identification code.

8. For line 6, Associated Flue Gas Desulfurization Units(s) , for reporting purposes identify an associated flue gas desulfurization unit to inclu de all the trains (or modules) associated with a single boiler. If the flue gas desulfurization unit also removes particulate matter, identify the unit in lines 5 and 6 using the same identification code

9. For line 7, Associated Flue(s) , a flue is defined as an enclosed passageway within a stack for directing products of combustion to the atmosphere . For stacks with multiple flues, report in one column all flues that serve the boiler identified in line 1. Separate multiple entries with commas. If the stack has a single flue, use the stack identification for the flue identification.

10. For line 8, Associated Stack(s) , a stack is defined as a tall, vert ical structure containing one or more flues used to discharge products of combustion into the atmosphere.

SCHEDULE 6. PART B. BOILER INFORMATION – AIR EMISSION STANDARDS (DATA NOT REQUIRED FOR PLANTS LESS THAN 100 MW)

1. Complete a separate page for each existing or planned boiler.

2. For line 2a, Type of Boiler Standards Under Which the Boiler Is Operating, indicate the standards as described in the U.S. Environmental Protection Agency regulation under 40 CFR. Select from the following codes of the New Source Performance Standards (NSPS):

D Subpart D is the Standards of Performance for fossil-fuel fired steam boilers for which construction began after August 17, 1971. Da Subpart Da is the Standards of Performance for fossil-fuel fired steam boilers for which construction began after September 18, 1978. Db Subpart Db is the Standards of Performance for fossil-fuel fired steam boilers for which construction began after June 19, 1984.Dc Subpart Dc is the Standards of Performance for small industrial-commercialinstitutional steam generating units. N Not covered under New Source Performance Standards.

For line 2b, Is Boiler Operating Under a New Source Review (NSR) Permit?, check “Yes” or “No”; if Yes, enter date and identification number of the issued permit.

3. For line 3, Type of Statute or Regulation, select from the following the most stringent type of statute or regulation code: FD Federal ST State LO Local15 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

4. If there is no standard for nitrogen oxide emission s, report “NA” for line 3, column (c), and skip the remaining column (c) items.

5. Line 4, Emission Standard Specified , refers to the numeric value for the unit of measurement in line 5. If no numeric value is specified, report “NA.” For Sulfur Dioxide (column (b)), if the standard requires both an emission rate and a percent scrubbed, report both standards separated by a slash (e.g., 1.2/90 for emission st andards specified in line 4, column (b), and pounds of sulfur dioxide per million Btu in fuel/per cent sulfur removal efficiency (by weight) for units of measurement in line 5, column (b ), and indicate in a footnote on SCHEDULE 7.

6. For line 5, Unit of Measurement Specified , column (a), Particulate Matter, select from the following unit of measurement codes (PB* is the preferred measurement):

Code Unit of Measurement

OP Percent of opacity PB* Pounds of Particulate matter per million Btu in fuel PC Grains of particulate matter per standard cubic foot of stack gas PG Pounds of particulate matter per thousand pounds of stack gas PH Pounds of particulate matter emitted per hour UG Micrograms of particulate matter per cubic meter OT Other (specify in SCHEDULE 7, COMMENTS)

7. For line 5, Unit of Measurement Specified , column (b), Sulfur Dioxide, select from the following unit of measurement codes (D P* is the preferred measurement):

Code Unit of Measurement

DC Ambient air quality concentration of sulfur dioxide (parts per million) DH Pounds of sulfur dioxide emitted per hour DL Annual sulfur dioxide emission level less than a level in a previous year DM Parts per million of sulfur dioxide in stack gas DP* Pounds of sulfur dioxide per million Btu in fuel SB Pounds of sulfur per million Btu in fuel SR Percent sulfur removal efficiency (by weight) SU Percent sulfur content of fuel (by weight) OT Other (specify in SCHEDULE 7, COMMENTS)

8. For line 5, Unit of Measurement Specified , column (c), Nitrogen Oxides, select from the following unit of measurement codes (N P* is the preferred measurement):

Code Unit of Measurement

NH Pounds of nitrogen oxides emitted per hour NL Annual nitrogen oxides emission level less than a level in a previous year NM Parts per million of nitrogen oxides in stack gas NO Ambient air quality concentration of nitrogen oxides (parts per million) NP* Pounds of nitrogen oxides per million Btu in fuel OT Other (specify in SCHEDULE 7, COMMENTS)16 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

9. For line 6, Time Period Specified , select from the following codes to indicate the period over which measurements were averaged:

Code Time Period

NV Never to exceed FM 5 minutes SM 6 minutes FT 15 minutes OH 1 hour WO 2 hours TH 3 hours EH 8 hours DA 24 hours WA Weekly average MO 30 days ND 90 days YR Annual PS Periodic stack testing DT Defined by testing NS Not specified OT Other (specify in SCHEDULE 7, COMMENTS)

10. For line 7, Year Boiler Was or Is Expected to Be in Compliance With Federal, State and/or Local Regulations , if the boiler is currently in complianc e, enter the year the boiler came into compliance or the year of the regulation, whichev er came last. Report “9999” only if a revision of a governing regulation is being sought or no plans have been approved to bring the boiler into compliance.

11. For line 8, If Not in Compliance, Strategy for Compliance , column (c), select from the following strategy for compliance codes (separate multiple entries (up to three) with commas):

Code Strategy for Compliance

BO Burner out of service FR Flue gas recirculation LA Low excess air LN Low nitrogen oxide burner MS Currently meeting standard NC No plans to control OV Overfire air SE Seeking revision of governing regulation OT Other (specify in SCHEDULE 7, COMMENTS)17 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

12. For line 9, Existing, and line 10, Planned, Strategies to Meet the Sulfur Dioxide and Nitrogen Oxides Requirements of Title IV of the Clean Air Act Amendment of 1990

, column (b), select from the following strategy for compliance codes (separate multiple entries (up to three) with commas):

Code Strategy for Compliance (Sulfur Dioxide)

CF Fluidized Bed Combustor CU Control unit under Phase I extension plan IF Install flue gas desulfurization unit (other than Phase I extension plan) NC No change in historic operation of unit anticipated ND Not determined at this time RP Repower Unit SS Switch to lower sulfur fuel SU Designate Phase II unit(s) as substitution unit(s) TU Transfer unit under Phase I extension plan UC Decrease utilization - designate Phase II unit(s) as compensating unit(s) UE Decrease utilization - rely on energy conservation and/or improved efficiency US Decrease utilization - designate sulfur-free generators to compensate UP Decrease utilization - purchase power OT Other (specify in SCHEDULE 7, COMMENTS)

Code Strategy for Compliance (Nitrogen Oxides)

AA Advanced Overfire Air BF Biased Firing (alternative burners) CF Fluidized Bed Combustor FR Flue Gas Recirculation FU Fuel Reburning LA Low Excess Air LN Low NOx Burner NC No change in historic operation of unit anticipated ND Not determined at this time OV Overfire Air RP Repower Unit SC Slagging SN Selective Noncatalytic Reduction SR Selective Catalytic Reduction UE Decrease utilization - rely on energy conservation and/or improved efficiency OT Other (specify in SCHEDULE 7, COMMENTS)18 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

SCHEDULE 6. PART C. BOILER INFORMATION – DESIGN PARAMETERS (DATA NOT REQUIRED FOR PL ANTS LESS THAN 100 MW)

1. Complete for each existing or planned boiler. If a procurement contract has been signed for an upgrade or retrofit of a boiler: 1) complete a separate page for the existing boiler; 2) explain In SCHEDULE 7. COMMENTS how long the existi ng equipment will be out of service; and 3) using the same boiler identification, complete a separate SCHEDULE 6. PART C for the planned upgrade or retrofit. For line 2, verify boiler status. Select from the following codes.

Code Boiler Status

CN Cancelled (previously reported as “planned”) CO New unit under construction OP Operating (in commercial service or out of service less than 365 days) OS Out of service (365 days or longer)

PL Planned (on order and expected to go into commercial service within 5 years) RE Retired (no longer in service and not expected to be returned to service)

SB Standby (or inactive reserve); i.e., not normally used, but available for service

SC Cold Standby (Reserve); deactivated (usually requires 3 to 6 months to reactivate) TS Operating under test conditions (not in commercial service)

2. For line 3, Boiler Actual or Projected In-service Date , and line 4, Boiler Actual or Projected Retirement Date , the month-year date should be entered as follows: August 1959 as 8-1959. If the month is unknown, use the month of June as a default and enter a 6 before the year.19 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

3. For line 5, Boiler Manufacturer , select one code from the following boiler manufacturers’ codes:

Code Boiler Manufacturer AI Aalborg Industries AL Alstrom AS American Shack AT Applied Thermal Systems BR BROS BW Babcock and Wilcox DJ De John Coen bv CE Combustion Engineering CN Coen DL Deltak DS Doosan EC Econotherm ER Erie City Iron Works ET Entek FW Foster Wheeler GE General Electric GT Gotaverken HT Hitachi ID Indeck IH Ishikawajima-Harima Heavy Industries IN Innovative Steam Technology KL Keeler Dorr Oliver KP Kvaerner Pulping KW Kawasaki Heavy Industries ME Mitchell Engineering NB Nebraska Boiler NM NEM NT Nooter/Erickson PB Peabody PR Pyro Power RS Riley Stoker ST Sterling TM Tampell TS Toshiba VO Vogt Machine Company/Vogt Power WE Westinghouse WG Wiegl Engineering WI Wickes ZN Zurn OT Other (specify in SCHEDULE 7, COMMENTS)20 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

4. For line 6, Type of Firing Used with Primary Fuels , select from the following firing codes (separate multiple entries ( up to three) with commas):

Firing Code Firing Type Description

AF Arch firing CB Cell Burner CF Concentric Firing CY Cyclone firing DB Duct burner FB Fluidized bed firing FF Front firing OF Opposed firing RF Rear firing SF Side firing SS Spreader stoker TF Tangential firing VF Vertical firing (burners mounted on furnace ceiling) OT Other (specify in SCHEDULE 7, COMMENTS)
5. For lines 8 through 11, enter firing rate data for primary fuels as entered in line 13. Do not enter firing rate for startup or flame stabilization fuels. For waste-heat boilers with auxiliary firing, enter the firing rate for auxiliary firing an d complete line 12 for waste heat.

6. For line 12, a waste-heat boiler is a boiler that receives all or a substantial portion of its energy input from the noncombustible exhaust gase s of a separate fuel-burning process.

7. For line 13, Primary Fuels Used , see table of energy source (fuel) codes. Show design firing rates for each fuel in the associated lines 8, 9, 10, and 11. Do not include startup fuels. Predominance is based on Btu.

8. For line 16, Total Air Flow , report at standard temperature and pressure, i.e., 68 degrees Fahrenheit and one atmosphere pressure.

9. For line 17, Wet or Dry Bottom , enter “W” for Wet or “D” for Dry. Wet Bottom is defined as slag tanks that are installed at furnace throat to contain and remove molten ash from the furnace. Dry Bottom is defined as having no slag tanks at furnace throat area; throat area is clear; bottom ash drops through throat to bottom ash water h oppers. This design is used where the ash melting temperature is greater than the te mperature on the furnace wall, allowing for relatively dry furnace wall conditions.21 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

SCHEDULE 6. PART D. BOILER INFORMATIO N – NITROGEN OXIDE EMISSION CONTROLS

1. Complete a separate page for each existing or planned boiler.

2. For line 2, Nitrogen Oxide Control Status , select from the following status codes:

Code Control Status

CN Cancelled (previously reported as “planned”) CO New unit under construction OP Operating (in commercial service or out of service less than 365 days) OS Out of service (365 days or longer) OZ Operated during the ozone season (May through September)

PL Planned (on order and expected to go into commercial service within 5 years)

RE Retired (no longer in service and not expected to be returned to service)

SB Standby (or inactive reserve); i.e., not normally used, but available for service

SC Cold Standby (Reserve); deactivated (usually requires 3 to 6 months to reactivate) TS Operating under test conditions (not in commercial service)

3. For line 3, Low Nitrogen Oxide Control Process , select from the following low nitrogen oxide control processes (separate multiple ent ries (up to three) with commas):

Code Control Process

AA Advanced Overfire Air BF Biased Firing (alternative burners) CF Fluidized Bed Combustor FR Flue Gas Recirculation FU Fuel Reburning H2O Water Injection LA Low Excess Air LN Low NOx Burner NA Not Applicable NH3 Ammonia Injection OV Overfire Air SC Slagging SN Selective Noncatalytic Reduction SR Selective Catalytic Reduction STM Steam Injection OT Other (specify in SCHEDULE 7, COMMENTS)22 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

4. For line 4, Manufacturer of Low Nitrogen Oxide Control Burners , select from the following low nitrogen oxide control burner manufacturers:

Code Manufacturer

AB Advanced Burner Technologies ABB ABB AC Advanced Combustion Technology AL Alstom AP AirPol AT Applied Thermal Systems AU Applied Utility Systems (AUS) AZ Alzeta BC Babcock Borsig Power BM Bloom BMD Burns & McDonnell BW Babcock and Wilcox CE Combustion Engineering CM Combustion Components Associates Inc CN Coen CSI Combustion Solutions Inc. CT Callidus Technologies DB Deutsche-Babcock DD Damper Design Inc DQ Duquesne Light Company & Energy Systems Associates DV Davis DX Deltex EA Eagle Air EG Energy and Environmental Research Corp (EER) EL Electric power Technologies EP EPRI ET Entropy Technology and Environmental Construction Corp (ETEC) FB Faber FN Forney FT Fuel Tech Inc FW Foster Wheeler GE General Electric GR GE Energy and Environmental Research Corp (GEEER) HL Holman HT Hitachi IC International Combustion Limited ID Indeck IH In house JZ John Zink Todd Combustion/Todd Combustion KL Keeler Dorr Oliver MB Mitsui-Babcock MI Mitsubishi Industries MT Mobotec NA Not Applicable NB Nebraska Boiler Company NC Natcom, Inc NE NEI NL Noell, Inc PA Procedair PB Peabody PS Peerless Manufacturing Company23 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

Code Manufacturer

PL Pillard PX Phoenix Combustion RD Rodenhuis and Verloop RI Riley RJ RJM RR Rolls Royce RS Riley Stoker/Riley Power RV RV Industries SC Southern Company SW Siemans-Westinghouse TC Todd Combustion TEC Thermal Equipment Corporation TM Tampella TS Toshiba WG Weigel Engineering ZC Zeeco OT Other (specify in a footnote in SCHEDULE 7)

SCHEDULE 6. PART E. BOILER INFORMATION – MERCURY EMISSION CONTROLS

1. For line 2, if “Yes” is checked on line 1, Does This Boiler have Mercury Emission Controls

, mark all of the boxes that apply to the type of mercury emission controls used. If the type of control is “other”, please describe in SCHEDULE 7, COMMENTS.

SCHEDULE 6 PART F. COOLING SYSTEM INFORMATION – DESIGN PARAMETERS (DATA NOT REQUIRED FOR PLANTS LESS THAN 100 MW)

1. If a procurement contract has been signed for an upgrade or retrofit of a cooling system: 1) complete a separate page for the existing co oling system; 2) expl ain on SCHEDULE 7, COMMENTS how long the existing equipment will be out of service; and 3) using the same cooling system identification, complete a s eparate SCHEDULE 6. PART F, for the planned upgrade or retrofit.

2. For line 2, Cooling System Status , select from the following equipment status codes:

Code System Status

CN Cancelled (previously reported as “planned”) CO New unit under construction OP Operating (in commercial service or out of service less than 365 days) OS Out of service (365 days or longer) PL Planned (on order and expected to go into commercial service within 5 years) RE Retired (no longer in service and not expected to be returned to service) SB Standby (or inactive reserve); i.e., not normally used, but available for service) SC Cold Standby (Reserve); deactivated (usually requires 3 to 6 months to reactivate) TS Operating under test conditions (not in commercial service)24 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

3. For line 4, Type of Cooling System , select from the following cooling system codes (separate multiple entries (up to four) with commas):

Code Cooling System Description

DC Dry (air) cooling System HRC Hybrid: recirculating cooling pond (s) or canal(s) with dry cooling HRF Hybrid: recirculating with forced draft cooling tower(s) with dry cooling HRI Hybrid: recirculating with induced draft cooling tower(s) with dry cooling OC Once through with cooling pond(s) or canal(s) OF Once through, fresh water OS Once through, saline water RC Recirculating with cooling pond(s) or canal(s) RF Recirculating with forced draft cooling tower(s) RI Recirculating with induced draft cooling tower(s) RN Recirculating with natural draft cooling tower(s) OT Other (specify in a footnote on SCHEDULE 7)

4. For line 5, Source of Cooling Water , provide name of river, lake, etc. For line 5 and line 6, Design Cooling Water Flow Rate , if more than one source of cooling water is used by a cooling system, enter other sources in a footnote in SCHEDULE 7. If water is purchased, report “municipal.” If water is taken from wells, report “wells.” If source of water is “municipal” or “wells,” do not complete lines 19, 20, 21, and 22 and provide the total amount of water used at 100 percent load in line 5.



### 5. For lines 8, 9, and 10, a cooling pond is a natural or man-made body of water that is used for dissipating waste heat from power plants.

6. For line 12, Type of Towers , select from the following cooling tower codes (separate multiple entries (up to two) with commas):

Code Type of Towers

MD Mechanical draft, dry process MW Mechanical draft, wet process ND Natural draft, dry process NW Natural draft, wet process WD Combination wet and dry processes

7. For lines 15, 16, 17, and 18, enter the actual installed cost for the existing system or the anticipated cost to bring a planned system into commercial operation. Installed cost should include the cost of all major modifications. A major modification is any physical change which results in a change in the amount of air or wa ter pollutants or which results in a different pollutant being emitted.

8. For line 15, Total System , the cost should include amounts for items such as pumps, piping, canals, ducts, intake and outlet structures, dams and dikes, reservoirs, cooling towers, and appurtenant equipment. The cost of condensers should not be included.

9. For lines 19 through 22, if the cooling system is a zero discharge type (RC, RF, RI, RN), do not complete column (b). The intake and the outle t are the points where the cooling system meets the source of cooling water found on line 5. Fo r all longitude and latitude coordinates, provide degrees, minutes, and seconds.

10. For line 23, Enter Datum for the above Lati tude and Longitude, if Known; Otherwise Enter “UNK”:25 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

The longitude and latitude measurement for a location depends in part on the coordinate system (or “datum”) the measurement is keyed to. “Datum systems” used in the United States include the North American Datum 1927 (NAD27), North American Datum 1983 (NAD83) and World Geodetic Survey 1984 (WGS84).

(For background information on datums and their uses, see: http://biology.usgs.gov/index.html 

### ).

SCHEDULE 6. PART G. FLUE GAS PARTICULATE COLLECTOR INFORMATION

1. For line 3, Flue Gas Particulate Collector Status , select from the following equipment status codes:

Code Status

CN Cancelled (previously reported as “planned”) CO New unit under construction OP Operating (in commercial service or out of service within 365 days) OS Out of service (365 days or longer) PL Planned (on order or expected to go into commercial service within 5 years) RE Retired (no longer in service and not expected to be returned to service) SB Standby (or inactive reserve, i.e., not normally used, but available for service) SC Cold Standby (Reserve); deactivated. Usually requires 3 to 6 months to reactivate TS Operating under test conditions (not in commercial service).

2. For line 4, Type of Flue Gas Particulate Collector , select from the following flue gas particulate collector codes (for combination units, separate multiple entries (up to three) with commas):

Code Description

BS Baghouse, shake and deflate BP Baghouse, pulse BR Baghouse, reverse air EC Electrostatic precipitator, cold side, with flue gas conditioning EH Electrostatic precipitator, hot side, with flue gas conditioning EK Electrostatic precipitator, cold side, without flue gas conditioning EW Electrostatic precipitator, hot side, without flue gas conditioning MC Multiple Cyclone SC Single Cyclone WS Wet Scrubber OT Other (specify in a footnote on SCHEDULE 7 of the form).

3. For line 5, Installed Cost of Flue Gas Particulate Collector Excluding Land , enter the actual installed cost for the existing system or the anticipated cost to bring a planned system into commercial operation. Installed cost should in clude the cost of all major modifications. A major modification is any physical change which results in a change in the amount of air or water pollutants or which results in a different pollutant being emitted.

4. For lines 6, 7, 8 and 9 enter value for fuel. Enter range of values, if applicable.

SCHEDULE 6. PART H. FLUE GAS DESULFURIZATION UNIT INFORMATION – DESIGN PARAMETE RS

1. If a procurement contract has been signed for an upgrade or retrofit of a Flue Gas Desulfurization Unit: 1) complete a separate page for the existing unit; 2) explain on SCHEDULE 7, COMMENTS, how long the existi ng equipment will be out of service; and 3)26 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010
using the same FGD identification, complete a separate SCHEDULE 6. Pa rt H for the planned upgrade or retrofit. 1a. For line 2 , Flue Gas Desulfurization Unit Status , select from the following equipment status codes:

Code Status

CN Cancelled (previously reported as planned) CO New unit under construction OP Operating (in commercial service or out of service less than 365 days) OS Out of service (365 days or longer) PL Planned (on order and expected to go into commercial service within 5 years) RE Retired (no longer in service and not expected to be returned to service) SB Standby (or inactive reserve, i.e., not normally used by available for service) SC Cold Standby (Reserve); deactivated. Usually requires 3 to 6 months to activate TS Operating under test conditions (not in commercial service) If the code selected is “OP” complete lines 4 through 14, otherwise do not complete these lines.

2. For line 4, Type of Flue Gas Desulfurization Unit , select from the following FGD unit codes (for combination units, separate multip le entries (up to four) with commas):

Code Type of Unit

BR Jet Bubbling Reactor CD Circulating Dry Scrubber DP Dry Powder Injection type MA Mechanically aided type PA Packed type SD Spray dryer type SP Spray type TR Tray type VE Venture type

3. For line 5, Type of Sorbent , select from the following sorbent codes (separate multiple entries (up to four) with commas):

Code Type of Sorbent

AF Alkaline fly ash CC Calcium carbide slurry CEF CE filtrate CSH Caustic sodium hydroxide DB Dibasic acid DL Dolomitic limestone LA Lime and alkaline fly ash LF Limestone and alkaline fly ash LI Lime LS Limestone MO Magnesium oxide SA Soda ash SC Sodium carbonate SL Soda liquid SS Sodium sulfite OT Other (specify in SCHEDULE 7)27 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

4. For line 7, Flue Gas Desulfurization Unit Manufacturer, select one code from the following flue gas desulfurization unit manufacturer codes:

Code Manufacturer

AA Advanced Air Technologies ABB ABB Environmental Systems AL Alstom AM American Air Filter AP Airpol API Air Pollution Industries AX Amerex Industries BE Bact Engineering BI Bleco Industries BL Bechtel Corporation BMC Burns and McDonnell BO Bionomics BPC Belco Pollution Control BPE Babcock Power Environmental Inc (BPEI) BT Belco Technologies BW Babcock and Wilcox CA Chiyoda CC Chemico CE Combustion Engineering CO Combustion Equipment DA Delta Conveying Systems DC Ducon DM Davey McKee EE Environmental Engineering EEC Environmental Elements Corporation

EI Entoleter Inc FL Flakt, Inc FM FMC FW Foster Wheeler GE General Electric GF Grafwolff HA Hamon IH In House Design JO Joy Manufacturing KC Korea Cottrell KE M.W. Kellogg KR Krebs Equipment LLB Lurgi Lentjes Bischoff MB Mobotek MC Macrotek MG McGill Air Clean MI Mitsubishi Industry MX Marselex NPA Neptune Airpol NSP NSP PA Procedair PB Peabody PR Pyro Power PU Pure Air RC Research Cottrell RS Riley Stoker SHU Saarberg-Holter Umwelttechnick GmbH SK Schenck Weigh Feeders TC Turbosonic TH Thyssen/CEA TK Turbotak28 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

Code Manufacturer

TP Tempala Power UE Utility Engineering UM United McGill UO Universal Oil Products WAPC Wheelabrator Air Pollution Control

ZU Zurn OT Other (specify in a footnote in SCHEDULE 7)

5. For line 15, Removal Efficiency for Sulfur Dioxide , report the removal efficiency as the percent by weight of gases removed from the flue gas.

6. For lines 20, 21, 22, and 23, enter the actual installed costs for the existing systems or the anticipated costs to bring a planned system into commercial operation. Installed cost should include the cost of all major modifications. A major modification is any physical change which results in a change in the amount of air or wa ter pollutants or which results in a different pollutant being emitted. The total (line 23) will be the sum of lines 20, 21, and 22 which includes any other costs pertaining to the installation of the unit.

SCHEDULE 6. PART I. STACK AND FLUE INFORMATION – DESIGN PARAMETERS (DATA NOT REQUIRED FOR PL ANTS LESS THAN 100 MW)

1. If a procurement contract has been signed for an upgrade or retrofit of a stack or flue: 1) complete a page for the existing stack or flue; 2) explain on SCHEDULE 7, COMMENTS, how long the existing structure will be out of se rvice; and 3) using the same flue and stack identifications, complete a separate SCHEDULE 6. Part I for the planned upgrade or retrofit.

2. For line 1, Flue ID , and line 2 , Stack ID , there must be an entry. If there is only one flue, also use the stack ID as the flue ID. Identificat ion codes must be the same as reported on SCHEDULE 6. PART A.

3. For line 3, Stack (or Flue) Actual or Projected In-Service Date of Commercial Operation

, the month-year should be entered as follows: e.g., August 1959 as 08-1959.

4. For line 4, Status of Stack , select one from the following equipment status codes:

Status Code

CN Cancelled (previously reported as “planned”) CO New unit under construction OP Operating (in commercial service or out of service within 365 days) OS Out of service (365 days or longer) PL Planned (on order or expected to go into commercial service within 5 years) RE Retired (no longer in service and not expected to be returned to service) SB Standby (or inactive reserve, i.e., not normally used, but available for service) SC Cold Standby (Reserve); deactivated. Usually requires 3 to 6 months to reactivate TS Operating under test conditions (not in commercial service).

5. For lines 7 and 8, the rate should be approxima tely equal to the cross-sectional area multiplied by the velocity, multiplied by 60.

6. For lines 13 and 14, seasonal average flue gas exit temperatures should be reported in29 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

degrees Fahrenheit, based on the arithmetic m ean of measurements during operating hours. Summer season includes June, July, and August. Winter season includes January, February, and December.

7. For line 15, Source , enter “M” for measured or “E” for estimated.

8. For lines 16 and 17, Stack Location , enter the latitude and longitude in degrees, minutes, and seconds.

9. For line 18, Enter Datum for Latitude and Longi tude, if Known; Otherwise Enter “UNK”:

The longitude and latitude measurement for a location depends in part on the coordinate system (or “datum”) the measurement is keyed to. “Datum systems” used in the United States, include the North American Datum 1927 (NAD27), North American Datum 1983 (NAD83) and World Geodetic Survey 1984 (WGS84).

If you know the datum system for the plant longi tude and latitude, enter the system name (e.g., NAD83) on line 7. If you do not know the datum system used, enter UNK.30 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

SCHEDULE 7. COMMENTS This schedule provides additional space for comments. Please identify schedule and line number and identifying information (e.g., plant code, boiler id, generator id) for each comment.



### Table 1. Energy Source Codes and Heat Content

Higher Heating Value” Range (Million Btu per Unit of Fuel Energy Source

Code Unit Label MMBtu Lo wer MMBtu Upper Energy Source Description Fossil Fuels
BIT tons 20 29 Anthracite Coal and Bituminous Coal LIG tons 10 14.5 Lignite Coal

Coal and Coal Synfuel SC tons 10 35 Coal Synfuel. Coal-based solid fuel that has been processed by a coal synfuel plant; and coal-based fuels such as briquettes, pellets, or extrusions, which are formed from fresh or recycled coal and binding materials. SUB tons 15 20 Subbituminous Coal WC tons 6.5 16 Waste/Other Coal. Including anthracite culm, bituminous gob, fine coal, lignite waste, waste coal. DFO barrels 5.5 6.2 Distillate Fu el Oil. Including Diesel, No. 1, No. 2, and No. 4 Fuel Oils. JF barrels 5 6 Jet Fuel KER barrels 5.6 6.1 Kerosene

Petroleum PC tons 24 30 Petroleum Coke Products RFO barrels 5.8 6.8 Residual Fuel Oil. Including No. 5, No. 6 Fuel Oils, and Bunker C Fuel Oil. WO barrels 3.0 5.8 Waste/Othe r Oil. Including Crude Oil, Liquid Butane, Liquid Propane, Oil Waste, Re-Refined Motor Oil, Sludge Oil, Tar Oil, or other petroleum-based liquid wastes. BFG Mcf 0.07 0.12 Blast Furnace Gas

Natural

Gas NG Mcf 0.8 1.1 Natural Gas

And Other

Gases OG Mcf 0.32 3.3 Other Gas. Specify in SCHEDULE 7, COMMENTS. PG Mcf 2.5 2.75 Gaseous Propane

SG Mcf 0.2 1.1 Synthetic Gas, other than coal-derived SGC Mcf 0.2 0.3 Synthetic Gas, derived from coal31 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010 Higher Heating Value” Range (Million Btu per Unit of Fuel Energy Source

Code Unit Label MMBtu Lo wer MMBtu Upper Energy Source Description Renewable Fuels
AB tons 9 18 Agricultural Crop Byproducts/Straw/Energy Crops MSW tons 9 12 Municipal Solid Waste OBS tons 8 25 Other Biomass Solids Specify in SCHEDULE 7, COMMENTS. Solid Renewable Fuels WDS tons 7 18 Wood/Wood Waste Solids. Including paper pellets, railroad ties, utility poles, wood chips, bark, & wood waste solids. OBL barrels 3.5 4.0 Other Biomass Liquids. Specify in SCHEDULE 7, COMMENTS. SLW tons 10 16 Sludge Waste BLQ tons 10 14 Black Liquor Liquid Renewable Fuels WDL barrels 8 14 Wood Wast e Liquids excluding Black Liquor, includes red liquor, sludge wood,spent sulfite liquor, and other woodbased liquids LFG Mcf 0.3 0.6 Landfill gas Gaseous Renewable Fuels OBG Mcf 0.36 1.6 Other Biomass Gas, includes digestor gas, methane, and other biomass gases. Specify in SCHEDULE 7, COMMENTS. SUN N/A 0 0 Solar WND N/A 0 0 Wind GEO N/A 0 0 Geothermal Other Renewable

Energy Sources WAT N/A 0 0 Water at a conventional hydroelectric turbine All Other Energy Sources PUR N/A 0 0 Purchased Steam All Other

Energy Sources WH N/A 0 0 Waste heat not directly attributed to an energy source. WH should only be reported where the energy source for the waste heat is undetermined. TDF tons 16 32 Tire-derived Fuels NUC Nuclear including Uranium, Plutonium, Thorium OTH N/A 0 0 Specify in SCHEDULE 7, COMMENTS.32 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010 Table 2. Commonly Used North American I ndustry Classification System (NAICS) Codes Code Description AGRICULTURE, FORESTRY, AND FISHING 111 Agriculture production - crops 112 Agriculture production, livestock and animal specialties 113 Forestry 114 Fishing, hunting, and trapping 115 Agricultural services MINING 211 Oil and gas extraction 2121 Coal mining 2122 Metal mining 2123 Mining and quarrying of nonmetallic minerals except fuels 23 CONSTRUCTION MANUFACTURING 311 Food and kindred products 3122 Tobacco products 314 Textile and mill products 315 Apparel and other finished products ma de from fabrics and similar materials 316 Leather and leather products 321 Lumber and wood products, except furniture 322 Paper and allied products (other than 322122 or 32213) 322122 Paper mills, except building paper 32213 Paperboard mills 323 Printing and publishing 324 Petroleum refining and related industries (other than 32411) 32411 Petroleum refining 325 Chemicals and allied products (other than 325188, 325211, 32512, or 325311) 32512 Industrial organic chemicals 325188 Industrial inorganic chemicals 325211 Plastic materials and resins 325311 Nitrogenous fertilizers 326 Rubber and miscellaneous plastic products 327 Stone, clay, glass, and concrete products (other than 32731) 32731 Cement, hydraulic 331 Primary metal industries (other than 331111 or 331312) 331111 Blast furnaces and steel mills 331312 Primary aluminum 332 Fabricated metal products, except machinery and transportation equipment 333 Industrial and commercial equipment and components except computer equipment 3345 Measuring, analyzing, and controlling instruments, photographic, medical, and optical goods, watches and clocks 335 Electronic and other electrical equipment and components except computer equipment 336 Transportation equipment 337 Furniture and fixtures 339 Miscellaneous manufacturing industries TRANSPORTATION AND PUBLIC UTILITIES 482 Railroad transportation 485 Local and suburban transit and interurban highway passenger transport 484 Motor freight transportation and warehousing
22 Electric, gas, and sanitary services33 Code Description 2212 Natural gas transmission 2213 Water supply 22131 Irrigation systems 22132 Sewerage systems 481 Transportation by air 482 Railroad Transportation 483 Water transportation 484 Motor freight transportation and warehousing 485 Local and suburban transit and interurban highway passenger transport 486 Pipelines, except natural gas 487 Transportation services 513 Communications 562212 Refuse systems 421 to 422 WHOLESALE TRADE 441 to 454 RETAIL TRADE 521 to 533 FINANCE, INSURANCE, AND REAL ESTATE SERVICES 512 Motion pictures 514 Business services 514199 Miscellaneous services 541 Legal services 561 Engineering, accounting, research , management, and related services 611 Education services 622 Health services 624 Social services 712 Museums, art galleries, and botanical and zoological gardens 713 Amusement and recreation services 721 Hotels 811 Miscellaneous repair services 8111 Automotive repair, services, and parking 812 Personal services 813 Membership organizations 814 Private Households 92 PUBLIC ADMINISTRATION34 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT INSTRUCTIONS Form Approved OMB No. 1905-0129 Approval Expires: 

### 12/31/2010

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-860 by thos e 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 mo re than $2,750 per day for ea ch civil violation, or a fine of not more than $5,000 per day for each crim inal 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 fo r 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 6.0 hours per response for respondents without environmental information and 11.3 hours per response for respondents with environmental information, includi ng the time for reviewing instructions, searching existing data sources, gathering and maintaining t he 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, includin g suggestions for reducing this burden, to the Energy Information Administration, Statistics and Methods Group, EI-70, 1000 Independence Avenue S.W., Forrestal Building, Washington, DC 20585-0670; and to the O ffice 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-860 will be treated as non-sensitive and may be publicly released in identifiable form except as noted below.
The information reported for the data element “Tested Heat Rate” cont ained on SCHEDULE 3. PART B will be treated as sensitive and protected to t he extent that it satisfies the criteria for exemption under the Freedom of Information Act (FOIA), 5 U.S.C. §552, the Department of Energy regulations, 10 C.F.R. §1004.11, implementing the FOIA, and the Trade Secrets Act, 18 U.S.C. §1905.
The Federal Energy Administration Act requires th e EIA to provide company-specific data to other Federal agencies when requested for official use. The information reported on this form may also be made available, upon request, to another component of the Department of Energy (DOE); to any Committee of Congress, the Government Accountability Office, or other Federal agencies authorized by law to receive such information. A court of competent jurisdiction may obtain this information in response to an order. The information may be used for any nonstatistical purposes such as administrative, regulatory, law enforcement, or adjudicatory purposes.
Disclosure limitation procedures are applied to the sensitive statistical data published from SCHEDULE 3. PART B, Tested Heat Rate, on Form EI A-860 to ensure that the risk of disclosure of identifiable information is very small.35 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

NOTICE: This report is mandatory under the Federal Energy Administration Ac t 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 s ee the provision on sanctions and the prov ision concerning the confidentiality of information in t he instructions. Title 18 USC 1001 makes it a criminal offe nse 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:_______________________

_______ Address:___________________ Telephone (include extension):_ _____________ Fax:__

________________ E-mail:____________

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

____ Addr ess:_______________________ Telephone (include extension):_ _____________ Fax:__

________________ E-mail:____________

____________________ Report For Operator Name:_____

________________________________________ Operator ID :_________________ Reporting as of December 31 Year:________________
Operator and Preparer Information
Legal Name of Operator:

________________________________________________ Current Address of Principal Business Office of Plant Operator: ________________________________________________

Preparer's Legal Name (If Different From Operator’s Legal Name): ________________________________________________ Current Address of Preparer's Office (If Different From Current Address of Principal Business Office of Entity): ________________________________________________ Is the Operator an Electric Utility? [ ] Yes [ ] No

For questions or additional information about t he Form EIA-860, contact the Survey Managers:



### Patricia Hutchins Telephone Number: (202) 586-1029 FAX Number: (202) 287-1960 E-mail: Patricia.Hutchins@eia.doe.gov36 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:____________________

_____________________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 2. POWER PLANT DATA
(EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

LINE PLANT 1. (EXISTING OR PLANNED FOR INITIA L COMMERCIAL OPERATION WITHIN 5 YEARS)

1 Plant Name EIA Plant Code

2 Street Address

3 County Name City Name:

4 State

5 Zip Code

6 Latitude (Degrees, Minutes, Seconds) Longitude (Degrees, Minutes, Seconds)

7 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”

8 NERC Region

9 Name of Water Source (For Purpose of Cooling or Hydroelectric)

10 Steam Plant Status [ ] existing [ ] planned [ ] retired

11 Steam Plant Type [ ] Organic 100 MW or more generator nameplate capacity [ ] Organic 10 MW or Greater to Under 100 MW generator nameplate capacity

12 Primary Purpose of the Plant (North American Industry Classification System Code)

13 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Cogenerator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

14 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Small Power Producer status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

15 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Exempt Wholesale Generator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

16 Owner of Transmission and/or Distribution Facilities: Enter the name of the owner of the transmission or distribution facilities to which the plant is interc onnected and the grid voltage (in kilovolts) at the point of interconnection.

__________________________________________________________________ Grid Voltage (kV):37 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_____

________________________ ____________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 2. POWER PLANT DATA
(EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

LINE PLANT 2. (EXISTING OR PLANNED FOR INIT IAL COMMERCIAL OPERATION WITHIN 5 YEARS)

1 Plant Name EIA Plant Code

2 Street Address

3 County Name City Name:

4 State

5 Zip Code

6 Latitude (Degrees, Minutes, Seconds) Longitude (Degrees, Minutes, Seconds)

7 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”

8 NERC Region

9 Name of Water Source (For Purpose of Cooling or Hydroelectric)

10 Steam Plant Status [ ] existing [ ] planned [ ] retired

11 Steam Plant Type [ ] Organic 100 MW or more generator nameplate capacity [ ] Organic 10 MW or Greater to Under 100 MW generator nameplate capacity

12 Primary Purpose of the Plant (North American Industry Classification System Code)

13 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Cogenerator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

14 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Small Power Producer status? If Yes, provide all QF docket number(s). Separate by using a comma.

_________________________________________ [ ] Yes [ ] No

15 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Exempt Wholesale Generator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

16 Owner of Transmission and/or Distribution Facilities: Enter the name of the owner of the transmission or distribution facilities to which the plant is interconnected and the grid voltage (in kilovolts) at the point of interconnection.

__________________________________________________________________ Grid Voltage (kV):38 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:____________________

_____________________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 2. POWER PLANT DATA
(EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

LINE PLANT 3. (EXISTING OR PLANNED FOR INITIA L COMMERCIAL OPERATION WITHIN 5 YEARS)

1 Plant Name EIA Plant Code

2 Street Address

3 County Name City Name:

4 State

5 Zip Code

6 Latitude (Degrees, Minutes, Seconds) Longitude (Degrees, Minutes, Seconds)

7 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”

8 NERC Region

9 Name of Water Source (For Purpose of Cooling or Hydroelectric)

10 Steam Plant Status [ ] existing [ ] planned [ ] retired

11 Steam Plant Type [ ] Organic 100 MW or more generator nameplate capacity [ ] Organic 10 MW or Greater to Under 100 MW generator nameplate capacity

12 Primary Purpose of the Plant (North American Industry Classification System Code)

13 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Cogenerator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

14 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Small Power Producer status? If Yes, provide all QF docket number(s). Separate by using a comma.

_________________________________________ [ ] Yes [ ] No

15 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Exempt Wholesale Generator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

16 Owner of Transmission and/or Distribution Facilities: Enter the name of the owner of the transmission or distribution facilities to which the plant is interconnected and the grid voltage (in kilovolts) at the point of interconnection.

__________________________________________________________________ Grid Voltage (kV):39 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:____________________

_____________________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 2. POWER PLANT DATA
(EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

LINE PLANT 4. (EXISTING OR PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

1 Plant Name EIA Plant Code

2 Street Address

3 County Name City Name:

4 State

5 Zip Code

6 Latitude (Degrees, Minutes, Seconds) Longitude (Degrees, Minutes, Seconds)

7 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”

8 NERC Region

9 Name of Water Source (For Purpose of Cooling or Hydroelectric)

10 Steam Plant Status [ ] existing [ ] planned [ ] retired

11 Steam Plant Type [ ] Organic 100 MW or more generator nameplate capacity [ ] Organic 10 MW or Greater to Under 100 MW generator nameplate capacity

12 Primary Purpose of the (North American Industry Classification System Code)

13 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Cogenerator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

14 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Small Power Producer status? If Yes, provide all QF docket number(s). Separate by using a comma.

_________________________________________ [ ] Yes [ ] No

15 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Exempt Wholesale Generator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

16 Owner of Transmission and/or Distribution Facilities: Enter the name of the owner of the transmission or distribution facilities to which the plant is interconnected and the grid voltage (in kilovolts) at the point of interconnection.

__________________________________________________________________ Grid Voltage (kV):40 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:____________________

_____________________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 2. POWER PLANT DATA
(EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

LINE PLANT 5. (EXISTING OR PLANNED FOR INITIA L COMMERCIAL OPERATION WITHIN 5 YEARS)

1 Plant Name EIA Plant Code

2 Street Address

3 County Name City Name:

4 State

5 Zip Code

6 Latitude (Degrees, Minutes, Seconds) Longitude (Degrees, Minutes, Seconds)

7 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”

8 NERC Region

9 Name of Water Source (For Purpose of Cooling or Hydroelectric)

10 Steam Plant Status [ ] existing [ ] planned [ ] retired

11 Steam Plant Type [ ] Organic 100 MW or more generator nameplate capacity [ ] Organic 10 MW or Greater to Under 100 MW generator nameplate capacity

12 Primary Purpose of the Plant (North American Industry Classification System Code)

13 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Cogenerator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

14 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Small Power Producer status? If Yes, provide all QF docket number(s). Separate by using a comma.

_________________________________________ [ ] Yes [ ] No

15 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Exempt Wholesale Generator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

16 Owner of Transmission and/or Distribution Facilities: Enter the name of the owner of the transmission or distribution facilities to which the plant is interc onnected and the grid voltage (in kilovolts) at the point of interconnection.

__________________________________________________________________ Grid Voltage (kV):41 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_____

________________________ ____________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 2. POWER PLANT DATA
(EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

LINE PLANT 6. (EXISTING OR PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

1 Plant Name EIA Plant Code

2 Street Address

3 County Name City Name:

4 State

5 Zip Code

6 Latitude (Degrees, Minutes, Seconds) Longitude (Degrees, Minutes, Seconds)

7 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”

8 NERC Region

9 Name of Water Source (For Purpose of Cooling or Hydroelectric)

10 Steam Plant Status [ ] existing [ ] planned [ ] retired

11 Steam` Plant Type [ ] Organic 100 MW or more generator nameplate capacity [ ] Organic 10 MW or Greater to Under 100 MW generator nameplate capacity

12 Primary Purpose of the Plant (North American Industry Classification System Code)

13 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Cogenerator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

14 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Small Power Producer status? If Yes, provide all QF docket number(s). Separate by using a comma.

_________________________________________ [ ] Yes [ ] No

15 Does this plant have Federal Energy Regulatory Commission (FERC) Qualifying Facility (QF) Exempt Wholesale Generator status? If Yes, provide all QF docket number(s). Separate by using a comma.

________________________________________ [ ] Yes [ ] No

16 Owner of Transmission and/or Distribution Facilities: Enter the name of the owner of the transmission or distribution facilities to which the plant is interc onnected and the grid voltage (in kilovolts) at the point of interconnection.

__________________________________________________________________ Grid Voltage (kV):42 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:____________________

_____________________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 3. GENERATOR INFORMATION
(EXISTING GENERATORS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS)

LINE 

### SCHEDULE 3. PART A. GENERATOR INFORMATION – GENERATORS
(COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT)
1 Plant Name

2 EIA Plant Code
Generator (a) Generator (b) Generator (c)
3 Operator’s Generator Identification

4 Associated Boiler Identifications for organic-fueled steam generators, including heat recovery generators with duct-firing, (for plants with a total generator nameplate capacity of 10 MW or greater) 1 ____ 5 ___ 2 ____ 6 ___ 3 ____ 7 ___ 4 ____ 8 ___ 1 ____ 5 ___ 2 ____ 6 ___ 3 ____ 7 ___ 4 ____ 8 ___ 1 ____ 5 ___ 2 ____ 6 ___ 3 ____ 7 ___ 4 ____ 8 ___

5 Prime Mover Code

6 Unit Code (Required for combined cycle generators)

7 Ownership Code

8 Is this generator an electric utility or non-utility generator? [ ] Electric Utility [ ] Non-Utility [ ] Electric Utility [ ] Non-Utility [ ] Electric Utility [ ] Non-Utility

9 Date of Sale If Sold (MM-YYYY)

10 Can This Generator Deliver Power to the Transmission Grid? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

11 For Combined-cycle Steam Turbines, (prime mover = CA, CS or CC) does unit have duct-burners? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No43 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:

_____________________ _______________ Operator ID:___________ Plant Name:_____________

_____________________ _____ Plant Code:___________ Reporting as of December 31 Year:________________ SCHEDULE 3. PART B. GENERATOR INFORMATION – EXISTING GENERATORS
(COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT) Generator (a) Generator (b) Generator (c)

1 Generator Nameplate Capacity (Megawatts)
Summer 2 Net Capacity (Megawatts) Winter Lagging

3a Reactive Power Output (MVAR) Corresponding to Net Summer Capacity For generators with nameplate capacity 10 MW or greater Leading

Lagging

3b Reactive Power Output (MVAR) Corresponding to Net Winter Capacity For generators with nameplate capacity 10 MW or greater Leading

4 Status Code

5 If Status Code is Standby, can the generator be synchronized to the grid? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

6 Initial Date of Operation (MMYYYY)

7 Retirement Date (MM-YYYY)

8 Is this generator associated with a Combined Heat and Power system (fuel input is used to produce both electricity and useful thermal output)? If Yes: Is this generator part of a topping cycle or a bottoming cycle? [ ] Yes [ ] No

[ ] Topping [ ] Bottoming [ ] Yes [ ] No

[ ] Topping [ ] Bottoming [ ] Yes [ ] No

[ ] Topping [ ] Bottoming

ENERGY SOURCES

9 Predominant Energy Source

9a If coal-fired or petroleum coke fired, check all combustion technologies that apply to the associated boiler(s) and steam conditions [ ] Pulverized coal [ ] Fluidized Bed [ ] Sub-critical [ ] Super-critical [ ] Ultra super-critical [ ] Carbon-capture [ ] Pulverized coal [ ] Fluidized Bed [ ] Sub-critical [ ] Super-critical [ ] Ultra super-critical [ ] Carbon-capture [ ] Pulverized coal [ ] Fluidized Bed [ ] Sub-critical [ ] Super-critical [ ] Ultra super-critical [ ] Carbon-capture

10 Start-up and flame stabilization energy sources (prime mover = ST (steam units only)

11 Second Most Predominant Energy Source44 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:

_____________________ _______________ Operator ID:___________ Plant Name:_____________

_____________________ _____ Plant Code:___________ Reporting as of December 31 Year:________________ SCHEDULE 3. PART B. GENERATOR INFORMATION – EXISTING GENERATORS
(COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT) Generator (a) Generator (b) Generator (c)

a b c d a b c d a b c d

12 Other Energy Sources Enter up to four codes in order of expected quantity used (measured in BTUs).

13 Is this generator part of a Solid Fuel Gasification system? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

14 If Energy Source is Wind, Enter the Number of Turbines

15 Tested Heat Rate (Btu/Kilowatthour)

16 Fuel Used for Heat Rate Test (enter fuel code or M for multiple fuels)
PROPOSED CHANGES TO EXI STING GENERATORS (WITHIN THE NEXT 5 YEARS)

17a Are there any planned modifications to this generator, including retirement? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

17b Planned uprates: 1. Incremental Net summer capacity (MW)
2. Incremental Net winter capacity (MW)
3. Planned Effective Date MM-YYYY

17c Planned derates: 1. Incremental Net summer capacity (MW)
2. Incremental Net winter capacity (MW)
3. Planned Effective Date MM-YYYY

17d Planned Repowering: 1. New Prime Mover

2. New Energy Source

3. Planned Effective Date MM-YYYY

[ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

17e Other Modifications? (explain in Notes)

Planned Effective Date MMYYYY45 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:

_____________________ _______________ Operator ID:___________ Plant Name:_____________

_____________________ _____ Plant Code:___________ Reporting as of December 31 Year:________________ SCHEDULE 3. PART B. GENERATOR INFORMATION – EXISTING GENERATORS
(COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT) Generator (a) Generator (b) Generator (c)

17f Planned Generator Retirement Planned Effective Date MM-YYYY



## FUEL SWITCHING AND CO-FIRING CAPABILITY

[ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

18 Ability to use multiple fuels Does the combustion system that powers this generator have 1) the regulatory permits, and 2), the equipment (including fuel storage facilities), in working order

, necessary to either co-fire fuels or to fuel switch? If No, skip to SCHEDULE 3 Part C. If No, skip to SCHEDULE 3 Part C. If No, skip to SCHEDULE 3 Part C.

19 Ability to Co-Fire
Can the unit co-fire fuels? (Note: co-firing excludes the limited use of an alternative fuel for startup or flame stabilization.) [ ] Yes [ ] No If No, skip to line 23. [ ] Yes [ ] No If No, skip to line 23. [ ] Yes [ ] No If No, skip to line 23.

a b c a b c a b c

d e f d e f d e f 20 Fuel Options for Co-Firing Enter the codes for up to six fuels that can be co-fired:

21 Ability to Co-Fire Oil and Natural Gas Can the unit co-fire fuel oil with natural gas? [ ] Yes [ ] No If No, skip to line 23. [ ] Yes [ ] No If No, skip to line 23. [ ] Yes [ ] No If No, skip to line 23.

22 Ability to Co-Fire Oil
a. Can the unit run on 100% oil? If Yes, skip to Line 23. If No, what is the :

 Maximum oil heat input (% of MMBtus) when co-firing with natural gas?

 Maximum output (net summer MW) achievable, when making the maximum use of oil and co-firing natural gas? [ ] Yes [ ] No

________ %

________ MW [ ] Yes [ ] No

________ %

________ MW [ ] Yes [ ] No

________ %

________ MW

23 Ability to Fuel Switch
Can the unit fuel switch? [ ] Yes [ ] No If No, skip to Sch. 3 Part C. [ ] Yes [ ] No If No, skip to Sch. 3 Part C. [ ] Yes [ ] No If No, skip to Sch. 3 Part C.46 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:

_____________________ _______________ Operator ID:___________ Plant Name:_____________

_____________________ _____ Plant Code:___________ Reporting as of December 31 Year:________________ SCHEDULE 3. PART B. GENERATOR INFORMATION – EXISTING GENERATORS
(COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT) Generator (a) Generator (b) Generator (c)

24 Oil – Natural Gas Fuel Switching
a. Can the unit switch between oil and natural gas? If No, skip to line 26.
If Yes:

 Can the unit switch fuels while operating (i.e., without shutting down the unit)?

 Net summer MW achievable when running on natural gas:

 Net summer MW achievable when running on fuel oil:

 Time Required to Switch this unit from using 100 percent natural gas to using 100 percent oil (check one box): [ ] Yes [ ] No

[ ] Yes [ ] No

_______ MW

_______ MW

[ ] 0 to 6 hours [ ] over 6 to 24 hours [ ] over 24 to 72 hours [ ] over 72 hours. [ ] Unknown or uncertain [ ] Yes [ ] No

[ ] Yes [ ] No

_______ MW

_______ MW

[ ] 0 to 6 hours [ ] over 6 to 24 hours [ ] over 24 to 72 hours [ ] over 72 hours. [ ] Unknown or uncertain [ ] Yes [ ] No

[ ] Yes [ ] No

_______ MW

_______ MW

[ ] 0 to 6 hours [ ] over 6 to 24 hours [ ] over 24 to 72 hours [ ] over 72 hours. [ ] Unknown or uncertain

25 Limits on Oil-Fired Operation

A. Are there factors that limit your ability to switch from Natural Gas to oil? If No, skip to line 26. If Yes: B . Check factors that apply. [ ] Yes [ ] No

( ) Limited on site fuel storage.

( ) Air Permit limits

( ) Other (explain in SCHEDULE 7) [ ] Yes [ ] No

( ) Limited on site fuel storage.

( ) Air Permit limits

( ) Other (explain in SCHEDULE 7) [ ] Yes [ ] No

( ) Limited on site fuel storage.

( ) Air Permit limits

( ) Other (explain in SCHEDULE 7)

a b c a b c a b C

d e f d e f d e f 26 Fuel Switching Options Enter the codes for up to six fuels that can be used as a sole source of fuel for this unit.47 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_______________

_______________ ___________ Operator ID:_______ Reporting as of December 31 Year:________________ SCHEDULE 3. PART C. GENERATOR IN FORMATION – PROPOSED GENERATORS (COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT)

Plant Name
EIA Plant Code Operator’s Generator Identification Generator (a) Generator (b) Generator (c)

1 Generator Nameplate Capacity (Megawatts)
Summer 2 Net Capacity (Megawatts) Winter Lagging

3a Reactive Power Output (MVAR) Corresponding to Net Summer Capacity For generators with nameplate capacity 10 MW or greater Leading

Lagging

3b Reactive Power Output (MVAR) Corresponding to Net Winter Capacity For generators with nameplate capacity 10 MW or greater Leading

4 Status Code

5 Planned Original Effective Date (MMYYYY)

6 Planned Current Effective Date (MMYYYY)

7 Will this generator be associated with a Combined Heat and Power system (fuel input is used to produce both electricity and useful thermal output)? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

8 Will this generator be part of a Solid Fuel Gasification system? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

9 Is this generator part of a site that was previously reported as indefinitely postponed or cancelled? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

PLANNED ENERGY SOURCES

10 Expected Predominant Energy Source

11 If coal-fired or petroleum coke fired, check all combustion technologies that apply to the associated boiler(s) and steam conditions [ ] Pulverized coal [ ] Fluidized Bed [ ] Sub-critical [ ] Super-critical [ ] Ultra super-critical [ ] Carbon-capture [ ] Pulverized coal [ ] Fluidized Bed [ ] Sub-critical [ ] Super-critical [ ] Ultra super-critical [ ] Carbon-capture [ ] Pulverized coal [ ] Fluidized Bed [ ] Sub-critical [ ] Super-critical [ ] Ultra super-critical [ ] Carbon-capture

12 Expected Second Most Predominant Energy Source

a b c d a b c d a b c d 13 Other Energy Source Options . Enter up to four codes in order of expected quantity used (measured in Btus).48 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_______________

_______________ ___________ Operator ID:_______ Reporting as of December 31 Year:________________ SCHEDULE 3. PART C. GENERATOR IN FORMATION – PROPOSED GENERATORS (COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT)

Plant Name
EIA Plant Code Operator’s Generator Identification Generator (a) Generator (b) Generator (c)

14 If Energy Source Is Wind, Enter The Number Of Turbines
COMBUSTIBLE FUEL CAPABILITY

15 Ability to use multiple fuels Will the combustion system that powers this generator have 1) the regulatory permits, and 2) the equipment (including fuel storage facilities), in working order, necessary to either co-fire fuels or to fuel switch? [ ] Yes [ ] No [ ] Undetermined

If No or Undetermined, skip to Sch. 4. [ ] Yes [ ] No [ ] Undetermined

If No or Undetermined, skip to Sch. 4. [ ] Yes [ ] No [ ] Undetermined

If No or Undetermined, skip to Sch. 4.

16 Ability to Co-Fire
Will the unit be able to co-fire fuels? (Note: co-firing excl udes the limited use of an alternative fuel for startup or flame stabilization.) [ ] Yes [ ] No

If No, skip to line 20. [ ] Yes [ ] No

If No, skip to line 20. [ ] Yes [ ] No

If No, skip to line 20.

a b c a b c a b c

d e f d e f d e f 17 Fuel Options for Co-Firing Enter the codes for up to six fuels that can be co-fired:

18 Ability to Co-Fire Oil and Natural Gas
Will the unit be able to co-fire fuel oil with natural gas? [ ] Yes [ ] No If No, skip to line 20. [ ] Yes [ ] No If No, skip to line 20. [ ] Yes [ ] No If No, skip to line 20.

19 Ability to Co-Fire Oil
a. Will the unit be able to run on 100% oil? If Yes, skip to Line 20. If No, what is:

 Maximum oil heat input (% of MMBtus) when co-firing with natural gas?

 Maximum output (net summer MW) achievable, when making the maximum use of oil and co-firing natural gas? [ ] Yes [ ] No

________ %

________ MW [ ] Yes [ ] No

________ %

________ MW [ ] Yes [ ] No

________ %

________ MW

20 Ability to Fuel Switch
Will the unit be able to fuel switch? [ ] Yes [ ] No If No, skip to Sch. 4. [ ] Yes [ ] No If No, skip to Sch. 4. [ ] Yes [ ] No If No, skip to Sch. 4.49 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_______________

_______________ ___________ Operator ID:_______ Reporting as of December 31 Year:________________ SCHEDULE 3. PART C. GENERATOR IN FORMATION – PROPOSED GENERATORS (COMPLETE ONE COLUMN FOR EACH GENERATOR, BY PLANT)

Plant Name
EIA Plant Code Operator’s Generator Identification Generator (a) Generator (b) Generator (c)

21 Oil – Natural Gas Fuel Switching
a. Will the unit be able to switch between oil and natural gas? If No, skip to line 23. If Yes:

 Will the unit be able to switch fuels while operating (i.e., without shutting down the unit)?

 Expected net summer MW achievable running on natural gas:

 Expected net summer MW achievable running on fuel oil:

 Expected Time Required to Switch this unit from using 100 percent natural gas to using 100 percent oil (check one box) [ ] Yes [ ] No

[ ] Yes [ ] No

_______ MW

_______ MW

[ ] 0 to 6 hours [ ] over 6 to 24 hours [ ] over 24 to 72 hours [ ] over 72 hours [ ] unknown or uncertain [ ] Yes [ ] No

[ ] Yes [ ] No

_______ MW

_______ MW

[ ] 0 to 6 hours [ ] over 6 to 24 hours [ ] over 24 to 72 hours [ ] over 72 hours. [ ] unknown or uncertain [ ] Yes [ ] No

[ ] Yes [ ] No

_______ MW

_______ MW

[ ] 0 to 6 hours [ ] over 6 to 24 hours [ ] over 24 to 72 hours [ ] over 72 hours [ ] unknown or uncertain

22 Limits on Oil-Fired Operation
A. Are there factors that will limit your ability to switch from Natural Gas to oil? If No, skip to line 23. If Yes:
B . Check factors that apply. [ ] Yes [ ] No

( ) Limited on site fuel storage.

( ) Air Permit limits

( ) Other (explain in SCHEDULE 7) [ ] Yes [ ] No

( ) Limited on site fuel storage.

( ) Air Permit limits

( ) Other (explain in SCHEDULE 7) [ ] Yes [ ] No

( ) Limited on site fuel storage.

( ) Air Permit limits

( ) Other (explain in SCHEDULE 7)

a b c a b c a b c

d e f d e f d e f 23 Fuel Switching Options Enter the codes for up to six fuels that can be used as a sole source of fuel for this unit.50 U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_________________________________________
Operator ID:_______ Reporting as of December 31 Year:________________

SCHEDULE 4. OWNERSHIP OF GENERATORS OWNED JOINTLY OR BY OTHERS
PLANT NAME (a) EIA PLANT CODE (b)

OPERATOR’S GENERATOR IDENTIFICATION (c) IDENTIFICATION OF OWNERS - OWNER NAME(S) AND CONTACT INFORMATION (d)

Owner/Joint Owner 1: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 2: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 3: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 4: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 5: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 6: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 7: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 8: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 9: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

JOINT OWNER 10: Name % OWNED (e):
Street Address City, State and Zip Code EIA CODE:

Total 100%51 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_____

________________________ ____________ Operator ID:_______ Reporting as of December 31 Year:________________ SCHEDULE 5. NEW GENERATOR IN TERCONNECTION INFORMATION (COMPLETE FOR EACH GENERATOR ENTERING SERVICE DURING CALENDAR YEAR 2007)
LINE 

### Name: Name: Name:

1 Plant Name and EIA Plant Code


### Code: Code: Code:

2 Operator’s Generator Identification

3 Date Of Actual Generator Interconnection (MM-YYYY)

4 Date Of The Initial Interconnection Request (MM-YYYY)

5 Interconnection Site Location (Nearest City or Town, State) 

### City: State: City: State: City: State:

6 Grid Voltage At The Point Of Interconnection (kV)

7 Owner Of The Transmission Or Distribution Facilities To Which Generator is Interconnected

8 Total Cost Incurred For The Direct, Physical Interconnection (Thousand $)
Equipment Included In The Direct Interconnection Cost (Check All Of The Following That Apply:)

a. Transmission Or Distribution Line: [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

b. Transformer [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

c. Protective Devices [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No d. Substation Or Switching Station [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No 9

e. Other Equipment (specify in SCHEDULE 7, Footnotes) [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

a. Total Cost For Other Grid Enhancements/ Reinforcements Needed To Accommodate Power Deliveries From the Generator (Thousand $) 10

b. Will This Cost Be Repaid? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No

11 Were Specific Transmission Use Rights Secured As A Result Of The Interconnection Costs Incurred? [ ] Yes [ ] No [ ] Yes [ ] No [ ] Yes [ ] No52 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:___

________________________ __________ Operator ID:_________ Plant Name:_____________

_____________________ _______ Plant Code: _________ Reporting as of December 31 Year:____________ ___ SCHEDULE 6. BOILER INFORMATION PART A. PLANT CONFIGURATION (FOR PLANTS EQUAL TO OR GREATER THAN 10 MW BUT LESS THAN 100 MW, COMPLETE ONLY LINES 1, 2, 3, AND IF APPLICABLE LINES 5 AND 6)

LINE EQUIPMENT TYPE EQUIPMENT IDENTIFICATION (a) EQUIPMENT IDENTIFICATION (b) EQUIPMENT IDENTIFICATION (c) EQUIPMENT IDENTIFICATION (d) EQUIPMENT IDENTIFICATION (e)

1 Boiler ID

2 Associated Generator(s) ID

3 Generator Associations with Boiler as Actual or Theoretical (indicate "A" for actual association or "T" for theoretical association)

4 Associated Cooling System(s) ID

5 Associated Flue Gas Particulate Collector(s) ID (include flue gas desulfurization units that also remove particulate matter)

6 Associated Flue Gas Desulfurization Unit(s) ID (include flue gas particulate collectors that also remove sulfur dioxide)

7 Associated Flue(s) ID

8 Associated Stack(s) ID53 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:__________________

_____________________ Operator ID:___________

Plant Name:_____________

__________________ ________ Plant Code:___________ Reporting as of Decem ber 31 Year:________________ SCHEDULE 6. PART B. BOILER INFO RMATION – AIR EMISSION STANDARDS (DATA NOT REQUIRED FOR PLANT S LESS THAN 100 MW) (COMPLETE A SEPARATE PAGE FOR EACH BOILER)

LINE

1 Boiler ID (as reported on SCHEDULE 6. PART A. line 1)

2a Type Of Boiler Standards Under Which The Boiler Is Operating (use codes) D [ ] Da [ ] Db [ ] Dc [ ] N [ ]

2b Is Boiler Operating Under a New Source Review (NSR) Permit? If Yes, list date and identification

number of the issued permit. [ ] Yes [ ] No Date (MM-YYYY) Permit Number

CATEGORY PARTICULATE MATTER (a) SULFUR DIOXIDE (b) NITROGEN OXIDES (c)

3 Type of Statute or Regulation (use codes) FD [ ] ST [ ]
LO [ ] NA [ ] FD [ ] ST [ ]
LO [ ] NA [ ] FD [ ] ST [ ]
LO [ ] NA [ ]

4 Emission Standard Specified

5 Unit of Measurement Specified (use codes)

6 Time Period Specified (use codes)

7 Year Boiler Was or is Expected to Be in Compliance With Federal, State and/or Local Regulation

8 If Not in Compliance, Strategy for Compliance (use codes)

9 Select Existing Strategies to meet th e Sulfur Dioxide and Nitrogen Oxides Requirements of Title IV of the Clean Air Act Amendment of 1990 (use codes)

10 Select Planned Strategies to meet th e Sulfur Dioxide and Nitrogen Oxides Requirements of Title IV of the Clean Air Act Amendment of 1990 (use codes)54 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129

Approval Expires: 12/31/2010 Operator Name:_________

_____________________ ___________ Operator ID:_________ Plant Name:________________

_________________________ Plant Code: _________ Reporting as of December 31 Year:_______________ SCHEDULE 6. PART C. BOILER IN FORMATION – DESIGN PARAMETERS (DATA NOT REQUIRED FOR PLANTS LESS THAN 100 MW) (COMPLETE A SEPARATE PAGE FOR EACH BOILER) LINE

1 Boiler ID (as reported on SCHEDULE 6 PART A. line 1)

2 Boiler Status (use codes)

3 Boiler Actual or Projected Date of Commercial Operation (e.g., 12-2001)

4 Boiler Actual or Projected Retirement Date (e.g., 12-2001)

5 Boiler Manufacturer (use code)

6 Type of Firing Used with Primary Fuels (use codes)

7 Maximum Continuous Steam Flow at 100 Percent Load (thousand pounds per hour)

8 Design Firing Rate at Maximum Continuous Steam Flow for Coal (nearest 0.1 ton per hour)

9 Design Firing Rate at Maximum Continuous Steam Flow for Petroleum (nearest 0.1 barrels per hour)

10 Design Firing Rate at Maximum Continuous Steam Flow for Gas (nearest 0.1 thousand cubic feet per hour)

11 Design Firing Rate at Maximum Continuous Steam Flow for Other (specify fuel and unit on SCHEDULE 7)

12 Design Waste Heat Input Rate at Maximum Continuous Steam Flow (million Btu per hour)

13 Primary Fuels Used in Order of Predominance (use codes)

14 Boiler Efficiency When Burning Primary Fuel at 100 Percent Load (nearest 0.1 percent)

15 Boiler Efficiency When Burning Primary Fuel at 50 Percent Load (nearest 0.1 percent)

16 Total Air Flow Including Excess Air at 100 Percent Load (cubic feet per minute at standard conditions)

17 Wet Or Dry Bottom (for coal-capab le boilers), (enter "W" for Wet or "D" for Dry)

18 Fly Ash Re-injection (enter "Y" for Yes or "N" for No)55 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129

Approval Expires: 12/31/2010 Operator Name:___

________________________ ___________ Operator ID:_________ Plant Name:________________

_________________________ Plant Code: _________ Reporting as of December 31 Year:________________ SCHEDULE 6. PART D. BOILER INFORMAT ION – NITROGEN OXIDE EMISSION CONTROLS (COMPLETE A SEPARATE PAGE FOR EACH BOILER)

1 Boiler ID (as reported on SCHEDULE 6. PART A. line 1)

2 Nitrogen Oxide Control Status (use codes)

NITROGEN OXIDE CONTROL EQUIPMENT AND OR PROCESS

3 Low Nitrogen Oxide Control Process (use codes)

4 Manufacturer of Low Nitrogen Oxide Control Burners (use code)


### SCHEDULE 6. PART E. BOILER INFORM ATION – MERCURY EMISSION CONTROLS

1 Does This Boiler Have Mercury Emission Controls? (check Yes or No) Yes [ ] No [ ]

2 If "Yes," Check all of the boxes that apply below: Activated

carbon injection system

[ ] Baghouse [ ] Dry scrubber [ ] Electrostatic precipitator [ ] Flue gas desulfurization [ ] Lime injection

[ ] Wet scrubber [ ] Other [ ]56 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:___

________________________ ___________ Operator ID:_______ Plant Name:_____________

_____________________ _______ Plant Code: _________ Reporting as of December 31 Year:________________ SCHEDULE 6. PART F. COOLING SYST EM INFORMATION - DESIGN PARAMETERS (DATA NOT REQUIRED FOR PLANTS LESS THAN 100 MW) (COMPLETE A SEPARATE PAGE FOR EACH COOLING SYSTEM) LINE

1 Cooling System ID (as reported on SCHEDULE 6. PART A. line 4) 2 Cooling System Status (use codes) 3 Cooling System Actual or Projected In-service Date of Commercial Operation (e.g., 12-2001) 4 Type of Cooling System (use codes)

5 Source of Cooling Water Including Makeup Water (name) (if discharge is into different water body, footnote in SCHEDULE 7) 6 Design Cooling Water Flow Rate at 100 per cent Load at Intake (cubic feet per second)

7 Actual or Projected In-Service Date for Chlorine Discharge Control Structures and Equipment (month and year of commercial operation, e.g., 12-1982) COOLING PONDS

8 Actual or Projected In-Service Date (month and year of commercial operation, e.g. 12-1982)

9 Total Surface Area (acres)

10 Total Volume (acre-feet)

COOLING TOWERS

11 Actual or Projected In-service Date (month and year of commercial operation, e.g., 12-1982)

12 Type of Towers (use codes)

13 Maximum Design Rate of Water Flow at 100 Percent Load (cubic feet per second)

14 Maximum Power Requirement at 100 Percent Load (megawatts)

INSTALLED COST OF COOLING SYSTEM EXCLUDING LAND AND CONDENSERS (thousand dollars) 15 Total System 16 Ponds (if applicable)

17 Towers (if applicable)

18 Chlorine Discharge Control Struct ures and Equipment (if applicable)

COOLING WATER INTAKE AND OUTLET LOCATIONS ITEM INTAKE (a) OUTLET (b)

19 Maximum Distance from Shore (feet)

20 Average Distance below Water Surface (feet)

21 Latitude (degrees, minutes, seconds)

22 Longitude (degrees, minutes, seconds)

23 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”57 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:___

________________________ __________ Operator ID:_________ Plant Name:_____________

_____________________ _______ Plant Code: _________ Reporting as of December 31 Year:________________ SCHEDULE 6. PART G. FLUE GAS PARTICULATE COLLECTOR INFORMATION (COMPLETE A SEPARATE PAGE FOR EACH FLUE GAS PARTICULATE COLLECTOR)
LINE

1 Flue Gas Particulate Collector ID (as reported on SCHEDULE 6. PART A. line 5)

2 Flue Gas Particulate Collector Actual or Projected In-Service Date of Commercial Operation (e.g., 12-2001)

3 Flue Gas Particulate Collector Status (use code)

4 Type of Flue Gas Particulate Collector (use codes)

5 Installed Cost of Flue Gas Particulate Collector Excluding Land (thousand dollars)

DESIGN FUEL SPECIFICATIONS FOR ASH (AS BURNED, TO NEAREST 0.1 PERCENT BY WEIGHT)

6 For Coal

7 For Petroleum
DESIGN FUEL SPECIFICATIONS FOR SULFUR (AS BU RNED, TO NEAREST 0.1 PERCENT BY WEIGHT)

8 For Coal

9 For Petroleum

DESIGN SPECIFICATIONS AT 100 PERCENT GENERATOR LOAD

10 Collection Efficiency (to nearest 0.1 percent)

11 Particulate Emission Rate (pounds per hour)

12 Particulate Collector Gas Exit Rate (actual cubic feet per minute)

13 Particulate Collector Gas Exit Temperature (degrees Fahrenheit)58 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:___

________________________ __________ Operator ID:_________ Plant Name:_____________

_____________________ _______ Plant Code: _________ Reporting as of December 31 Year:________________ SCHEDULE 6. PART H. FLUE GAS DESULF URIZATION UNIT - DESIGN PARAMETERS (COMPLETE A SEPARATE PAGE FOR EACH FLUE GAS DESULFURIZATION UNIT)
LINE

1 Flue Gas Desulfurization Unit ID (as reported on SCHEDULE 6. PART A. line 6) 2 Flue Gas Desulfurization Unit Status (use codes)

3 Flue Gas Desulfurization Unit Actual or Projected In-service Date of Commercial Operation (e.g., 12-2001) 4 Type of Flue Gas Desulfurization Unit (use code)

5 Type of Sorbent (use code)

6 Salable Byproduct Recovery (enter "Y" for Yes or "N" for No)
7 Flue Gas Desulfurization Unit Manufacturer (use code) 8 Annual Pond and Land Fill Requirements (nearest acre foot per year)

9 Is Sludge Pond Lined (enter "Y" for Yes, "N" for No, or "NA" for Not Applicable)

10 Can Flue Gas Bypass Flue Gas Desulfurization Unit (enter "Y" for Yes or "N" for No)

DESIGN FUEL SPECIFICATIONS FOR COAL

11 Ash (to nearest 0.1 percent by weight)

12 Sulfur (to nearest 0.1 percent by weight)
NUMBER OF FLUE GAS DESULFURIZATION UNIT SCRUBBER TRAINS (OR MODULES)
13 Total

14 Operated at 100 Percent Load

DESIGN SPECIFICATIONS OF FLUE GAS DESULFURIZATION UNIT AT 100 PERCENT GENERATOR LOAD
15 Removal Efficiency for Sulfur Dioxide (to nearest 0.1 percent by weight)

16 Sulfur Dioxide Emission Rate (pounds per hour)

17 Flue Gas Exit Rate (actual cubic feet per minute)

18 Flue Gas Exit Temperature (degrees Fahrenheit)

19 Flue Gas Entering Flue Gas Desulfur ization Unit (percent of total)

INSTALLED COST OF FLUE GAS DESULFURIZATION UNIT, EXCLUDING LAND (THOUSAND DOLLARS)
20 Structures and Equipment

21 Sludge Transport and Disposal System

22 Other (installed cost of flue gas desulfurization unit)

23 Total (sum of lines 20, 21, 22)59 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:___

________________________ _________ Operator ID:_________ Plant Name:_____________

_____________________ _______ Plant Code: _________ Reporting as of December 31 Year:________________ SCHEDULE 6. PART I. STACK AND FLUE IN FORMATION - DESIGN PARAMETERS (DATA NOT REQUIRED FOR PLANTS LESS THAN 100 MW) (COMPLETE A SEPARATE PAGE FOR EACH STACK AND FLUE)
LINE

1 Flue ID (as reported on SCHEDULE 6. PART A. line 8) 2 Stack ID (as reported on SCHEDULE 6. PART A. line 7) 3 Stack (or Flue) Actual or Projected In-Service Date of Commercial Operation (e.g., 12-2001) 4 Status of Stack (or Flue) (use code) 5 Flue Height at Top from Ground Level (feet) 6 Cross-Sectional Area at Top of Flue (nearest square foot) DESIGN FLUE GAS EXIT (AT TOP OF STACK)
7 Rate at 100 Percent Load (actual cubic feet per minute) 8 Rate at 50 Percent Load (actual cubic feet per minute) 9 Temperature at 100 Percent Load (degrees Fahrenheit) 10 Temperature at 50 Percent Load (degrees Fahrenheit) 11 Velocity at 100 Percent Load (feet per second) 12 Velocity at 50 Percent Load (feet per second) ACTUAL SEASONAL FLUE GAS EXIT TEMPERATURE (DEGREES FAHRENHEIT)
13 Summer Season

14 Winter Season

15 Source (enter "M" for measured or "E" for estimated)
STACK LOCATION
16 Stack Location - Latitude (degrees, minutes, seconds)

17 Stack Location - Longitude (degrees, minutes, seconds)

18 Enter Datum for Latitude and Longitude, if Known; Otherwise Enter “UNK”60 

### U.S. Department of Energy Energy Information Administration Form EIA-860 (2009) ANNUAL ELECTRIC GENERATOR REPORT Form Approved OMB No. 1905-0129 Approval Expires: 12/31/2010

Operator Name:_____

________________________ ____________ Operator ID:_______ Reporting as of December 31 Year:________________
SCHEDULE 7. COMMENTS

SCHEDULE

NUMBER (a) PART (b) LINE NUMBER (c) NOTES PROVIDE ALL IDENTIFYING CODES (e .g., plant code, generator id, boiler id) to which the comment applies, along with the comment. (d)