# Electric Power Annual 2012

December2013

Independent Statistics & Analysis www.eia.gov U.S. Department of Energy Washington, DC 20585U.S. EnergyInformation Administration | Electric Power Annual



### This report wasprepared by the U.S. Energy Information Administration (EIA), the statistical and analytical agency within the U.S. Department of Energy. By law, EIA’s data, analyses, and forecasts are independent of approval by any other officer or employee of the UnitedStates Government.U.S. EnergyInformation Administration | Electric Power Annual



# Tableof Contents
Chapter 1. National Summary Data Table 1.1.Total Electric Power Industry Summary Statistics Table 1.2.Summary Statistics for the United States Table 1.3.Supply and Disposition of Electricity 

### Chapter 2.Electricity Sales Table 2.1.Number of Ultimate Customers Served by Sector, by Provider Table 2.2.Retail Sales and Direct Use of Electricity to Ultimate Customers by Sector, by Provider Table 2.3.Revenue from Retail Sales of Electricityto Ultimate Customers by Sector, by Provider Table 2.4.Average Retail Price of Electricity to Ultimate Customers by End

-Use Sector Table 2.5.Retail Sales of Electricity to Ultimate Customers: Total by End

-Use Sector Table 2.6.Revenue from Retail Sales of Electricity to Ultimate Customers: Total by End

-Use Sector Table 2.7.Average Retail Price of Electricity to Ultimate Customers: Total by End

-Use Sector Table 2.8.Retail Sales of Electricity to Ultimate Customers by End

-Use Sector, by State Table 2.9.Revenue from Retail Sales of Electricity to Ultimate Customers by End

-Use Sector, by

State Table 2.10.Average Retail Price of Electricity to Ultimate Customers by End

-Use Sector, by State Table 2.11.Electric Power Industry

-Electricity Purchases Table 2.12.Electric Power Industry

-Electricity Sales for Resale Table 2.13.Electric Power Industry

-U.S. Electricity Imports from and Electricity Exports to Canada

and Mexico Table 2.14.Green Pricing Customers by End Use Sector 

### Chapter 3.Net Generation Table 3.1.A.Net Generation by Energy Source: Total (All Sectors) Table 3.1.B.Net GenerationfromRenewableSources: Total (All Sectors) Table 3.2.A.Net Generation by Energy Source: Electric Utilities Table 3.2.B.Net GenerationfromRenewableSources: Electric Utilities Table 3.3.A.Net Generation by Energy Source: Independent Power Producers Table 3.3.B.Net GenerationfromRenewableSources: Independent Power Producers Table 3.4.A.Net Generation by Energy Source: Commercial Sector Table 3.4.B.Net GenerationfromRenewableSources: Commercial Sector Table 3.5.A.Net Generation by Energy Source: Industrial Sector Table 3.5.B.Net GenerationfromRenewableSources: Industrial Sector Table 3.6.Net Generation by State by Sector Table3.7.Net Generationfrom Coal by State by Sector Table3.8.Net Generation from Petroleum Liquids by State by Sector Table3.9.Net Generation from Petroleum Coke by State by Sector Table3.10.Net Generation from Natural Gas by State by Sector Table3.11.Net Generationfrom Other Gases by State by Sector Table3.12.Net Generation from Nuclear Energy by State by Sector Table3.13.Net Generation from Hydroelectric (Conventional) Power by State by Sector Table3.14.Net Generation from RenewableSourcesExcluding Hydroelectricby State by Sector Table3.15.Net Generation from Hydroelectric (Pumped Storage) Power by State by Sector Table3.16.Net Generation from Other Energy Sources by State by SectorU.S. EnergyInformation Administration | Electric Power Annual



### Table3.17.Net Generation from Wind by State by Sector Table3.18.NetGeneration from Biomass by State by Sector Table3.19.Net Generation from Geothermal by State by Sector Table3.20.Net Generation from Solar by State by Sector Table3.21.Useful Thermal Output by Energy Source: Total Combined Heat and Power (All Sectors) Table3.22.Useful Thermal Output by Energy Source: Electric PowerSectorCombined Heat and

Power Table3.23.Useful Thermal Output by Energy Source: Commercial Sector Combined Heat and Power Table3.24.Useful Thermal Output by Energy Source: Industrial Sector Combined Heat and Power 

### Chapter 4.Generation Capacity Table 4.1.Count of Electric Power Industry Power Plants, by Sector, by Predominant Energy

Sources within Plant Table 4.2.A.Existing Net Summer Capacity by Energy Source and Producer Type Table 4.2.B.Existing Net Summer Capacity of Other RenewableSources by Producer Type Table 4.3.Existing Capacity by Energy Source Table 4.4.Existing Capacity by Producer Type Table 4.5.Planned Generating Capacity Changes, by Energy Source Table 4.6.Capacity Additions, Retirements and Changes by Energy Source Table 4.7.A.Net Summer Capacity of Utility Scale Units by Technology and by State Table 4.7.B.Net Summer Capacity of Utility Scale Units Using Primarily Renewable Energy Sources

and by State Table4.7.C.Net Summer Capacity of Utility Scale Units Using Primarily Fossil Fuels and by State Table 4.8.A.Capacity Factors for Utility Scale Generators Primarily Using Fossil Fuels Table 4.8.B.Capacity Factors for Utility Scale Generators Not Primarily Using Fossil Fuel Table 4.9.Total Capacity of Distributed and Dispersed Generators by Technology Type Table 4.10.Net Metering Customers and Capacity by Technology Type, by End Use Sector Table 4.11.Fuel

-Switching Capacity of Operable Generators Reporting Natural Gas as the Primary

Fuel, by Producer Type Table 4.12.Fuel

-Switching Capacity of Operable Generators Reporting Petroleum Liquids as the

Primary Fuel, by Producer Type Table 4.13.Fuel

-Switching Capacity of Operable Generators: From Natural Gas to Petroleum

Liquids, by Type of Prime Mover Table 4.14.Fuel

-Switching Capacity of Operable Generators: From Natural Gas to Petroleum

Liquids, by Year of Initial Commercial Operation 

### Chapter 5

.Consumption of Fossil Fuels Table 5.1.A.Coal: Consumption(Thousand Tons) for Electricity Generation by Sector Table 5.1.B.Coal: Consumption (Thousand Tons) for Useful Thermal Output by Sector Table 5.1.C.Coal: Consumption (Thousand Tons) for Electricity Generation and Useful Thermal

Output by Sector Table 5.1.D.Coal: Consumption (Billion Btus) for Electricity Generation by Sector Table 5.1.E.Coal: Consumption (Billion Btus) for Useful Thermal Output by Sector Table 5.1.F.Coal: Consumption (Billion Btus) for Electricity Generation and Useful Thermal Output

bySector Table 5.2.A.Petroleum Liquids: Consumption (Thousand Barrels) for Electricity Generation by Sector Table 5.2.B.Petroleum Liquids: Consumption (Thousand Barrels) for Useful Thermal Output by

SectorU.S. EnergyInformation Administration | Electric Power Annual



### Table 5.2.C.Petroleum Liquids: Consumption (Thousand Barrels) for Electricity Generation and

Useful Thermal Output by Sector Table 5.2.D.Petroleum Liquids: Consumption (Billion Btus) for Electricity Generation by Sector Table 5.2.E.Petroleum Liquids: Consumption (Billion Btus) for Useful Thermal Output by Sector Table 5.2.F.Petroleum Liquids: Consumption (Billion Btus) for Electricity Generation and Useful

Thermal Output by Sector Table 5.3.A.Petroleum Coke: Consumption (Thousand Tons) for Electricity Generation by Sector Table 5.3.B.Petroleum Coke:Consumption (Thousand Tons) for Useful Thermal Output by Sector Table 5.3.C.Petroleum Coke: Consumption (Thousand Tons) for Electricity Generation and Useful

Thermal Output by Sector Table 5.3.D.Petroleum Coke: Consumption (Billion Btus) for ElectricityGeneration by Sector Table 5.3.E.Petroleum Coke: Consumption (Billion Btus) for Useful Thermal Output by Sector Table 5.3.F.Petroleum Coke: Consumption (Billion Btus) for Electricity Generation and Useful

Thermal Output by Sector Table 5.4.A.Natural Gas: Consumption (Million Cubic Feet) for Electricity Generation by Sector Table 5.4.B.Natural Gas: Consumption (Million Cubic Feet) for Useful Thermal Output by Sector Table 5.4.C.Natural Gas: Consumption (Million Cubic Feet) for Electricity Generation and Useful

Thermal Output by Sector Table 5.4.D.Natural Gas: Consumption (Billion Btus) for Electricity Generation by Sector Table 5.4.E.Natural Gas: Consumption (Billion Btus) for Useful Thermal Output by Sector Table 5.4.F.Natural Gas: Consumption (Billion Btus) for Electricity Generation and Useful Thermal

Output by Sector Table 5.5.D.Wood / Wood Waste Biomass: Consumption (Billion Btus) for Electricity Generation by

Sector Table 5.5.E.Wood / Wood Waste Biomass: Consumption (Billion Btus) for Useful Thermal Output by

Sector Table 5.5.F.Wood / Wood Waste Biomass: Consumption (Billion Btus) for Electricity Generation and

Useful Thermal Output by Sector Table 5.6.A.Landfill Gas: Consumption (Million Cubic Feet) for Electricity Generation by Sector Table 5.6.B.Landfill Gas: Consumption (Million Cubic Feet) for Useful Thermal Output by Sector Table 5.6.C.Landfill Gas: Consumption (Million Cubic Feet) for Electricity Generation and Useful

Thermal Output by Sector Table 5.6.D.Landfill Gas: Consumption (Billion Btus) for Electricity Generation by Sector Table 5.6.E.Landfill Gas: Consumption (Billion Btus) for Useful Thermal Output by Sector Table 5.6.F.Landfill Gas: Consumption (Billion Btus) for Electricity Generation and Useful Thermal

Output by Sector Table 5.7.A.Biogenic Municipal Solid Waste: Consumption (Thousand Tons) for Electricity

Generation by Sector Table 5.7.B.Biogenic Municipal Solid Waste: Consumption (Thousand Tons) for Useful Thermal

Output by Sector Table 5.7.C.Biogenic Municipal Solid Waste: Consumption (Thousand Tons) for Electricity

Generation and Useful Thermal Output by Sector Table 5.7.D.Biogenic Municipal Solid Waste: Consumption (Billion Btus) for Electricity Generation by

Sector Table 5.7.E.Biogenic Municipal Solid Waste: Consumption (Billion Btus) for Useful Thermal Output

by Sector Table 5.7.F.Biogenic Municipal Solid Waste: Consumption (Billion Btus) for Electricity Generation

and Useful Thermal Output by SectorU.S. EnergyInformation Administration | Electric Power Annual



### Table 5.8.D.Other Waste Biomass: Consumption (Billion Btus)for Electricity Generation by Sector Table 5.8.E.Other Waste Biomass: Consumption (Billion Btus) for Useful Thermal Output by Sector Table 5.8.F.Other Waste Biomass: Consumption (Billion Btus) for Electricity Generation and Useful

Thermal Output by Sector Table 5.9

.Consumption of Coal for Electricity Generation by State by Sector Table 5.10

.Consumption of Petroleum Liquids for Electricity Generation by State by Sector Table 5.11

.Consumption of Petroleum Coke for Electricity Generation by State by Sector Table 5.12.Consumption of Natural Gas for Electricity Generation by State by Sector Table 5.13.Consumption of Landfill Gas for Electricity Generation by State by Sector Table 5.14.Consumption ofBiogenic Municipal Solid Wastefor Electricity Generation by State by

Sector 

### Chapter 6

.Fossil Fuel Stocks for Electricity Generation Table 6.1.Stocks of Coal, Petroleum Liquids, and Petroleum Coke: Electric Power Sector Table 6.2.Stocks of Coal, Petroleum Liquids, and Petroleum Coke: Electric Power Sector, by State Table 6.3.Stocks of Coal, Petroleum Liquids, and Petroleum Coke: Electric Power Sector, by Census

Division Table 6.4.Stocks of Coal by Coal Rank: Electric Power Sector 

### Chapter 7

.Receipts, Cost, and Quality of Fossil Fuels Table 7.1.Receipts, Average Cost, and Quality of Fossil Fuels for the Electric Power Industry Table 7.2.Receipts and Quality of Coal Delivered for the Electric Power Industry Table 7.3.Average Quality of Fossil Fuel Receipts for the Electric Power Industry Table 7.4.Weighted Average Cost of Fossil Fuels for the Electric Power Industry Table 7.5.Receipts, Average Cost, and Quality of Fossil Fuels: Electric Utilities Table 7.6.Receipts, Average Cost, and Quality of Fossil Fuels: Electric Utilities (continued) Table 7.7.Receipts, Average Cost, and Quality of Fossil Fuels: Independent Power Producers Table 7.8.Receipts, Average Cost, and Quality of Fossil Fuels: Independent Power Producers

(continued) Table 7.9.Receipts, Average Cost, and Quality of Fossil Fuels:Commercial Sector Table 7.10.Receipts, Average Cost, and Quality of Fossil Fuels: Commercial Sector (continued) Table 7.11.Receipts, Average Cost, and Quality of Fossil Fuels: Industrial Sector Table 7.12.Receipts, Average Cost, and Quality of Fossil Fuels: Industrial Sector (continued) Table 7.13.Receipts of Coal Delivered for Electricity Generation by State Table 7.14.Receipts of Petroleum Liquids Delivered for Electricity Generation by State Table 7.15.Receipts of Petroleum Coke Delivered for Electricity Generation by State Table 7.16.Receipts of Natural Gas Delivered for Electricity Generation by State Table 7.17.Average Cost of Coal Delivered for Electricity Generation by State Table 7.18.Average Cost of Petroleum Liquids Delivered for Electricity Generation by State Table 7.19.Average Cost of Petroleum Coke Delivered for Electricity Generation by State Table 7.20.Average Cost of Natural Gas Delivered for Electricity Generation by State Table 7.21.Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Total (All

Sectors) by State Table 7.22.Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Electric

Utilities by State Table 7.23.Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Independent

Power Producers by StateU.S. EnergyInformation Administration | Electric Power Annual



### Table 7.24.Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Commercial

Sectorby State Table 7.25.Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Industrial

Sectorby State 

### Chapter 8

.Electric Power System Characteristics and Performance Table 8.1.Average Operating Heat Rate for Selected Energy Sources Table 8.2.AverageTestedHeat Rates by Prime Mover and Energy Source Table 8.3.Revenue and ExpenseStatistics for Major U.S. Investor

-Owned Electric Utilities Table 8.4.Average Power Plant Operating Expenses for Major U.S. Investor

-Owned Electric Utilities Table 8.5.Revenue and Expense Statistics for U.S. Cooperative Borrower

-Owned Electric Utilities Table 8.6.A.Noncoincident Peak Load by North American Electric Reliability Corporation Assessment

Area, Actual Table 8.6.B.Noncoincident Peak Load by North American Electric Reliability Corporation Assessment

Area, Projected Table 8.7.A.Net Energy for Load by North American Electric Reliability Corporation Assessment Area,

Actual Table 8.7.B.Net Energy for Load by North American Electric Reliability Corporation Assessment Area,

Projected Table 8.8.A.Summer Net Internal Demand, Capacity Resources, andCapacity Margins by North

American Electric Reliability Corporation Assessment Area, Actual Table 8.8.B.Summer Net Internal Demand, Capacity Resources, and Capacity Margins by North

American Electric Reliability Corporation Assessment Area, Projected Table 8.9.A.Winter Net Internal Demand, Capacity Resources, and Capacity Margins by North

American Electric Reliability Corporation Assessment Area, Actual Table 8.9.B.Winter Net Internal Demand, Capacity Resources, and Capacity Margins by North

American Electric Reliability Corporation Assessment Area, Projected Table 8.10.A.Existing Transmission Capacity by High

-Voltage Size Table 8.10.B.Proposed Transmission Capacity Additions by High

-Voltage Size Table 8.11.A.U.S. Transmission Circuit Outages by Typeand NERC region Table 8.11.B.U.S. Transformer Outages by Type and NERC region Table 8.12.A.U.S. Transmission Circuit Sustained Automatic Outage Counts and Hours,by High

Voltage Size and NERC Region Table 8.12.B.U.S. TransformerSustainedAutomatic Outage Counts and Hours by High

-Voltage Size

and NERC Region Table 8.13.A.U.S. Transmission CircuitSustainedAutomatic Outage Countsand Hoursby Cause Code

and by NERC Region Table 8.13.B.U.S. TransformerSustainedAutomatic Outage Countsand HoursbyCause Code and by

NERC Region 

### Chapter9

.Environmental Data Table 9.1.Emissions from Energy Consumption at Conventional Power Plants and Combined

-Heat

and

-Power Plants Table 9.2.Quantity andNet Summer Capacity of Operable Environmental Equipment Table 9.3.Quantity andNet Summer Capacity of Operable Cooling Systems, by Energy Sourceand

Cooling System Type Table 9.4.Average Cost of Existing Flue Gas Desulfurization UnitsU.S. EnergyInformation Administration | Electric Power Annual



### Table 9.5.Emissions from Energy Consumption at Conventional Power Plants and Combined

-Heat

and

-Power Plants, by State 

### Chapter10

.Demand

-Side Management and Advanced Metering Table 10.1.Demand

-Side Management Program Annual Effects by Program Category Table 10.2.Demand

-Side Management Program Annual Effects by Program Category, by Sector Table 10.3.Demand

-Side Management Program Incremental Effects by Program Category Table 10.4.Demand

-Side Management Program Incremental Effects by Program Category, by

Sector Table 10.5.Demand

-Side Management Program Direct and Indirect Costs Table10.6.Advanced Metering Count by Technology Type 

### Appendix Technical Notes Table A.1.Sulfur Dioxide Uncontrolled Emission Factors Table A.2.Nitrogen OxidesUncontrolled Emission Factors Table A.3.Carbon Dioxide Uncontrolled Emission Factors Table A.4.Nitrogen OxidesControl Technology Emissions Reduction Factors Table A.5.Unit

-of

-Measure Equivalents EIA Electric Industry Data Collection

# Chapter 1
National Summary DataFuel Year 2012 Year 2011Percentage Change Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011

Coal 1,514,043 1,733,430 -12.7% 1,146,480 1,301,107 354,076 416,783 883 1,049 12,603 14,490 Petroleum Liquids 13,403 16,086 -16.7% 9,892 11,688 2,757 3,655 191 86 563 657 Petroleum Coke 9,787 14,096 -30.6% 5,664 9,428 1,758 3,431 6 3 2,359 1,234 Natural Gas 1,225,894 1,013,689 20.9% 504,958 414,843 627,833 511,447 6,603 5,487 86,500 81,911 Other Gas 11,898 11,566 2.9% 0 29 2,984 2,911 0 3 8,913 8,624 Nuclear 769,331 790,204 -2.6% 394,823 415,298 374,509 374,906 0 0 0 0 Hydroelectric Conventional 276,240 319,355 -13.5% 252,936 291,413 20,923 26,117 28 26 2,353 1,799 Renewable Sources Excluding Hydroelectric 218,333 193,981 12.6% 28,017 21,933 160,064 141,954 2,545 2,476 27,707 27,619 ... Wind 140,822 120,177 17.2% 22,926 17,140 117,822 102,981 54 51 19 5 ... Solar Thermal and Photovoltaic 4,327 1,818 138.0% 639 216 3,525 1,511 148 84 14 7 ... Wood and Wood-Derived Fuels 37,799 37,449 0.9% 1,836 2,023 9,214 8,709 24 26 26,725 26,691 ... Other Biomass 19,823 19,222 3.1% 1,472 1,417 15,084 14,573 2,319 2,315 948 917 ... Geothermal 15,562 15,316 1.6% 1,143 1,137 14,419 14,180 0 0 0 0 Hydroelectric Pumped Storage -4,950 -6,421 -22.9% -4,202 -5,492 -748 -928 0 0 0 0 Other Energy Sources 13,787 14,154 -2.6% 603 604 7,030 7,059 1,046 950 5,108 5,541 All Energy Sources 4,047,765 4,100,141 -1.3% 2,339,172 2,460,851 1,551,186 1,487,335 11,301 10,080 146,107 141,875

Coal (1000 tons) 825,734 934,938 -11.7% 615,467 689,316 205,295 239,541 307 347 4,665 5,735 Petroleum Liquids (1000 barrels) 22,604 27,326 -17.3% 17,521 20,844 4,110 5,633 272 133 702 716 Petroleum Coke (1000 tons) 3,675 5,012 -26.7% 2,105 3,449 756 1,277 1 1 812 286 Natural Gas (1000 Mcf) 9,484,710 7,883,865 20.3% 4,101,927 3,446,087 4,686,260 3,819,107 63,116 47,170 633,407 571,501

Coal (1000 tons) 19,333 21,532 -10.2% 0 0 2,790 3,628 1,143 1,321 15,400 16,584 Petroleum Liquids (1000 barrels) 3,097 3,826 -19.0% 0 0 992 1,004 122 168 1,984 2,654 Petroleum Coke (1000 tons) 1,346 1,080 24.7% 0 0 113 112 11 6 1,222 962 Natural Gas (1000 Mcf) 886,103 839,681 5.5% 0 0 322,607 308,669 47,883 39,856 515,613 491,155

Coal (1000 tons) 845,066 956,470 -11.6% 615,467 689,316 208,085 243,168 1,450 1,668 20,065 22,319 Petroleum Liquids (1000 barrels) 25,702 31,152 -17.5% 17,521 20,844 5,102 6,637 394 301 2,685 3,370 Petroleum Coke (1000 tons) 5,021 6,092 -17.6% 2,105 3,449 869 1,388 13 6 2,034 1,248 Natural Gas (1000 Mcf) 10,370,812 8,723,546 18.9% 4,101,927 3,446,087 5,008,867 4,127,777 110,999 87,026 1,149,020 1,062,657

Sector Year 2012 Year 2011Percentage Change Year 2012 Year 2011Percentage Change Year 2012 Year 2011Percentage Change Residential 1,374,515 1,422,801 -3.4% 163,280 166,714 -2.1% 11.88 11.72 1.4% Commercial 1,327,101 1,328,057 -0.1% 133,898 135,926 -1.5% 10.09 10.23 -1.4% Industrial 985,714 991,316 -0.6% 65,761 67,606 -2.7% 6.67 6.82 -2.2% Transportation 7,320 7,672 -4.6% 747 803 -6.9% 10.21 10.46 -2.4% All Sectors 3,694,650 3,749,846 -1.5% 363,687 371,049 -2.0% 9.84 9.90 -0.6% Net Generation (Thousand Megawatthours) 

### Table 1.1. Total Electric Power Industry Summary Statistics, 2012 and 2011 Net Generation and Consumption of Fuels for January through December Total (All Sectors) Electric Power Sector Commercial Industrial

Sales, Revenue, and Average Retail Price for January through December Electric Utilities Independent Power Producers

Consumption of Fossil Fuels for Electricity Generation

Consumption of Fossil Fuels for Useful Thermal Output

Consumption of Fossil Fuels for Electricity Generation and Useful Thermal Output

Total U.S. Electric Power Industry Retail Sales (million kWh) Retail Revenue (million dollars) Average Retail Price (cents/kWh)

NM = Not meaningful due to large relative standard error. W = Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Coal generation and consumption includes anthracite, bituminous, subbituminous, lignite, waste coal, refined coal, synthetic coal, and coal-derived synthesis gas. Petroleum Liquids includes distillate fuel oil, residual fuel oil, jet fuel, kerosene, propane, and waste oil. Petroleum Coke includes petroleum coke and synthesis gas derived from petroleum coke. Natural gas includes a small amount of supplemental gaseous fuels that cannot be identified separately. Other Gases includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Wood and Wood-Derived Fuels include wood, black liquor, and other wood waste. Other Biomass includes biogenic municipal solid waste, landfill gas, sludge waste, agricultural byproducts, and other biomass. Coal stocks include anthracite, bituminous, subbituminous, lignite, refined coal, and synthetic coal; waste coal is excluded. Retail sales and net generation may not correspond exactly for a particular month for a variety of reasons (e.g., sales data may include imported electricity). Net generation is presented for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time that vary depending upon customer class and consumption occurring during and outside the calendar month. Note: Values are final. Percentage change is calculated before rounding. See technical notes for additional information including more on the Commercial, Industrial, and Transportation sectors. Sources: U.S. Energy Information Administration, Form EIA-826, 'Monthly Electric Sales and Revenue With State Distributions Report.' U.S. Energy Information Administration, Form EIA-923, 'Power Plant Operations Report.'YearResidentialCommer-cialIndustrialTransportation Other Total 2002116,622,03715,333,700 601,744 N/A1,066,554133,624,035 2003117,280,48116,549,519 713,221 1,127 N/A134,544,348 2004118,763,76816,606,783 747,600 1,025 N/A136,119,176 2005120,760,83916,871,940 733,862 518 N/A138,367,159 2006122,471,07117,172,499 759,604 791 N/A140,403,965 2007123,949,91617,377,219 793,767 750 N/A142,121,652 2008124,937,46917,562,726 774,713 727 N/A143,275,635 2009125,177,17517,561,661 757,519 705 N/A143,497,060 2010125,717,93517,674,338 747,746 239 N/A144,140,258 2011126,143,07217,638,062 727,920 92 N/A144,509,146 2012126,832,34317,729,029 732,385 83 N/A145,293,840

YearResidentialCommer-cialIndustrialTransportation Other Total 20021,265,1801,104,497 990,238 N/A 105,5523,465,466 20031,275,8241,198,7281,012,373 6,810 N/A3,493,734 20041,291,9821,230,4251,017,850 7,224 N/A3,547,479 20051,359,2271,275,0791,019,156 7,506 N/A3,660,969 20061,351,5201,299,7441,011,298 7,358 N/A3,669,919 20071,392,2411,336,3151,027,832 8,173 N/A3,764,561 20081,379,9811,335,9811,009,300 7,700 N/A3,732,962 20091,364,4741,307,168 917,442 7,781 N/A3,596,865 20101,445,7081,330,199 970,873 7,712 N/A3,754,493 20111,422,8011,328,057 991,316 7,672 N/A3,749,846 20121,374,5151,327,101 985,714 7,320 N/A3,694,650

YearResidentialCommer-cialIndustrialTransportation Other Total 2002 106,834 87,117 48,336 N/A 7,124 249,411 2003 111,249 96,263 51,741 514 N/A 259,767 2004 115,577 100,546 53,477 519 N/A 270,119 2005 128,393 110,522 58,445 643 N/A 298,003 2006 140,582 122,914 62,308 702 N/A 326,506 2007 148,295 128,903 65,712 792 N/A 343,703 2008 155,433 138,469 68,920 827 N/A 363,650 2009 157,008 132,940 62,504 828 N/A 353,280 2010 166,782 135,559 65,750 815 N/A 368,906 2011 166,714 135,926 67,606 803 N/A 371,049 2012 163,280 133,898 65,761 747 N/A 363,687 

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

(From Table 2.1.) Number of Ultimate Customers

(From Table 2.2.) Sales to Ultimate Customers (Thousand Megawatthours)

(From Table 2.3.) Revenue From Ultimate Customers (Million Dollars)

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

YearResidentialCommer-cialIndustrialTransportation Other Total 2002 8.44 7.89 4.88 N/A 6.75 7.20 2003 8.72 8.03 5.11 7.54 N/A 7.44 2004 8.95 8.17 5.25 7.18 N/A 7.61 2005 9.45 8.67 5.73 8.57 N/A 8.14 2006 10.40 9.46 6.16 9.54 N/A 8.90 2007 10.65 9.65 6.39 9.70 N/A 9.13 2008 11.26 10.36 6.83 10.74 N/A 9.74 2009 11.51 10.17 6.81 10.65 N/A 9.82 2010 11.54 10.19 6.77 10.57 N/A 9.83 2011 11.72 10.23 6.82 10.46 N/A 9.90 2012 11.88 10.09 6.67 10.21 N/A 9.84

Year PurchasesSales for Resale Imports Exports 20028,754,8078,568,678 36,779 15,796 20036,979,6696,920,954 30,395 23,975 20046,998,5496,758,975 34,210 22,898 20056,092,2856,071,659 43,929 19,151 20065,502,5845,493,473 42,691 24,271 20075,411,4225,479,394 51,396 20,144 20085,612,7815,680,733 57,019 24,198 20095,028,6475,065,031 52,191 18,138 20105,770,1345,929,211 45,083 19,106 20115,024,6215,143,121 52,300 15,049 20124,984,9335,013,765 59,257 11,996 

### (Cents per Kilowatthour) (From Table 2.4.) Average Retail Price

(From Tables 2.11. - 2.13.) Trade (Thousand Megawatthours)

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

Year CoalPetroleum Natural Gas Other Gas Nuclear HydroConventional Wind 20021,933,130 94,567 691,006 11,463 780,064 264,329 10,354 20031,973,737 119,406 649,908 15,600 763,733 275,806 11,187 20041,978,301 121,145 710,100 15,252 788,528 268,417 14,144 20052,012,873 122,225 760,960 13,464 781,986 270,321 17,811 20061,990,511 64,166 816,441 14,177 787,219 289,246 26,589 20072,016,456 65,739 896,590 13,453 806,425 247,510 34,450 20081,985,801 46,243 882,981 11,707 806,208 254,831 55,363 20091,755,904 38,937 920,979 10,632 798,855 273,445 73,886 20101,847,290 37,061 987,697 11,313 806,968 260,203 94,652 20111,733,430 30,1821,013,689 11,566 790,204 319,355 120,177 20121,514,043 23,1901,225,894 11,898 769,331 276,240 140,822

Year Solar Thermal andPhotovoltaic Wood andWoodDerived FuelsGeothermal Other Biomass Hydro Pumped Storage Other Energy Sources All Energy Sources 2002 555 38,665 14,491 15,044 -8,743 13,5273,858,452 2003 534 37,529 14,424 15,812 -8,535 14,0453,883,185 2004 575 38,117 14,811 15,421 -8,488 14,2323,970,555 2005 550 38,856 14,692 15,420 -6,558 12,8214,055,423 2006 508 38,762 14,568 16,099 -6,558 12,9744,064,702 2007 612 39,014 14,637 16,525 -6,896 12,2314,156,745 2008 864 37,300 14,840 17,734 -6,288 11,8044,119,388 2009 891 36,050 15,009 18,443 -4,627 11,9283,950,331 2010 1,212 37,172 15,219 18,917 -5,501 12,8554,125,060 2011 1,818 37,449 15,316 19,222 -6,421 14,1544,100,141 2012 4,327 37,799 15,562 19,823 -4,950 13,7874,047,765 

### (From Tables 3.1.A. and 3.1.B.) Net Generation (Thousand Megawatthours)

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

Year CoalPetroleum Natural Gas Other Gas Nuclear HydroConventional Wind 2002 315,350 59,651 312,512 2,008 98,657 79,356 4,417 2003 313,019 60,730 355,442 1,994 99,209 78,694 5,995 2004 313,020 59,119 371,011 2,296 99,628 77,641 6,456 2005 313,380 58,548 383,061 2,063 99,988 77,541 8,706 2006 312,956 58,097 388,294 2,256 100,334 77,821 11,329 2007 312,738 56,068 392,876 2,313 100,266 77,885 16,515 2008 313,322 57,445 397,460 1,995 100,755 77,930 24,651 2009 314,294 56,781 401,272 1,932 101,004 78,518 34,296 2010 316,800 55,647 407,028 2,700 101,167 78,825 39,135 2011 317,640 51,482 415,191 1,934 101,419 78,652 45,676 2012 309,680 47,167 422,364 1,946 101,885 78,738 59,075

Year Solar Thermal andPhotovoltaic Wood andWoodDerived FuelsGeothermal Other Biomass Hydro Pumped Storage Other Energy Sources All Energy Sources 2002 397 5,844 2,252 3,800 20,371 686 905,301 2003 397 5,871 2,133 3,758 20,522 684 948,446 2004 398 6,182 2,152 3,529 20,764 746 962,942 2005 411 6,193 2,285 3,609 21,347 887 978,020 2006 411 6,372 2,274 3,727 21,461 882 986,215 2007 502 6,704 2,214 4,134 21,886 788 994,888 2008 536 6,864 2,229 4,186 21,858 9421,010,171 2009 619 6,939 2,382 4,317 22,160 8881,025,400 2010 866 7,037 2,405 4,369 22,199 8841,039,062 2011 1,524 7,077 2,409 4,536 22,293 1,4201,051,251 2012 3,170 7,508 2,592 4,811 22,368 1,7291,063,033 

### (From Tables 4.2.A. and 4.2.B.) Net Summer Generating Capacity (Megawatts)

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

Year Coal (Thousand Tons)Petroleum (Thousand Barrels) Natural Gas (Millions of Cubic Feet) Other Gas (Millions

of BTU) Coal (Thousand Tons)Petroleum (Thousand Barrels) Natural Gas (Millions of Cubic Feet) Other Gas (Millions

of BTU) 2002 987,583 168,5976,126,062 131,230 17,676 15,036 866,529 146,881 20031,014,058 206,6535,616,135 156,306 17,720 17,939 721,267 137,838 20041,020,523 203,4945,674,580 135,144 24,275 25,8701,052,100 218,295 20051,041,448 206,7856,036,370 109,916 23,833 24,408 984,340 238,396 20061,030,556 110,6346,461,615 114,665 23,227 20,371 942,817 226,464 20071,046,795 112,6157,089,342 114,904 22,810 19,775 872,579 214,321 20081,042,335 80,9326,895,843 96,757 22,168 12,016 793,537 203,236 2009 934,683 67,6687,121,069 83,593 20,507 13,161 816,787 175,671 2010 979,684 65,0717,680,185 90,058 21,727 10,161 821,775 172,081 2011 934,938 52,3877,883,865 91,290 21,532 9,223 839,681 191,138 2012 825,734 40,9779,484,710 103,353 19,333 9,828 886,103 199,121

Year Coal (Thousand Tons)Petroleum (Thousand Barrels) Natural Gas (Millions of Cubic Feet) Other Gas (Millions

of BTU) 20021,005,144 183,4086,986,081 278,111 20031,031,778 224,5936,337,402 294,143 20041,044,798 229,3646,726,679 353,438 20051,065,281 231,1937,020,709 348,312 20061,053,783 131,0057,404,432 341,129 20071,069,606 132,3897,961,922 329,225 20081,064,503 92,9487,689,380 299,993 2009 955,190 80,8307,937,856 259,265 20101,001,411 75,2318,501,960 262,138 2011 956,470 61,6108,723,546 282,428 2012 845,066 50,80510,370,812 302,475 For Electricity Generation For Useful Thermal Output 

### (From Chapter 5.) Consumption of Fossil Fuels

Total

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

Year Coal (Thousand Tons)Petroleum (Thousand Barrels) Coal (Thousand Tons)Petroleum (Thousand Barrels)Natural Gas (Millions of Cubic Feet) Coal (Dollars per MMBtu)Petroleum (Dollars per MMBtu)Natural Gas (Dollars per MMBtu) 2002 141,714 52,490 884,287 120,8515,607,737 1.25 3.34 3.56 2003 121,567 53,170 986,026 185,5675,500,704 1.28 4.33 5.39 2004 106,669 51,4341,002,032 186,6555,734,054 1.36 4.29 5.96 2005 101,137 50,0621,021,437 194,7336,181,717 1.54 6.44 8.21 2006 140,964 51,5831,079,943 100,9656,675,246 1.69 6.23 6.94 2007 151,221 47,2031,054,664 88,3477,200,316 1.77 7.17 7.11 2008 161,589 44,4981,069,709 96,3417,879,046 2.07 10.87 9.02 2009 189,467 46,181 981,477 88,9518,118,550 2.21 7.02 4.74 2010 174,917 40,800 979,918 75,2858,673,070 2.27 9.54 5.09 2011 172,387 37,387 956,538 66,0589,056,164 2.39 12.48 4.72 2012 185,116 34,698 841,183 40,3649,531,389 2.38 12.48 3.42

Year Operating RevenuesOperating Expenses Net Operating IncomeOperating RevenuesOperating Expenses Net Operating Income 2002 219,609 189,062 30,548 27,458 24,561 2,897 2003 230,151 201,057 29,094 29,228 26,361 2,867 2004 238,759 206,960 31,799 30,650 27,828 2,822 2005 265,652 236,786 28,866 34,088 31,209 2,879 2006 275,501 245,589 29,912 36,723 33,550 3,173 2007 270,964 241,198 29,766 38,208 34,843 3,365 2008 298,962 267,263 31,699 42,087 38,511 3,576 2009 276,124 244,243 31,881 42,189 38,337 3,852 2010 285,512 253,022 32,490 45,264 41,138 4,126 2011 280,520 247,118 33,402 46,146 42,099 4,047 2012 270,912 235,694 35,218 N/A N/A N/A 

### (From Tables 6.1. and 7.1) Year End Stocks, Annual Receipts and Average Costs Electric Power Sector Year End Stocks Annual Receipts at All Electricty Generators Average Cost of Fuel at All Electricty Generators



### (From Tables 8.3. and 8.5.) Revenues And Expenses (Million Dollars) Major U.S. Investor-Owned Electric Utilities U.S. Cooperative Borrower Owned Electric Utilities

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

YearSummer Net Internal DemandSummer CapacitySummer Capacity

Margin 2002 696,376 833,380 16.4% 2003 696,752 856,131 18.6% 2004 692,908 875,870 20.9% 2005 746,470 882,125 15.4% 2006 776,479 891,226 12.9% 2007 766,786 914,397 16.1% 2008 744,151 909,504 18.2% 2009 713,106 916,449 22.2% 2010 746,513 923,599 19.2% 2011 759,642 892,426 14.9% 2012 768,943 927,060 17.1%

Year Carbon Dioxide

(CO2) Sulfur Dioxide

(SO2)Nitrogen Oxides (NOx) 20022,423,963 10,881 5,194 20032,445,094 10,646 4,532 20042,486,982 10,309 4,143 20052,543,838 10,340 3,961 20062,488,918 9,524 3,799 20072,547,032 9,042 3,650 20082,484,012 7,830 3,330 20092,269,508 5,970 2,395 20102,388,596 5,400 2,491 20112,287,071 4,845 2,406 20122,156,875 3,704 2,148 

### (From Table 8.8.A.) Summer Demand and Capacity

(From Table 9.1.) Emissions (Thousand Metric Tons)

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

Total DSM Cost

Year Energy Savings: Thousand MWhActual Peak Load Reduction: MW Energy Savings: Thousand MWhActual Peak Load Reduction: MWThousand Dollars 2002 50,328 13,457 1,700 9,2561,649,403 2003 48,254 13,585 1,935 9,2981,340,686 2004 52,663 14,272 1,966 9,2631,560,578 2005 59,000 15,394 930 10,3411,939,115 2006 63,076 16,006 790 11,2682,072,962 2007 67,278 17,773 1,859 12,5452,604,711 2008 74,871 19,708 1,822 12,0643,186,742 2009 76,912 19,761 1,027 11,9723,607,076 2010 86,914 20,828 447 12,5364,230,420 2011 120,659 26,314 556 12,1265,544,396 2012 138,525 28,924 712 13,2006,000,466 

### (From Tables 10.1. and 10.5.) Demand Side Management Savings and Costs
Energy Efficiency Load Management

Coal includes anthracite, bituminous, subbituminous and lignite coal. Starting in 2002 waste coal is included in all coal metrics except for year-end stocks. Starting in 2002 Synthetic coal is included in all coal metrics. Starting in 2011 Coal-derived synthesis gas is included in all coal metrics. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum includes Distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology) and waste oil. Prior to 2011 propane was in the Other Gas category. Beginning in 2004 small quantities of waste oil were excluded from petroleum stocks. Natural gas includes a small number of generators for which waste heat is the primary energy source. Natural gas also includes a small amount of supplemental gaseous fuels that cannot be identified separately. Prior to 2011, synthesis gas derived from petroleum coke was in the Other Gas category. Other Gas includes blast furnace gas, propane gas, and other manufactured and waste gases derived from fossil fuels. Conventional hydroelectric power excludes pumped storage facilities. Wood and wood derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other biomass includes biogenic municipal solid waste, landfill gas, sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). The reported summer capacity for other biomass also includes non-biogenic municipal solid waste. Pumped storage is the capacity to generate electricity from water previously pumped to an elevated reservoir and then released through a conduit to turbine generators located at a lower level. The generation from a hydroelectric pumped storage facility is the net value of production minus the energy used for pumping. Other energy sources include batteries, hydrogen, purchased steam, sulfur, tire-derived fuels and other miscellaneous energy sources, and for generation values, non-biogenic muncipal solid waste.

### Table 1.2. Summary Statistics for the United States, 2002 - 2012

Costs of fuels for 2002 through 2007 include data from the Form EIA-423 for independent power producers, commercial powerproducing facilities, and industrial power-producing facilities. Beginning in 2008, data are collected on the Form EIA-923 for utilities, independent power producers, commerical power-producing facilities, and industrial power-producing facilities. Receipts, cost, and quality data are collected from plants above a 50 MW threshold, and imputed for plants between 1 and 50 MW. Therefore, there may be a notable increase in fuel receipts beginning with 2008 data. Receipts of coal include imported coal.

N/A = Not available. Notes: See Glossary reference for definitions. See Technical Notes Appendix for conversion to different units of measure. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. Dual-fired capacity returned to respective fuel categories for current and all historical years. New fuel switchable capacity tables have replaced dual-fired breakouts. Totals may not equal sum of components because of independent rounding.
Sources: U.S. Energy Information Administration Form EIA-411, 'Coordinated Bulk Power Supply Program Report;' Form EIA-412, 'Annual Electric Industry Financial Report'. The Form EIA-412 was terminated in 2003; Form EIA-767, 'Steam-Electric Plant Operation and Design Report' was suspended; Form EIA-860, 'Annual Electric Generator Report;' Form EIA-861, 'Annual Electric Power Industry Report;' Form EIA-923, 'Power Plant Operations Report' replaces several form(s) including: Form EIA-906, 'Power Plant Report;' Form EIA-920 'Combined Heat and Power Plant Report;' Form EIA-423, 'Monthly Cost and Quality of Fuels for Electric Plants Report;' and FERC Form 423, 'Monthly Report of Cost and Quality of Fuels for Electric Plants,' and their predecessor forms. Federal Energy Regulatory Commission, FERC Form 1, 'Annual Report of Major Utilities, Licensees and Others;' FERC Form 1-F, 'Annual Report for Nonmajor Public Utilities and Licensees;' Rural Utilities Service (RUS) Form 7, 'Operating Report;' RUS Form 12, 'Operating Report;' Imports and Exports: DOE, Office of Electricity Delivery and Energy Reliability, Form OE-781R, 'Annual Report of International Electric Export/Import Data,' predecessor forms, and National Energy Board of Canada. For 2001 forward, data from the California Independent System Operator are used in combination with the Form OE-781R values to estimate electricity trade with Mexico.YearElectric UtilitiesIPP (Non-CHP) IPP (CHP) Commercial Sector Industrial SectorTotal Imports Total Supply 2002 2,549 955 194 7 153 37 3,895 2003 2,462 1,063 196 7 155 30 3,914 2004 2,505 1,119 184 8 154 34 4,005 2005 2,475 1,247 180 8 145 44 4,099 2006 2,484 1,259 165 8 148 43 4,107 2007 2,504 1,324 177 8 143 51 4,208 2008 2,475 1,332 167 8 137 57 4,176 2009 2,373 1,278 159 8 132 52 4,003 2010 2,472 1,339 162 9 144 45 4,170 2011 2,461 1,331 156 10 142 52 4,152 2012 2,339 1,387 164 11 146 59 4,107

Year Full-Service Providers Energy-Only Providers Facility Direct Direct Use Total Exports Losses and Unaccounted ForTotal Disposition 2002 3,307 141 17 166 16 248 3,895 2003 3,285 189 20 168 24 228 3,914 2004 3,318 222 8 168 23 266 4,005 2005 3,413 237 11 150 19 269 4,099 2006 3,438 219 12 147 24 266 4,107 2007 3,468 283 14 126 20 298 4,208 2008 3,434 286 14 132 24 287 4,176 2009 3,289 295 13 127 18 261 4,003 2010 3,365 379 10 132 19 265 4,170 2011 3,273 467 10 133 15 255 4,152 2012 3,172 514 8 138 12 263 4,107 Retail Sales

N/A = Not Available. Facility Direct Retail Sales typically represent bilateral electric power sales between industrial and commercial generating facilities. Direct Use represents commercial and industrial facility use of onsite net electricity generation; electricity sales or transfers to adjacent or co-located facilities; and barter transactions. Losses and Unaccounted For includes: (1) reporting by utilities and power marketers that represent losses incurred in transmission and distribution, as well as volumes unaccounted for in their own energy balance; and (2) discrepancies among the differing categories upon balancing the table. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including U.S. Energy Information Administration, Form EIA-906, "Power Plant Report;" and Form EIA-920, "Combined Heat and Power Plant Report;" Form EIA-861, "Annual Electric Power Industry Report;" and predecessor forms. Imports and Exports: Mexico data - DOE, Fossil Fuels, Office of Fuels Programs, Form OE-781R, "Annual Report of International Electrical Export/Import Data:" Canada data - National Energy Board of Canada (metered energy firm and interruptible). 

### Table 1.3. Supply and Disposition of Electricity, 2002 through 2012

(From Chapter 2.) Supply (Million Megawatthours)

Generation



### (From Chapter 2.) Disposition (Million Megawatthours)

# Chapter 2
Electricity SalesYear Residential Commercial Industrial Transportation Other Total

2002 116,622,037 15,333,700 601,744 N/A 1,066,554133,624,035 2003 117,280,481 16,549,519 713,221 1,127 N/A134,544,348 2004 118,763,768 16,606,783 747,600 1,025 N/A136,119,176 2005 120,760,839 16,871,940 733,862 518 N/A138,367,159 2006 122,471,071 17,172,499 759,604 791 N/A140,403,965 2007 123,949,916 17,377,219 793,767 750 N/A142,121,652 2008 124,937,469 17,562,726 774,713 727 N/A143,275,635 2009 125,177,175 17,561,661 757,519 705 N/A143,497,060 2010 125,717,935 17,674,338 747,746 239 N/A144,140,258 2011 126,143,072 17,638,062 727,920 92 N/A144,509,146 2012 126,832,343 17,729,029 732,385 83 N/A145,293,840

2002 113,790,812 14,899,747 586,217 N/A 1,035,604130,312,380 2003 115,029,545 16,136,616 695,616 1,042 N/A131,862,819 2004 116,325,747 16,161,269 733,809 941 N/A133,221,766 2005 118,469,928 16,389,549 719,219 496 N/A135,579,192 2006 120,677,627 16,673,766 745,645 764 N/A138,097,802 2007 121,782,003 16,767,635 771,637 710 N/A139,321,985 2008 122,595,644 16,952,660 756,294 664 N/A140,305,262 2009 122,533,214 16,860,320 736,751 666 N/A140,130,951 2010 121,555,089 16,675,341 718,651 198 N/A138,949,279 2011 120,306,190 16,321,174 682,906 56 N/A137,310,326 2012 118,650,233 16,111,883 681,074 48 N/A135,443,238

2002 2,831,225 433,953 15,527 N/A 30,950 3,311,655 2003 2,250,936 412,903 17,605 85 N/A 2,681,529 2004 2,438,021 445,514 13,791 84 N/A 2,897,410 2005 2,290,911 482,391 14,643 22 N/A 2,787,967 2006 1,793,444 498,733 13,959 27 N/A 2,306,163 2007 2,167,913 609,584 22,130 40 N/A 2,799,667 2008 2,341,825 610,066 18,419 63 N/A 2,970,373 2009 2,643,961 701,341 20,768 39 N/A 3,366,109 2010 4,162,846 998,997 29,095 41 N/A 5,190,979 2011 5,836,882 1,316,888 45,014 36 N/A 7,198,820 2012 8,182,110 1,617,146 51,311 35 N/A 9,850,602 N/A = Not Available. Pursuant to applicable Texas statutes establishing competitive electricity markets within the Electric Reliability Council of Texas (ERCOT), all customers served by Retail Energy Providers must be provided bundled energy and delivery services, so they are included under "Full-Service Providers". Full-Service Providers sell bundled electricity services (e.g., both energy and delivery) to end users. Full-Service Providers may purchase electricity from others (such as Independent Power Producers or other Full-Service Providers) prior to delivery. Direct sales from independent facility generators to end use consumers are reported under Full-Service Providers. Energy-Only Providers sell energy to end use customers; incumbent utility distribution firms provide Delivery-Only Services for these customers. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." and Form EIA-861S, "Annual Electric Power Industry Report (Short Form)." 

### Table 2.1. Number of Ultimate Customers Served by Sector, by Provider, 2002 through 2012

Total Electric Industry

Full-Service Providers

Energy-Only ProvidersYear Residential Commercial Industrial Transportation Other Total Direct Use Total End Use

2002 1,265,179,869 1,104,496,607 990,237,631 N/A 105,551,904 3,465,466,011 166,184,296 3,631,650,307 2003 1,275,823,910 1,198,727,601 1,012,373,247 6,809,728 N/A 3,493,734,486 168,294,526 3,662,029,012 2004 1,291,981,578 1,230,424,731 1,017,849,532 7,223,642 N/A 3,547,479,483 168,470,002 3,715,949,485 2005 1,359,227,107 1,275,079,020 1,019,156,065 7,506,321 N/A 3,660,968,513 150,015,531 3,810,984,044 2006 1,351,520,036 1,299,743,695 1,011,297,566 7,357,543 N/A 3,669,918,840 146,926,612 3,816,845,452 2007 1,392,240,996 1,336,315,196 1,027,831,925 8,172,595 N/A 3,764,560,712 125,670,185 3,890,230,897 2008 1,379,981,104 1,335,981,135 1,009,300,309 7,699,632 N/A 3,732,962,180 132,196,685 3,865,158,865 2009 1,364,474,417 1,307,167,813 917,442,063 7,780,573 N/A 3,596,864,866 126,937,958 3,723,802,824 2010 1,445,708,403 1,330,199,364 970,872,874 7,712,412 N/A 3,754,493,053 131,910,249 3,886,403,302 2011 1,422,801,093 1,328,057,439 991,315,564 7,672,084 N/A 3,749,846,180 132,754,037 3,882,600,217 2012 1,374,514,708 1,327,101,196 985,713,854 7,320,028 N/A 3,694,649,786 137,656,510 3,832,306,296

2002 1,248,349,458 1,036,366,268 937,138,192 N/A 102,238,786 3,324,092,704 N/A 3,324,092,704 2003 1,257,766,998 1,112,206,121 931,661,404 3,315,043 N/A 3,304,949,566 N/A 3,304,949,566 2004 1,272,237,425 1,116,497,417 933,529,502 3,188,466 N/A 3,325,452,810 N/A 3,325,452,810 2005 1,339,568,275 1,151,327,861 929,675,932 3,341,814 N/A 3,423,913,882 N/A 3,423,913,882 2006 1,337,837,993 1,170,661,399 939,194,648 3,040,062 N/A 3,450,734,102 N/A 3,450,734,102 2007 1,375,450,126 1,180,789,042 923,148,031 2,635,498 N/A 3,482,022,697 N/A 3,482,022,697 2008 1,362,811,730 1,152,674,093 929,246,647 2,515,304 N/A 3,447,247,774 N/A 3,447,247,774 2009 1,345,125,375 1,140,767,357 813,292,567 2,453,843 N/A 3,301,639,142 N/A 3,301,639,142 2010 1,409,355,244 1,123,328,313 840,091,476 2,440,567 N/A 3,375,215,600 N/A 3,375,215,600 2011 1,368,453,770 1,090,292,969 822,404,124 1,730,820 N/A 3,282,881,683 N/A 3,282,881,683 2012 1,297,818,441 1,073,346,766 807,805,140 1,389,340 N/A 3,180,359,687 N/A 3,180,359,687

2002 16,830,411 68,130,339 53,099,439 N/A 3,313,118 141,373,307 N/A 141,373,307 2003 18,056,912 86,521,480 80,711,843 3,494,685 N/A 188,784,920 N/A 188,784,920 2004 19,744,153 113,927,314 84,320,030 4,035,176 N/A 222,026,673 N/A 222,026,673 2005 19,658,832 123,751,159 89,480,133 4,164,507 N/A 237,054,631 N/A 237,054,631 2006 13,682,043 129,082,296 72,102,918 4,317,481 N/A 219,184,738 N/A 219,184,738 2007 16,790,870 155,526,154 104,683,894 5,537,097 N/A 282,538,015 N/A 282,538,015 2008 17,169,374 183,307,042 80,053,662 5,184,328 N/A 285,714,406 N/A 285,714,406 2009 19,349,042 166,400,456 104,149,496 5,326,730 N/A 295,225,724 N/A 295,225,724 2010 36,353,159 206,871,051 130,781,398 5,271,845 N/A 379,277,453 N/A 379,277,453 2011 54,347,323 237,764,470 168,911,440 5,941,264 N/A 466,964,497 N/A 466,964,497 2012 76,696,267 253,754,430 177,908,714 5,930,688 N/A 514,290,099 N/A 514,290,099

N/A = Not Available. Direct Use represents commercial and industrial facility use of onsite net electricity generation; and electricity sales or transfers to adjacent or co-located facilities for which revenue information is not available. Pursuant to applicable Texas statutes establishing competitive electricity markets within the Electric Reliability Council of Texas (ERCOT), all customers served by Retail Energy Providers must be provided bundled energy and delivery services, so they are included under "Full-Service Providers". Full-Service Providers sell bundled electricity services (e.g., both energy and delivery) to end users. Full-Service Providers may purchase electricity from others (such as Independent Power Producers or other Full-Service Providers) prior to delivery. Direct sales from independent facility generators to end use consumers are reported under Full-Service Providers. Energy-Only Providers sell energy to end use customers; incumbent utility distribution firms provide Delivery-Only Services for these customers. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report.", Form EIA-861S, "Annual Electric Power Industry Report (Short Form)" and Form EIA-923, "Power Plant Operations Report" 

### Table 2.2. Retail Sales and Direct Use of Electricity to Ultimate Customers by Sector, by Provider, 2002 through 2012 (Megawatthours)

Total Electric Industry

Full-Service Providers

Energy-Only ProvidersYear Residential Commercial Industrial Transportation Other Total

2002 106,834 87,117 48,336 N/A 7,124 249,411 2003 111,249 96,263 51,741 514 N/A 259,767 2004 115,577 100,546 53,477 519 N/A 270,119 2005 128,393 110,522 58,445 643 N/A 298,003 2006 140,582 122,914 62,308 702 N/A 326,506 2007 148,295 128,903 65,712 792 N/A 343,703 2008 155,433 138,469 68,920 827 N/A 363,650 2009 157,008 132,940 62,504 828 N/A 353,280 2010 166,782 135,559 65,750 815 N/A 368,906 2011 166,714 135,926 67,606 803 N/A 371,049 2012 163,280 133,898 65,761 747 N/A 363,687

2002 104,814 80,573 44,826 N/A 6,803 237,014 2003 109,165 87,764 46,686 226 N/A 243,841 2004 113,306 89,597 47,993 238 N/A 251,134 2005 125,983 97,405 52,113 249 N/A 275,749 2006 138,608 107,432 56,385 257 N/A 302,683 2007 145,642 109,703 56,950 232 N/A 312,527 2008 152,429 115,062 61,286 250 N/A 329,027 2009 153,723 112,111 53,345 226 N/A 319,405 2010 161,221 110,298 54,561 233 N/A 326,312 2011 158,788 108,318 54,285 162 N/A 321,552 2012 152,817 106,012 52,667 132 N/A 311,628

2002 2,020 6,545 3,510 N/A 321 12,396 2003 2,084 8,499 5,055 288 N/A 15,926 2004 2,272 10,949 5,484 281 N/A 18,985 2005 2,410 13,117 6,333 394 N/A 22,254 2006 1,974 15,482 5,922 445 N/A 23,823 2007 2,653 19,200 8,762 560 N/A 31,176 2008 3,004 23,407 7,635 577 N/A 34,622 2009 3,286 20,828 9,159 602 N/A 33,875 2010 5,560 25,261 11,190 582 N/A 42,593 2011 7,926 27,609 13,321 641 N/A 49,497 2012 10,464 27,886 13,094 615 N/A 52,059

2002 914 3,989 2,408 N/A 143 7,454 2003 980 5,210 3,605 215 N/A 10,011 2004 1,086 6,859 3,881 201 N/A 12,027 2005 1,285 8,844 4,749 308 N/A 15,186 2006 1,127 10,792 4,510 356 N/A 16,784 2007 1,646 13,553 7,197 458 N/A 22,854 2008 1,873 17,126 6,212 455 N/A 25,667 2009 1,877 14,271 7,205 460 N/A 23,813 2010 3,230 16,999 8,664 425 N/A 29,318 2011 4,578 18,085 10,392 463 N/A 33,519 2012 5,776 17,397 9,895 432 N/A 33,500

2002 1,106 2,556 1,102 N/A 178 4,942 2003 1,104 3,289 1,450 72 N/A 5,915 2004 1,186 4,090 1,603 79 N/A 6,958 2005 1,125 4,273 1,584 86 N/A 7,068 2006 847 4,690 1,412 90 N/A 7,040 2007 1,007 5,647 1,565 102 N/A 8,322 2008 1,131 6,281 1,422 121 N/A 8,956 2009 1,409 6,557 1,954 143 N/A 10,062 2010 2,330 8,262 2,526 157 N/A 13,276 2011 3,348 9,523 2,929 178 N/A 15,978 2012 4,687 10,489 3,199 183 N/A 18,559 Delivery-Only Providers

N/A = Not Available. Pursuant to applicable Texas statutes establishing competitive electricity markets within the Electric Reliability Council of Texas (ERCOT), all customers served by Retail Energy Providers must be provided bundled energy and delivery services, so they are included under "Full-Service Providers". Full-Service Providers sell bundled electricity services (e.g., both energy and delivery) to end users. Full-Service Providers may purchase electricity from others (such as Independent Power Producers or other Full-Service Providers) prior to delivery. Direct sales from independent facility generators to end use consumers are reported under Full-Service Providers. Energy-Only Providers sell energy to end use customers; incumbent utility distribution firms provide Delivery-Only Services for these customers. Data reported under Restructured Retail Service Providers represent the sum of Energy-Only and Delivery-Only Services." Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." Form EIA-861S, "Annual Electric Power Industry Report (Short Form)." 

### Table 2.3. Revenue from Retail Sales of Electricity to Ultimate Customers by Sector, by Provider, 2002 through 2012 (Million Dollars)

Total Electric Industry

Full-Service Providers

Restructured Retail Service Providers

Energy-Only ProvidersYear Residential Commercial Industrial Transportation Other Total

2002 8.44 7.89 4.88 N/A 6.75 7.20 2003 8.72 8.03 5.11 7.54 N/A 7.44 2004 8.95 8.17 5.25 7.18 N/A 7.61 2005 9.45 8.67 5.73 8.57 N/A 8.14 2006 10.40 9.46 6.16 9.54 N/A 8.90 2007 10.65 9.65 6.39 9.70 N/A 9.13 2008 11.26 10.36 6.83 10.74 N/A 9.74 2009 11.51 10.17 6.81 10.65 N/A 9.82 2010 11.54 10.19 6.77 10.57 N/A 9.83 2011 11.72 10.23 6.82 10.46 N/A 9.90 2012 11.88 10.09 6.67 10.21 N/A 9.84

2002 8.40 7.77 4.78 N/A 6.65 7.13 2003 8.68 7.89 5.01 6.82 N/A 7.38 2004 8.91 8.02 5.14 7.47 N/A 7.55 2005 9.40 8.46 5.61 7.45 N/A 8.05 2006 10.36 9.18 6.0 8.44 N/A 8.77 2007 10.59 9.29 6.17 8.82 N/A 8.98 2008 11.18 9.98 6.60 9.96 N/A 9.54 2009 11.43 9.83 6.56 9.20 N/A 9.67 2010 11.44 9.82 6.49 9.55 N/A 9.67 2011 11.60 9.93 6.60 9.35 N/A 9.79 2012 11.77 9.88 6.52 9.50 N/A 9.80

2002 12.0 9.61 6.61 N/A 9.69 8.77 2003 11.54 9.82 6.26 8.23 N/A 8.44 2004 11.51 9.61 6.50 6.95 N/A 8.55 2005 12.26 10.60 7.08 9.47 N/A 9.39 2006 14.43 11.99 8.21 10.32 N/A 10.87 2007 15.80 12.35 8.37 10.11 N/A 11.03 2008 17.49 12.77 9.54 11.12 N/A 12.12 2009 16.98 12.52 8.79 11.31 N/A 11.47 2010 15.30 12.21 8.56 11.04 N/A 11.23 2011 14.58 11.61 7.89 10.79 N/A 10.60 2012 13.64 10.99 7.36 10.38 N/A 10.12

2002 5.43 5.86 4.53 N/A 4.30 5.27 2003 5.43 6.02 4.47 6.16 N/A 5.30 2004 5.50 6.02 4.60 4.99 N/A 5.42 2005 6.54 7.15 5.31 7.40 N/A 6.41 2006 8.23 8.36 6.25 8.24 N/A 7.66 2007 9.80 8.71 6.87 8.28 N/A 8.09 2008 10.91 9.34 7.76 8.79 N/A 8.98 2009 9.70 8.58 6.92 8.63 N/A 8.07 2010 8.88 8.22 6.62 8.06 N/A 7.73 2011 8.42 7.61 6.15 7.80 N/A 7.18 2012 7.53 6.86 5.56 7.29 N/A 6.51

2002 6.57 3.75 2.08 N/A 5.39 3.50 2003 6.11 3.80 1.80 2.07 N/A 3.13 2004 6.0 3.59 1.90 1.96 N/A 3.13 2005 5.72 3.45 1.77 2.07 N/A 2.98 2006 6.19 3.63 1.96 2.08 N/A 3.21 2007 6.0 3.63 1.50 1.84 N/A 2.95 2008 6.59 3.43 1.78 2.34 N/A 3.13 2009 7.28 3.94 1.88 2.68 N/A 3.41 2010 6.41 3.99 1.93 2.98 N/A 3.50 2011 6.16 4.01 1.73 2.99 N/A 3.42 2012 6.11 4.13 1.80 3.09 N/A 3.61 Delivery-Only Providers

N/A = Not Available. Pursuant to applicable Texas statutes establishing competitive electricity markets within the Electric Reliability Council of Texas (ERCOT), all customers served by Retail Energy Providers must be provided bundled energy and delivery services, so they are included under "Full-Service Providers". Full-Service Providers sell bundled electricity services (e.g., both energy and delivery) to end users. Full-Service Providers may purchase electricity from others (such as Independent Power Producers or other Full-Service Providers) prior to delivery. Direct sales from independent facility generators to end use consumers are reported under Full-Service Providers. Energy-Only Providers sell energy to end use customers; incumbent utility distribution firms provide Delivery-Only Services for these customers. Data reported under Restructured Retail Service Providers represent the sum of Energy-Only and Delivery-Only Services." Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." 

### Table 2.4. Average Retail Price of Electricity to Ultimate Customers by End-Use Sector 2002 through 2012 (Cents per kilowatthour)

Total Electric Industry

Full-Service Providers

Restructured Retail Service Providers

Energy-Only ProvidersPeriod Residential Commercial Industrial Transportation All Sectors

2003 1,275,824 1,198,728 1,012,373 6,810 3,493,734 2004 1,291,982 1,230,425 1,017,850 7,224 3,547,479 2005 1,359,227 1,275,079 1,019,156 7,506 3,660,969 2006 1,351,520 1,299,744 1,011,298 7,358 3,669,919 2007 1,392,241 1,336,315 1,027,832 8,173 3,764,561 2008 1,379,981 1,335,981 1,009,300 7,700 3,732,962 2009 1,364,474 1,307,168 917,442 7,781 3,596,865 2010 1,445,708 1,330,199 970,873 7,712 3,754,493 2011 1,422,801 1,328,057 991,316 7,672 3,749,846 2012 1,374,515 1,327,101 985,714 7,320 3,694,650

January 147,500 108,120 75,506 715 331,841 February 122,840 100,747 74,164 689 298,440 March 111,790 101,756 78,303 656 292,505

April 88,046 99,791 78,597 600 267,034 May 94,843 106,176 82,088 606 283,712 June 127,496 119,388 83,347 658 330,889 July 154,688 127,925 85,725 667 369,006 August 154,053 129,143 87,904 628 371,728 September 124,582 119,137 83,353 639 327,711 October 96,688 108,461 82,046 615 287,811 November 93,166 101,524 79,575 607 274,871 December 130,015 108,031 80,264 633 318,943

January 145,054 108,243 80,077 710 334,084 February 120,121 99,789 76,332 637 296,879 March 104,921 104,263 82,196 664 292,044

April 93,700 100,505 80,356 629 275,190 May 97,688 107,624 82,095 619 288,026 June 125,983 118,169 83,941 643 328,736 July 154,729 128,063 87,245 650 370,686 August 153,739 129,371 89,014 625 372,749 September 122,720 117,951 84,959 634 326,263 October 94,585 108,655 84,287 616 288,144 November 93,220 100,552 80,858 590 275,220 December 116,341 104,873 79,956 656 301,826

January 125,881 105,239 79,205 650 310,975 February 107,975 100,080 78,298 629 286,983 March 99,362 102,474 81,298 597 283,731

April 88,103 101,037 81,030 590 270,760 May 100,895 110,800 84,678 595 296,968 June 122,934 118,009 83,619 597 325,160 July 154,579 128,535 87,219 629 370,963 August 147,941 128,106 88,105 633 364,785 September 118,831 116,585 82,060 613 318,090 October 96,669 110,471 82,996 599 290,735 November 97,155 101,641 78,847 569 278,212 December 114,188 104,122 78,360 619 297,288

See Technical notes for additional information on the Commercial, Industrial, and Transportation sectors. NA = Not available. See Glossary for definitions. Geographic coverage is the 50 States and the District of Columbia. Values include energy service provider (power marketer) data. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-826. Utilities and energy service providers may classify commercial and industrial customers based on either NAICS codes or demands or usage falling within specified limits by rate schedule. Changes from year to year in consumer counts, sales and revenues, particularly involving the commercial and industrial consumer sectors, may result from respondent implementation of changes in the definitions of consumers, and reclassifications. Retail sales and net generation may not correspond exactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net generation is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary dependent upon customer class and consumption occurring in and outside the calendar month. Sources: U.S. Energy Information Administration, Form EIA-826, Monthly Electric Sales and Revenue Report with State Distributions Report; Form EIA-861, Annual Electric Power Industry Report; and Form EIA-861S, Annual Electric Power Industry Report (Short Form). 

### Table 2.5. Retail Sales of Electricity to Ultimate Customers: Total by End-Use Sector, 2003 - December 2012 (Million Kilowatthours)

Annual Totals

2010

2011

2012Period Residential Commercial Industrial Transportation All Sectors

2003 111,249 96,263 51,741 514 259,767 2004 115,577 100,546 53,477 519 270,119 2005 128,393 110,522 58,445 643 298,003 2006 140,582 122,914 62,308 702 326,506 2007 148,295 128,903 65,712 792 343,703 2008 155,433 138,469 68,920 827 363,650 2009 157,008 132,940 62,504 828 353,280 2010 166,782 135,559 65,750 815 368,906 2011 166,714 135,926 67,606 803 371,049 2012 163,280 133,898 65,761 747 363,687

January 15,476 10,328 4,910 73 30,787 February 13,375 9,960 4,861 72 28,268 March 12,415 10,126 5,114 67 27,722

April 10,309 9,934 5,147 63 25,453 May 11,296 10,776 5,453 64 27,589 June 15,189 12,605 5,805 73 33,673 July 18,620 13,713 6,196 73 38,601 August 18,529 13,714 6,344 68 38,656 September 14,890 12,533 5,831 67 33,321 October 11,471 11,118 5,576 65 28,230 November 10,828 10,144 5,219 64 26,254 December 14,384 10,608 5,295 66 30,353

January 15,770 10,590 5,228 73 31,662 February 13,286 9,968 5,058 67 28,380 March 12,090 10,354 5,369 68 27,881

April 10,936 10,015 5,243 63 26,257 May 11,656 10,962 5,481 66 28,166 June 15,079 12,592 5,993 71 33,736 July 18,709 13,661 6,381 73 38,824 August 18,582 13,874 6,583 68 39,107 September 14,934 12,494 6,076 68 33,572 October 11,427 11,142 5,706 63 28,338 November 10,982 10,034 5,281 59 26,355 December 13,262 10,241 5,205 64 28,772

January 14,360 10,352 5,102 64 29,878 February 12,424 9,944 5,052 60 27,479 March 11,621 10,086 5,250 59 27,015

April 10,504 9,919 5,168 60 25,650 May 12,011 11,039 5,528 59 28,637 June 14,863 12,259 5,765 62 32,949 July 18,553 13,354 6,219 67 38,193 August 18,009 13,313 6,239 67 37,629 September 14,614 12,238 5,716 66 32,634 October 11,633 11,131 5,491 61 28,316 November 11,418 10,052 5,122 59 26,651 December 13,271 10,212 5,110 64 28,656

See Technical notes for additional information on the Commercial, Industrial, and Transportation sectors. NA = Not available. See Glossary for definitions. Geographic coverage is the 50 States and the District of Columbia. Values include energy service provider (power marketer) data. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-826. Utilities and energy service providers may classify commercial and industrial customers based on either NAICS codes or demands or usage falling within specified limits by rate schedule. Changes from year to year in consumer counts, sales and revenues, particularly involving the commercial and industrial consumer sectors, may result from respondent implementation of changes in the definitions of consumers, and reclassifications. Retail sales and net generation may not correspond exactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net generation is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary dependent upon customer class and consumption occurring in and outside the calendar month. Sources: U.S. Energy Information Administration, Form EIA-826, Monthly Electric Sales and Revenue Report with State Distributions Report; Form EIA-861, Annual Electric Power Industry Report; and Form EIA-861S, Annual Electric Power Industry Report (Short Form). 

### Table 2.6. Revenue from Retail Sales of Electricity to Ultimate Customers: Total by End-Use Sector, 2003 - December 2012 (Million Dollars)

Annual Totals

2010

2011

2012Period Residential Commercial Industrial Transportation All Sectors

2003 8.72 8.03 5.11 7.54 7.44 2004 8.95 8.17 5.25 7.18 7.61 2005 9.45 8.67 5.73 8.57 8.14 2006 10.40 9.46 6.16 9.54 8.90 2007 10.65 9.65 6.39 9.70 9.13 2008 11.26 10.36 6.83 10.74 9.74 2009 11.51 10.17 6.81 10.65 9.82 2010 11.54 10.19 6.77 10.57 9.83 2011 11.72 10.23 6.82 10.46 9.90 2012 11.88 10.09 6.67 10.21 9.84

January 10.49 9.55 6.50 10.17 9.28 February 10.89 9.89 6.55 10.48 9.47 March 11.11 9.95 6.53 10.28 9.48

April 11.71 9.95 6.55 10.52 9.53 May 11.91 10.15 6.64 10.52 9.72 June 11.91 10.56 6.96 11.14 10.18 July 12.04 10.72 7.23 10.95 10.46 August 12.03 10.62 7.22 10.86 10.40 September 11.95 10.52 7.00 10.53 10.17 October 11.86 10.25 6.80 10.49 9.81 November 11.62 9.99 6.56 10.47 9.55 December 11.06 9.82 6.60 10.39 9.52

January 10.87 9.78 6.53 10.29 9.48 February 11.06 9.99 6.63 10.55 9.56 March 11.52 9.93 6.53 10.24 9.55

April 11.67 9.96 6.53 9.97 9.54 May 11.93 10.19 6.68 10.70 9.78 June 11.97 10.66 7.14 11.01 10.26 July 12.09 10.67 7.31 11.21 10.47 August 12.09 10.72 7.40 10.82 10.49 September 12.17 10.59 7.15 10.80 10.29 October 12.08 10.25 6.77 10.25 9.83 November 11.78 9.98 6.53 9.93 9.58 December 11.40 9.77 6.51 9.79 9.53

January 11.41 9.84 6.44 9.78 9.61 February 11.51 9.94 6.45 9.61 9.58 March 11.70 9.84 6.46 9.95 9.52

April 11.92 9.82 6.38 10.11 9.47 May 11.90 9.96 6.53 9.97 9.64 June 12.09 10.39 6.89 10.33 10.13 July 12.00 10.39 7.13 10.70 10.30 August 12.17 10.39 7.08 10.53 10.32 September 12.30 10.50 6.97 10.74 10.26 October 12.03 10.08 6.62 10.13 9.74 November 11.75 9.89 6.50 10.41 9.58 December 11.62 9.81 6.52 10.28 9.64

See Technical notes for additional information on the Commercial, Industrial, and Transportation sectors. NA = Not available. See Glossary for definitions. Geographic coverage is the 50 States and the District of Columbia. Values include energy service provider (power marketer) data. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-826. Utilities and energy service providers may classify commercial and industrial customers based on either NAICS codes or demands or usage falling within specified limits by rate schedule. Changes from year to year in consumer counts, sales and revenues, particularly involving the commercial and industrial consumer sectors, may result from respondent implementation of changes in the definitions of consumers, and reclassifications. Retail sales and net generation may not correspond exactly for a particular month for a variety of reasons (i.e., sales data may include purchases of electricity from nonutilities or imported electricity). Net generation is for the calendar month while retail sales and associated revenue accumulate from bills collected for periods of time (28 to 35 days) that vary dependent upon customer class and consumption occurring in and outside the calendar month. Sources: U.S. Energy Information Administration, Form EIA-826, Monthly Electric Sales and Revenue Report with State Distributions Report; Form EIA-861, Annual Electric Power Industry Report; and Form EIA-861S, Annual Electric Power Industry Report (Short Form). 

### Table 2.7. Average Retail Price of Electricity to Ultimate Customers: Total by End-Use Sector, 2003 - December 2012 (Cents per Kilowatthour)

Annual Totals

2010

2011

2012Census Division and State Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 New England 47,208 47,481 44,864 45,018 27,818 27,927 566 569 120,456 120,995 Connecticut 12,758 12,919 12,976 13,087 3,566 3,668 193 185 29,492 29,859 Maine 4,481 4,382 4,053 4,018 3,027 3,016 0 0 11,561 11,415 Massachusetts 20,313 20,473 17,723 17,767 16,927 16,974 350 357 55,313 55,570 New Hampshire 4,439 4,454 4,478 4,478 1,953 1,936 0 0 10,870 10,869 Rhode Island 3,121 3,129 3,640 3,660 923 916 24 27 7,708 7,732 Vermont 2,095 2,125 1,994 2,009 1,422 1,417 0 0 5,511 5,550 Middle Atlantic 132,231 135,434 157,278 159,059 69,507 71,039 3,910 4,131 362,925 369,664 New Jersey 28,663 29,399 38,340 39,118 7,762 8,033 287 310 75,053 76,860 New York 50,692 51,240 76,018 76,406 13,705 13,420 2,748 2,981 143,163 144,047 Pennsylvania 52,876 54,796 42,920 43,536 48,039 49,585 875 840 144,710 148,757 East North Central 188,641 191,617 183,333 183,359 202,221 201,563 614 576 574,809 577,115 Illinois 46,902 47,057 50,808 50,468 45,277 44,844 553 516 143,540 142,886 Indiana 32,964 33,912 24,022 24,111 48,168 47,774 20 21 105,173 105,818 Michigan 34,461 34,811 38,514 38,613 31,836 31,624 7 5 104,818 105,054 Ohio 52,288 53,687 46,756 47,112 53,379 53,913 34 34 152,457 154,746 Wisconsin 22,026 22,150 23,233 23,055 23,561 23,407 0 0 68,820 68,612 West North Central 102,799 106,281 99,542 99,483 91,325 88,491 39 41 293,706 294,296 Iowa 13,988 14,327 12,210 12,088 19,512 19,240 0 0 45,709 45,655 Kansas 13,797 14,344 15,456 15,609 11,041 10,807 0 0 40,293 40,760 Minnesota 22,060 22,524 22,496 22,371 23,416 23,619 17 19 67,989 68,533 Missouri 34,337 35,941 30,483 30,962 17,594 17,330 22 22 82,435 84,255 Nebraska 9,680 9,947 9,233 9,139 11,915 10,590 0 0 30,828 29,676 North Dakota 4,485 4,552 5,109 4,866 5,124 4,319 0 0 14,717 13,737 South Dakota 4,454 4,646 4,557 4,447 2,724 2,586 0 0 11,734 11,680 South Atlantic 336,757 354,455 303,319 305,563 139,354 139,809 1,293 1,321 780,723 801,147 Delaware 4,522 4,632 4,243 4,260 2,755 2,591 0 0 11,519 11,483 District of Columbia 2,003 2,061 8,713 8,966 218 216 325 319 11,259 11,562 Florida 112,127 116,341 92,038 91,778 16,426 16,886 84 86 220,674 225,090 Georgia 53,660 57,750 45,937 46,930 31,225 31,521 157 171 130,979 136,371 Maryland 26,678 27,296 30,108 30,750 4,500 5,007 528 547 61,814 63,600 North Carolina 54,672 58,056 46,510 46,467 26,896 26,555 7 7 128,085 131,085 South Carolina 28,366 30,802 21,251 21,593 28,164 28,094 0 0 77,781 80,489 Virginia 43,535 45,771 46,757 47,051 17,316 17,218 188 188 107,795 110,228 West Virginia 11,195 11,746 7,763 7,768 11,856 11,720 4 4 30,817 31,239 East South Central 114,475 122,605 82,290 83,741 123,233 122,257 2 2 320,000 328,605 Alabama 30,632 33,003 21,799 22,257 33,751 33,735 0 0 86,183 88,995 Kentucky 26,097 27,198 18,756 18,721 44,196 43,619 0 0 89,048 89,538 Mississippi 17,993 19,336 13,585 13,738 16,810 16,263 0 0 48,388 49,338 Tennessee 39,754 43,068 28,150 29,025 28,476 28,638 2 2 96,381 100,733 West South Central 208,157 220,886 189,413 184,254 158,384 164,990 81 80 556,035 570,209 Arkansas 17,909 18,787 12,102 12,146 16,848 16,994 0 0 46,860 47,928 Louisiana 30,027 32,019 24,245 24,281 30,449 30,058 11 11 84,731 86,369 Oklahoma 22,810 24,425 19,961 19,613 16,570 15,809 0 0 59,341 59,847 Texas 137,412 145,654 133,105 128,214 94,517 102,129 70 68 365,104 376,065 Mountain 94,872 94,775 94,114 93,413 82,292 80,414 99 93 271,377 268,697 Arizona 32,923 33,079 29,692 29,512 12,448 12,352 0 0 75,063 74,944 Colorado 18,220 18,277 19,997 19,889 15,415 15,242 52 50 53,685 53,458 Idaho 8,159 8,390 5,978 5,969 9,574 8,912 0 0 23,712 23,272 Montana 4,778 4,913 4,918 4,892 4,168 3,983 0 0 13,863 13,788 Nevada 12,123 11,493 9,315 8,995 13,734 13,420 8 8 35,180 33,916 New Mexico 6,764 6,874 9,166 9,258 7,249 6,910 0 0 23,179 23,042 Utah 9,188 8,947 10,803 10,544 9,694 9,333 38 35 29,723 28,859 Wyoming 2,717 2,803 4,245 4,353 10,009 10,262 0 0 16,971 17,418 Pacific Contiguous 144,476 144,204 166,835 167,944 86,536 89,832 717 859 398,563 402,838 California 90,110 88,398 121,792 122,781 46,952 49,936 685 827 259,538 261,942 Oregon 18,855 19,429 15,804 15,754 12,006 11,963 25 25 46,689 47,171 Washington 35,511 36,376 29,240 29,409 27,579 27,933 7 7 92,336 93,725 Pacific Noncontiguous 4,899 5,063 6,113 6,223 5,043 4,995 0 0 16,056 16,281 Alaska 2,160 2,134 2,875 2,854 1,381 1,331 0 0 6,416 6,320 Hawaii 2,739 2,929 3,238 3,368 3,662 3,665 0 0 9,639 9,962 U.S. Total 1,374,515 1,422,801 1,327,101 1,328,057 985,714 991,316 7,320 7,672 3,694,650 3,749,846

See Technical notes for additional information on the Commercial, Industrial, and Transportation sectors. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: - See Glossary for definitions. - Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-826. Utilities and energy service providers may classify commercial and industrial customers based on either NAICS codes or demands or usage falling within specified limits by rate schedule. Changes from year to year in consumer counts, sales and revenues, particularly involving the commercial and industrial consumer sectors, may result from respondent implementation of changes in the definitions of consumers, and reclassifications. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-826, Monthly Electric Sales and Revenue Report with State Distributions Report. 

### Table 2.8. Retail Sales of Electricity to Ultimate Customers by End-Use Sector, by State, 2012 and 2011 (Million Kilowatthours) Residential Commercial Industrial Transportation All SectorsCensus Division and State Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 New England 7,418 7,546 6,137 6,441 3,292 3,504 38 45 16,885 17,536 Connecticut 2,213 2,339 1,901 2,038 452 486 19 19 4,584 4,882 Maine 657 674 467 494 242 268 0 0 1,366 1,436 Massachusetts 3,029 3,003 2,453 2,547 2,127 2,270 17 22 7,627 7,842 New Hampshire 713 736 598 629 231 238 0 0 1,543 1,602 Rhode Island 450 449 432 453 99 103 2 4 982 1,008 Vermont 356 346 285 281 142 139 0 0 784 766 Middle Atlantic 20,195 21,395 20,395 21,712 5,206 5,803 489 509 46,285 49,419 New Jersey 4,524 4,773 4,899 5,268 816 918 28 33 10,267 10,991 New York 8,930 9,357 11,446 12,079 918 1,051 390 401 21,683 22,889 Pennsylvania 6,742 7,265 4,050 4,365 3,472 3,834 71 75 14,335 15,540 East North Central 22,730 22,595 17,336 17,404 13,164 13,153 39 40 53,269 53,191 Illinois 5,335 5,545 4,058 4,361 2,625 2,879 34 35 12,053 12,821 Indiana 3,470 3,410 2,196 2,116 3,053 2,946 2 2 8,721 8,474 Michigan 4,871 4,621 4,211 3,989 2,427 2,315 1 0 11,510 10,926 Ohio 6,148 6,133 4,429 4,535 3,328 3,298 2 2 13,908 13,969 Wisconsin 2,905 2,885 2,442 2,403 1,731 1,715 0 0 7,078 7,003 West North Central 10,888 10,751 8,446 8,185 5,733 5,380 3 3 25,069 24,319 Iowa 1,513 1,499 978 949 1,033 1,003 0 0 3,524 3,451 Kansas 1,551 1,527 1,427 1,370 783 725 0 0 3,761 3,623 Minnesota 2,504 2,469 1,989 1,930 1,531 1,528 2 2 6,025 5,929 Missouri 3,492 3,503 2,499 2,491 1,037 1,013 2 2 7,029 7,008 Nebraska 972 927 774 730 835 681 0 0 2,581 2,338 North Dakota 406 391 410 370 336 269 0 0 1,152 1,030 South Dakota 448 435 369 345 179 160 0 0 996 940 South Atlantic 38,314 39,652 28,421 28,912 9,129 9,317 109 119 75,973 78,000 Delaware 614 635 430 453 230 231 0 0 1,274 1,319 District of Columbia 246 276 1,048 1,157 12 15 29 32 1,335 1,481 Florida 12,807 13,389 8,895 9,040 1,320 1,444 7 8 23,029 23,880 Georgia 5,996 6,384 4,400 4,631 1,866 2,080 12 14 12,275 13,109 Maryland 3,425 3,634 3,141 3,468 364 439 44 49 6,974 7,590 North Carolina 5,963 5,955 4,030 3,780 1,727 1,597 1 1 11,721 11,332 South Carolina 3,338 3,405 2,046 2,008 1,696 1,669 0 0 7,080 7,081 Virginia 4,823 4,871 3,778 3,743 1,163 1,118 16 15 9,780 9,748 West Virginia 1,103 1,103 654 632 750 724 0 0 2,507 2,460 East South Central 11,814 12,429 8,124 8,203 7,530 7,566 0 0 27,468 28,197 Alabama 3,491 3,661 2,318 2,331 2,101 2,107 0 0 7,910 8,100 Kentucky 2,461 2,503 1,637 1,589 2,365 2,326 0 0 6,462 6,418 Mississippi 1,847 1,966 1,267 1,302 1,049 1,062 0 0 4,163 4,331 Tennessee 4,016 4,298 2,902 2,980 2,015 2,070 0 0 8,933 9,348 West South Central 21,435 23,019 15,131 15,767 8,529 9,899 8 8 45,104 48,692 Arkansas 1,665 1,694 934 911 971 957 0 0 3,570 3,562 Louisiana 2,514 2,870 1,880 2,050 1,449 1,711 1 1 5,844 6,632 Oklahoma 2,168 2,313 1,461 1,490 843 863 0 0 4,472 4,666 Texas 15,088 16,142 10,857 11,315 5,266 6,368 7 7 31,218 33,832 Mountain 10,378 10,012 8,464 8,275 5,083 4,892 10 9 23,935 23,189 Arizona 3,718 3,666 2,830 2,803 813 810 0 0 7,361 7,279 Colorado 2,088 2,059 1,878 1,878 1,071 1,076 5 5 5,042 5,018 Idaho 707 661 410 383 525 455 0 0 1,642 1,498 Montana 482 479 449 446 213 210 0 0 1,143 1,135 Nevada 1,434 1,334 822 814 891 892 1 1 3,148 3,041 New Mexico 769 756 855 840 423 419 0 0 2,047 2,015 Utah 912 802 870 775 545 476 4 3 2,331 2,057 Wyoming 268 255 350 336 603 555 0 0 1,221 1,146 Pacific Contiguous 18,699 17,924 19,885 19,506 6,735 6,842 52 70 45,370 44,342 California 13,822 13,061 16,327 16,018 4,925 5,046 49 67 35,123 34,193 Oregon 1,849 1,853 1,314 1,284 671 654 2 2 3,835 3,793 Washington 3,028 3,010 2,244 2,203 1,139 1,142 1 1 6,412 6,356 Pacific Noncontiguous 1,409 1,392 1,559 1,521 1,361 1,250 0 0 4,329 4,163 Alaska 386 376 429 431 232 209 0 0 1,048 1,016 Hawaii 1,023 1,016 1,130 1,090 1,129 1,041 0 0 3,281 3,147 U.S. Total 163,280 166,714 133,898 135,926 65,761 67,606 747 803 363,687 371,049

See Technical notes for additional information on the Commercial, Industrial, and Transportation sectors. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: - See Glossary for definitions. - Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-826. Utilities and energy service providers may classify commercial and industrial customers based on either NAICS codes or demands or usage falling within specified limits by rate schedule. Changes from year to year in consumer counts, sales and revenues, particularly involving the commercial and industrial consumer sectors, may result from respondent implementation of changes in the definitions of consumers, and reclassifications. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-826, Monthly Electric Sales and Revenue Report with State Distributions Report. 

### Table 2.9. Revenue from Retail Sales of Electricity to Ultimate Customers by End-Use Sector, by State, 2012 and 2011 (Million Dollars) Residential Commercial Industrial Transportation All SectorsCensus Division and State Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 Year 2012 Year 2011 New England 15.71 15.89 13.68 14.31 11.83 12.55 6.68 7.85 14.02 14.49 Connecticut 17.34 18.11 14.65 15.57 12.67 13.24 9.69 10.25 15.54 16.35 Maine 14.66 15.38 11.53 12.29 7.98 8.88

-- -- 11.81 12.58 Massachusetts 14.91 14.67 13.84 14.33 12.57 13.38 4.91 6.14 13.79 14.11 New Hampshire 16.07 16.52 13.36 14.04 11.83 12.27

-- -- 14.19 14.74 Rhode Island 14.40 14.33 11.87 12.37 10.68 11.27 8.28 14.11 12.74 13.04 Vermont 17.01 16.26 14.32 14.00 9.98 9.83

-- -- 14.22 13.80 Middle Atlantic 15.27 15.80 12.97 13.65 7.49 8.17 12.50 12.32 12.75 13.37 New Jersey 15.78 16.23 12.78 13.47 10.52 11.43 9.77 10.69 13.68 14.30 New York 17.62 18.26 15.06 15.81 6.70 7.83 14.20 13.45 15.15 15.89 Pennsylvania 12.75 13.26 9.44 10.03 7.23 7.73 8.07 8.93 9.91 10.45 East North Central 12.05 11.79 9.46 9.49 6.51 6.53 6.33 6.92 9.27 9.22 Illinois 11.37 11.78 7.99 8.64 5.80 6.42 6.15 6.81 8.40 8.97 Indiana 10.53 10.06 9.14 8.77 6.34 6.17 9.56 9.74 8.29 8.01 Michigan 14.13 13.27 10.93 10.33 7.62 7.32 8.08 8.53 10.98 10.40 Ohio 11.76 11.42 9.47 9.63 6.24 6.12 6.98 6.64 9.12 9.03 Wisconsin 13.19 13.02 10.51 10.42 7.34 7.33

-- -- 10.28 10.21 West North Central 10.59 10.12 8.48 8.23 6.28 6.08 7.72 7.52 8.54 8.26 Iowa 10.82 10.46 8.01 7.85 5.30 5.21

-- -- 7.71 7.56 Kansas 11.24 10.65 9.24 8.78 7.09 6.71

-- -- 9.33 8.89 Minnesota 11.35 10.96 8.84 8.63 6.54 6.47 8.67 8.23 8.86 8.65 Missouri 10.17 9.75 8.20 8.04 5.89 5.85 6.97 6.90 8.53 8.32 Nebraska 10.04 9.32 8.38 7.99 7.01 6.43

-- -- 8.37 7.88 North Dakota 9.06 8.58 8.02 7.61 6.55 6.24

-- -- 7.83 7.50 South Dakota 10.07 9.35 8.10 7.76 6.57 6.20

-- -- 8.49 8.05 South Atlantic 11.38 11.19 9.37 9.46 6.55 6.66 8.44 9.03 9.73 9.74 Delaware 13.58 13.70 10.13 10.64 8.36 8.91

-- -- 11.06 11.48 District of Columbia 12.28 13.40 12.02 12.90 5.46 6.89 9.01 10.19 11.85 12.81 Florida 11.42 11.51 9.66 9.85 8.04 8.55 8.45 8.81 10.44 10.61 Georgia 11.17 11.05 9.58 9.87 5.98 6.60 7.65 7.94 9.37 9.61 Maryland 12.84 13.31 10.43 11.28 8.09 8.76 8.29 9.03 11.28 11.93 North Carolina 10.91 10.26 8.66 8.13 6.42 6.01 7.88 7.04 9.15 8.64 South Carolina 11.77 11.05 9.63 9.30 6.02 5.94

-- -- 9.10 8.80 Virginia 11.08 10.64 8.08 7.95 6.72 6.49 8.51 8.24 9.07 8.84 West Virginia 9.85 9.39 8.42 8.14 6.33 6.18 8.66 8.60 8.14 7.88 East South Central 10.32 10.14 9.87 9.80 6.11 6.19 11.28 12.07 8.58 8.58 Alabama 11.40 11.09 10.63 10.47 6.22 6.25

-- -- 9.18 9.10 Kentucky 9.43 9.20 8.73 8.49 5.35 5.33

-- -- 7.26 7.17 Mississippi 10.26 10.17 9.33 9.48 6.24 6.53

-- -- 8.60 8.78 Tennessee 10.10 9.98 10.31 10.27 7.08 7.23 11.28 12.07 9.27 9.28 West South Central 10.30 10.42 7.99 8.56 5.39 6.00 10.30 9.85 8.11 8.54 Arkansas 9.30 9.02 7.71 7.50 5.76 5.63 11.23 11.10 7.62 7.43 Louisiana 8.37 8.96 7.75 8.44 4.76 5.69 8.72 8.33 6.90 7.68 Oklahoma 9.51 9.47 7.32 7.60 5.09 5.46

-- -- 7.54 7.80 Texas 10.98 11.08 8.16 8.83 5.57 6.24 10.54 10.08 8.55 9.00 Mountain 10.94 10.56 8.99 8.86 6.18 6.08 9.62 9.48 8.82 8.63 Arizona 11.29 11.08 9.53 9.50 6.53 6.55

-- -- 9.81 9.71 Colorado 11.46 11.27 9.39 9.44 6.95 7.06 9.69 9.79 9.39 9.39 Idaho 8.67 7.87 6.86 6.41 5.48 5.10

-- -- 6.92 6.44 Montana 10.08 9.75 9.13 9.12 5.10 5.27

-- -- 8.25 8.23 Nevada 11.83 11.61 8.83 9.05 6.48 6.65 8.40 8.58 8.95 8.97 New Mexico 11.37 11.00 9.32 9.07 5.83 6.06

-- -- 8.83 8.74 Utah 9.93 8.96 8.06 7.35 5.62 5.10 9.79 9.24 7.84 7.13 Wyoming 9.85 9.11 8.24 7.72 6.03 5.41

-- -- 7.19 6.58 Pacific Contiguous 12.94 12.43 11.92 11.61 7.78 7.62 7.21 8.13 11.38 11.01 California 15.34 14.78 13.41 13.05 10.49 10.11 7.17 8.14 13.53 13.05 Oregon 9.80 9.54 8.31 8.15 5.59 5.47 8.24 7.89 8.21 8.04 Washington 8.53 8.28 7.68 7.49 4.13 4.09 8.06 8.54 6.94 6.78 Pacific Noncontiguous 28.76 27.49 25.50 24.45 26.99 25.02

-- -- 26.96 25.57 Alaska 17.88 17.62 14.93 15.10 16.82 15.71

-- -- 16.33 16.08 Hawaii 37.34 34.68 34.88 32.37 30.82 28.40

-- -- 34.04 31.59 U.S. Total 11.88 11.72 10.09 10.23 6.67 6.82 10.21 10.46 9.84 9.90

See Technical notes for additional information on the Commercial, Industrial, and Transportation sectors. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: - See Glossary for definitions. - Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-826. Utilities and energy service providers may classify commercial and industrial customers based on either NAICS codes or demands or usage falling within specified limits by rate schedule. Changes from year to year in consumer counts, sales and revenues, particularly involving the commercial and industrial consumer sectors, may result from respondent implementation of changes in the definitions of consumers, and reclassifications. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-826, Monthly Electric Sales and Revenue Report with State Distributions Report. 

### Table 2.10. Average Retail Price of Electricity to Ultimate Customers by End-Use Sector, by State, 2012 and 2011 (Cents per Kilowatthour) Residential Commercial Industrial Transportation All SectorsYear Electric UtilitiesEnergy-Only ProvidersIndependent Power Producers Combined Heat and Power U.S. Total 2003 2,610,525 4,264,102 37,921 67,122 6,979,669 2004 2,725,694 4,170,331 24,258 78,267 6,998,549 2005 2,760,043 3,250,298 12,201 69,744 6,092,285 2006 2,605,315 2,793,288 26,628 77,353 5,502,584 2007 2,504,002 2,805,833 24,942 76,646 5,411,422 2008 2,483,927 3,024,730 25,431 78,693 5,612,781 2009 2,364,648 2,564,407 27,922 71,669 5,028,647 2010 2,353,086 3,319,211 23,976 73,861 5,770,134 2011 2,245,381 2,679,803 21,844 77,593 5,024,621 2012 2,148,346 2,740,043 17,726 78,818 4,984,933 

### Table 2.11. Electric Power Industry - Electricity Purchases, 2002 through 2012 (Thousand Megawatthours)

Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report" and Form EIA-923, "Power Plant Operations Report"Year Electric UtilitiesEnergy-Only ProvidersIndependent Power Producers Combined Heat and Power U.S. Total 2002 1,838,901 5,757,283 943,531 28,963 8,568,678 2003 1,824,030 3,906,220 1,156,796 33,909 6,920,954 2004 1,923,440 3,756,175 1,053,364 25,996 6,758,975 2005 1,925,710 2,867,048 1,252,796 26,105 6,071,659 2006 1,698,389 2,446,104 1,321,342 27,638 5,493,473 2007 1,603,179 2,476,740 1,368,310 31,165 5,479,394 2008 1,576,976 2,718,661 1,355,017 30,079 5,680,733 2009 1,495,636 2,240,399 1,295,857 33,139 5,065,031 2010 1,541,554 2,946,452 1,404,137 37,068 5,929,211 2011 1,529,434 2,206,981 1,372,306 34,400 5,143,121 2012 1,456,774 2,135,819 1,384,155 37,017 5,013,765 

### Table 2.12. Electric Power Industry - Electricity Sales for Resale, 2002 through 2012 (Thousand Megawatthours)

Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report" and Form EIA-923, "Power Plant Operations Report"Year Imports from Exports to Imports from Exports to Imports Exports 2002 36,536,479 15,231,079 242,598 564,602 36,779,077 15,795,681 2003 29,324,625 23,584,513 1,069,926 390,190 30,394,551 23,974,703 2004 33,007,487 22,482,109 1,202,576 415,754 34,210,063 22,897,863 2005 42,332,039 18,680,237 1,597,275 470,731 43,929,314 19,150,968 2006 41,544,052 23,405,387 1,147,258 865,948 42,691,310 24,271,335 2007 50,118,056 19,559,417 1,277,646 584,175 51,395,702 20,143,592 2008 55,731,229 23,614,158 1,288,152 584,001 57,019,381 24,198,159 2009 50,870,451 17,517,112 1,320,144 620,872 52,190,595 18,137,984 2010 43,763,091 18,481,678 1,320,095 624,502 45,083,186 19,106,180 2011 51,075,952 14,398,470 1,223,758 650,082 52,299,710 15,048,552 2012 57,971,110 11,392,267 1,285,959 603,382 59,257,069 11,995,649
Sources: National Energy Board of Canada; DOE, Office of Electricity Delivery and Energy Reliability, Form OE-781R, 'Annual Report of International Electric Export/Import Data,' predecessor forms. To estimate electricity trade with Mexico, for 2001 forward data from the California Independent System Operator are used in combination with the Form OE-781R values. 

### Table 2.13. Electric Power Industry - U.S. Electricity Imports from and Electricity Exports to Canada and Mexico, 2002-2012 (Megawatthours)

Canada Mexico U.S. TotalYear Residential Commercial Industrial Transportation Total 2003 819,579 56,423 1,124

-- 877,126 2004 864,794 63,189 289 61 928,333 2005 871,774 70,303 695

-- 942,772 2006 606,919 35,414 522 1 642,856 2007 773,391 61,608 553 99 835,651 2008 918,284 63,521 987 203 982,995 2009 1,058,185 64,139 1,454

-- 1,123,778 2010 1,137,047 78,128 1,407

-- 1,216,582 2011 1,187,867 89,677 1,440

-- 1,278,984 2012 2,162,230 102,223 1,509

-- 2,265,963 

### Table 2.14. Green Pricing Customers by End Use Sector, 2003 through 2012

In 2006 the single largest provider of green pricing services in the country discontinued service in two States. More than 297,600 customers reverted to standard service tariffs, in Ohio and Pennsylvania. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report."

# Chapter 3

Net GenerationPeriod Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Nuclear Hydroelectric Conventional Renewable Sources Excluding Hydroelectric Hydroelectric Pumped Storage Other Total

2002 1,933,130 78,701 15,867 691,006 11,463 780,064 264,329 79,109 -8,743 13,527 3,858,452 2003 1,973,737 102,734 16,672 649,908 15,600 763,733 275,806 79,487 -8,535 14,045 3,883,185 2004 1,978,301 100,391 20,754 710,100 15,252 788,528 268,417 83,067 -8,488 14,232 3,970,555 2005 2,012,873 99,840 22,385 760,960 13,464 781,986 270,321 87,329 -6,558 12,821 4,055,423 2006 1,990,511 44,460 19,706 816,441 14,177 787,219 289,246 96,525 -6,558 12,974 4,064,702 2007 2,016,456 49,505 16,234 896,590 13,453 806,425 247,510 105,238 -6,896 12,231 4,156,745 2008 1,985,801 31,917 14,325 882,981 11,707 806,208 254,831 126,101 -6,288 11,804 4,119,388 2009 1,755,904 25,972 12,964 920,979 10,632 798,855 273,445 144,279 -4,627 11,928 3,950,331 2010 1,847,290 23,337 13,724 987,697 11,313 806,968 260,203 167,173 -5,501 12,855 4,125,060 2011 1,733,430 16,086 14,096 1,013,689 11,566 790,204 319,355 193,981 -6,421 14,154 4,100,141 2012 1,514,043 13,403 9,787 1,225,894 11,898 769,331 276,240 218,333 -4,950 13,787 4,047,765

January 173,320 3,187 1,161 74,173 909 72,569 22,383 12,805 -565 1,014 360,957 February 153,044 1,251 1,122 66,198 825 65,245 20,590 10,901 -351 909 319,735 March 144,406 1,272 1,198 63,431 1,010 64,635 20,886 14,654 -325 1,002 312,168

April 126,952 1,220 1,067 64,644 943 57,611 19,097 15,607 -335 996 287,800 May 143,272 1,851 1,143 73,665 1,017 66,658 25,079 14,631 -441 1,060 327,936 June 165,491 2,656 1,333 92,268 964 68,301 29,854 14,209 -472 1,153 375,759

July 179,600 2,970 1,441 114,624 963 71,913 24,517 13,107 -557 1,146 409,725 August 177,745 2,419 1,157 121,151 1,061 71,574 20,119 13,100 -600 1,158 408,884 September 148,746 1,675 1,108 93,004 954 69,371 17,265 13,227 -421 1,116 346,045 October 132,270 1,221 1,007 77,738 808 62,751 17,683 13,791 -438 1,090 307,921 November 135,185 1,220 860 69,227 907 62,655 19,562 15,782 -467 1,079 306,010 December 167,258 2,395 1,128 77,573 952 73,683 23,169 15,359 -530 1,131 362,119

January 170,803 1,902 1,555 74,254 930 72,743 25,531 14,742 -659 1,071 362,872 February 138,311 1,217 1,217 65,924 807 64,789 24,131 16,116 -413 1,027 313,127 March 134,845 1,276 1,416 65,947 945 65,662 31,134 16,650 -349 1,182 318,710

April 124,488 1,459 965 70,029 918 54,547 31,194 18,125 -466 1,141 302,401 May 137,102 1,356 1,023 75,243 875 57,013 32,587 17,638 -417 1,210 323,628 June 158,055 1,374 1,220 90,691 1,013 65,270 32,151 17,284 -567 1,236 367,727

July 176,586 1,714 1,440 119,624 1,098 72,345 31,285 14,000 -708 1,309 418,693 August 171,281 1,295 1,299 119,856 1,087 71,339 25,764 14,054 -692 1,230 406,511 September 140,941 1,119 1,305 91,739 1,004 66,849 21,378 13,048 -583 1,132 337,931 October 126,627 1,114 948 78,819 941 63,337 19,787 16,550 -601 1,176 308,699 November 121,463 1,082 701 75,441 943 64,474 20,681 18,589 -458 1,187 304,102 December 132,929 1,178 1,007 86,122 1,005 71,837 23,732 17,185 -509 1,254 335,740

January 129,091 1,180 1,297 90,761 1,017 72,381 23,107 19,906 -348 1,137 339,528 February 113,872 908 994 90,610 1,044 63,847 20,283 16,996 -237 1,072 309,389 March 105,526 971 570 92,251 1,076 61,729 25,909 20,200 -281 1,140 309,091

April 96,285 965 538 94,829 1,057 55,871 26,294 18,563 -265 1,091 295,228 May 115,983 1,079 651 107,352 1,002 62,081 28,643 18,898 -371 1,200 336,518 June 131,261 1,306 762 115,598 972 65,140 26,659 18,470 -507 1,166 360,826

July 160,450 1,530 809 138,863 1,042 69,129 26,491 15,725 -619 1,218 414,640 August 152,181 1,202 916 131,736 1,050 69,602 23,034 15,330 -529 1,178 395,700 September 125,589 978 882 108,012 904 64,511 17,604 15,401 -431 1,135 334,585 October 120,999 1,061 744 91,725 895 59,743 16,501 19,225 -378 1,135 311,651 November 128,727 986 824 80,169 875 56,713 18,732 18,217 -409 1,140 305,975 December 134,079 1,235 800 83,989 963 68,584 22,984 21,402 -576 1,176 334,635
Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Other Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, solar thermal, photovoltaic energy, and wind. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.1.A. Net Generation by Energy Source: Total (All Sectors), 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Wind Solar Photovoltaic Solar Thermal Wood and Wood-Derived Fuels Landfill Gas Biogenic Municipal Solid Waste Other Waste Biomass Geothermal Conventional Hydroelectric Total Renewable Sources

2002 10,354 N/A N/A 38,665 N/A N/A N/A 14,491 264,329 N/A 2003 11,187 2 532 37,529 5,077 8,306 2,428 14,424 275,806 355,293 2004 14,144 6 569 38,117 5,128 8,151 2,141 14,811 268,417 351,485 2005 17,811 16 535 38,856 5,142 8,330 1,948 14,692 270,321 357,651 2006 26,589 15 493 38,762 5,677 8,478 1,944 14,568 289,246 385,772 2007 34,450 16 596 39,014 6,158 8,304 2,063 14,637 247,510 352,747 2008 55,363 76 788 37,300 7,156 8,097 2,481 14,840 254,831 380,932 2009 73,886 157 735 36,050 7,924 8,058 2,461 15,009 273,445 417,724 2010 94,652 423 789 37,172 8,377 7,927 2,613 15,219 260,203 427,376 2011 120,177 1,012 806 37,449 9,044 7,354 2,824 15,316 319,355 513,336 2012 140,822 3,451 876 37,799 9,803 7,320 2,700 15,562 276,240 494,573

January 6,854 6 4 3,126 671 632 200 1,312 22,383 35,188 February 5,432 11 22 2,895 623 557 203 1,159 20,590 31,490 March 8,589 21 55 3,090 728 660 204 1,307 20,886 35,539

April 9,764 34 78 2,932 693 667 198 1,240 19,097 34,704 May 8,698 43 110 2,893 690 696 191 1,311 25,079 39,710 June 8,049 52 124 3,094 720 691 215 1,264 29,854 44,063

July 6,724 47 114 3,308 713 684 243 1,274 24,517 37,624 August 6,686 49 107 3,319 716 682 243 1,297 20,119 33,219 September 7,106 49 89 3,157 707 664 204 1,253 17,265 30,493 October 7,944 36 40 3,003 670 645 232 1,222 17,683 31,474 November 9,748 43 34 3,080 713 668 244 1,252 19,562 35,344 December 9,059 32 12 3,275 731 682 236 1,330 23,169 38,528

January 8,550 33 6 3,290 732 542 241 1,347 25,531 40,273 February 10,452 47 39 2,937 680 505 242 1,215 24,131 40,247 March 10,545 65 58 3,081 737 600 228 1,337 31,134 47,784

April 12,422 80 84 2,798 692 602 209 1,239 31,194 49,320 May 11,772 90 100 2,794 728 630 205 1,318 32,587 50,225 June 10,985 98 125 3,230 764 650 218 1,215 32,151 49,435

July 7,489 88 103 3,362 793 659 238 1,269 31,285 45,285 August 7,474 120 109 3,384 805 635 252 1,275 25,764 39,817 September 6,869 108 78 3,178 754 603 232 1,226 21,378 34,425 October 10,525 99 60 2,954 754 630 247 1,281 19,787 36,337 November 12,439 82 25 3,088 793 636 256 1,271 20,681 39,270 December 10,656 101 20 3,353 813 662 256 1,324 23,732 40,917

January 13,632 82 13 3,314 806 589 206 1,263 23,107 43,013 February 11,052 106 29 3,111 735 561 209 1,193 20,283 37,279 March 14,026 163 68 3,034 801 597 226 1,285 25,909 46,109

April 12,709 223 96 2,704 766 598 219 1,248 26,294 44,858 May 12,541 337 125 2,937 804 633 217 1,304 28,643 47,541 June 11,972 391 136 3,081 790 627 195 1,277 26,659 45,128

July 8,822 392 117 3,352 855 651 216 1,321 26,491 42,216 August 8,469 369 93 3,370 861 621 244 1,304 23,034 38,364 September 8,790 373 85 3,227 808 600 218 1,300 17,604 33,005 October 12,636 365 66 3,113 861 601 254 1,329 16,501 35,726 November 11,649 316 31 3,190 827 604 253 1,347 18,732 36,950 December 14,524 333 16 3,365 890 639 244 1,390 22,984 44,385

Wood and Wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Waste Biomass includes sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.1.B. Net Generation from Renewable Sources: Total (All Sectors), 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Nuclear Hydroelectric Conventional Renewable Sources Excluding Hydroelectric Hydroelectric Pumped Storage Other Total

2002 1,514,670 52,838 6,286 229,639 206 507,380 242,302 3,089 -7,434 480 2,549,457 2003 1,500,281 62,774 7,156 186,967 243 458,829 249,622 3,421 -7,532 519 2,462,281 2004 1,513,641 62,196 11,498 199,662 374 475,682 245,546 3,692 -7,526 467 2,505,231 2005 1,484,855 58,572 11,150 238,204 10 436,296 245,553 4,945 -5,383 643 2,474,846 2006 1,471,421 31,269 9,634 282,088 30 425,341 261,864 6,588 -5,281 700 2,483,656 2007 1,490,985 33,325 7,395 313,785 141 427,555 226,734 8,953 -5,328 586 2,504,131 2008 1,466,395 22,206 5,918 320,190 46 424,256 229,645 11,308 -5,143 545 2,475,367 2009 1,322,092 18,035 7,182 349,166 96 417,275 247,198 14,617 -3,369 483 2,372,776 2010 1,378,028 17,258 8,807 392,616 52 424,843 236,104 17,927 -4,466 462 2,471,632 2011 1,301,107 11,688 9,428 414,843 29 415,298 291,413 21,933 -5,492 604 2,460,851 2012 1,146,480 9,892 5,664 504,958 0 394,823 252,936 28,017 -4,202 603 2,339,172

January 129,279 2,418 736 29,332 6 39,345 20,298 1,338 -427 36 222,362 February 113,856 890 696 25,880 6 34,945 18,752 1,087 -246 29 195,895 March 107,626 1,009 816 25,683 6 33,460 18,546 1,540 -232 37 188,491

April 95,791 923 675 25,721 5 30,946 16,812 1,777 -245 36 172,441 May 108,550 1,443 690 30,549 6 34,506 22,803 1,602 -356 42 199,835 June 124,451 2,132 837 36,530 6 35,835 27,661 1,449 -392 42 228,551

July 134,219 1,986 910 44,597 5 38,536 22,611 1,331 -474 34 243,756 August 132,743 1,785 758 47,474 5 38,021 18,465 1,431 -543 46 240,185 September 110,642 1,207 803 36,692 2 37,188 15,854 1,441 -353 45 203,521 October 97,612 877 645 31,613 1 31,226 15,718 1,542 -361 43 178,917 November 99,803 835 511 27,567 1 32,112 17,612 1,778 -397 34 179,858 December 123,456 1,752 730 30,978 2 38,722 20,970 1,610 -439 39 217,820

January 126,539 1,210 1,082 29,515 1 37,742 23,602 1,713 -551 46 220,900 February 103,607 888 818 25,456 1 34,119 22,187 1,905 -331 49 188,700 March 102,328 982 922 26,612 1 34,201 28,401 1,930 -277 49 195,148

April 93,647 1,178 600 29,154 1 28,964 28,280 2,098 -403 50 183,567 May 104,296 1,062 655 31,372 7 28,502 29,436 1,975 -366 55 196,994 June 119,780 976 831 38,311 6 34,635 29,631 1,795 -491 60 225,535

July 133,078 1,110 983 49,479 1 38,444 29,180 1,428 -612 51 253,142 August 128,915 924 908 49,617 1 37,435 23,866 1,418 -599 55 242,540 September 105,127 819 945 37,391 2 34,639 19,289 1,383 -500 48 199,144 October 94,046 837 618 33,218 1 33,558 17,509 2,041 -517 46 181,359 November 90,103 822 399 30,532 4 34,107 18,732 2,168 -398 45 176,515 December 99,641 879 667 34,186 3 38,952 21,300 2,079 -450 49 197,306

January 96,773 858 843 36,548 0 38,270 20,835 2,620 -301 53 196,498 February 86,462 699 658 35,281 0 33,117 18,363 2,124 -202 53 176,554 March 80,689 784 256 36,916 0 30,601 23,555 2,697 -209 43 175,331

April 75,146 766 293 38,669 0 27,884 24,174 2,374 -250 41 169,095 May 87,924 816 380 45,633 0 31,384 26,049 2,645 -291 53 194,593 June 100,022 934 473 48,423 0 34,052 24,540 2,448 -429 52 210,514

July 121,051 1,133 467 57,832 0 35,999 24,766 1,828 -530 48 242,595 August 115,044 906 477 53,961 0 36,149 21,575 1,851 -445 59 229,579 September 94,983 737 520 44,430 0 33,384 16,308 1,814 -368 62 191,871 October 90,924 787 409 38,288 0 31,289 14,911 2,491 -323 48 178,825 November 96,094 717 454 33,438 0 29,038 16,928 2,474 -355 46 178,834 December 101,368 755 434 35,539 0 33,656 20,933 2,653 -499 45 194,884
Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Other Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, solar thermal, photovoltaic energy, and wind. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.2.A. Net Generation by Energy Source: Electric Utilities, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Wind Solar Photovoltaic Solar Thermal Wood and Wood-Derived Fuels Landfill Gas Biogenic Municipal Solid Waste Other Waste Biomass Geothermal Conventional Hydroelectric Total Renewable Sources

2002 213 N/A N/A 709 N/A N/A N/A 1,402 242,302 N/A 2003 354 2 0 882 394 326 214 1,249 249,622 253,043 2004 405 6 0 1,209 460 198 166 1,248 245,546 249,238 2005 1,046 16 0 1,829 503 250 175 1,126 245,553 250,499 2006 2,351 15 0 1,937 705 228 190 1,162 261,864 268,452 2007 4,361 10 1 2,226 751 240 226 1,139 226,734 235,687 2008 6,899 16 1 1,888 844 211 252 1,197 229,645 240,953 2009 10,348 28 1 1,748 866 184 261 1,182 247,198 261,815 2010 13,089 101 0 2,328 879 154 259 1,118 236,104 254,031 2011 17,140 187 29 2,023 957 165 295 1,137 291,413 313,346 2012 22,926 551 89 1,836 1,022 184 265 1,143 252,936 280,953

January 918 4 0 216 74 11 14 101 20,298 21,636 February 706 5 0 185 73 9 19 90 18,752 19,839 March 1,145 7 0 167 96 13 22 90 18,546 20,086

April 1,406 10 0 166 75 14 20 85 16,812 18,589 May 1,229 11 0 168 74 13 20 88 22,803 24,405 June 1,043 11 0 191 74 14 22 93 27,661 29,110

July 910 10 0 206 71 14 25 96 22,611 23,943 August 1,002 10 0 214 70 14 27 94 18,465 19,896 September 1,036 10 0 198 70 11 22 94 15,854 17,295 October 1,146 9 0 181 69 15 24 98 15,718 17,260 November 1,354 8 0 218 67 13 24 93 17,612 19,391 December 1,194 7 0 217 65 12 18 96 20,970 22,580

January 1,310 6 3 191 75 10 19 98 23,602 25,315 February 1,519 8 5 174 71 10 33 86 22,187 24,092 March 1,508 12 9 185 76 12 29 99 28,401 30,331

April 1,759 14 3 119 73 14 21 94 28,280 30,378 May 1,622 14 3 126 74 16 23 96 29,436 31,411 June 1,391 13 0 187 76 16 26 86 29,631 31,426

July 997 13 0 203 82 15 24 95 29,180 30,608 August 959 19 0 220 85 15 28 92 23,866 25,283 September 965 25 4 180 74 15 27 93 19,289 20,672 October 1,637 22 0 154 91 16 23 99 17,509 19,550 November 1,813 23 3 108 90 13 20 98 18,732 20,900 December 1,659 19 0 176 88 14 23 100 21,300 23,379

January 2,222 15 5 172 76 13 19 99 20,835 23,454 February 1,745 18 3 158 76 12 20 92 18,363 20,487 March 2,306 30 10 136 80 16 23 95 23,555 26,252

April 2,022 37 12 92 85 17 22 87 24,174 26,547 May 2,197 53 10 157 90 18 24 97 26,049 28,694 June 2,019 69 9 132 84 14 27 92 24,540 26,987

July 1,361 66 11 165 93 15 22 96 24,766 26,594 August 1,370 59 8 184 94 17 24 96 21,575 23,426 September 1,375 57 6 156 83 15 28 95 16,308 18,122 October 2,078 51 7 124 92 17 23 99 14,911 17,402 November 2,029 48 4 178 85 16 17 97 16,928 19,402 December 2,203 48 4 182 85 14 16 99 20,933 23,586

Wood and Wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Waste Biomass includes sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.2.B. Net Generation from Renewable Sources: Electric Utilities, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Nuclear Hydroelectric Conventional Renewable Sources Excluding Hydroelectric Hydroelectric Pumped Storage Other Total

2002 395,943 22,241 8,368 378,044 1,763 272,684 18,189 44,466 -1,309 8,612 1,149,001 2003 452,433 35,818 7,949 380,337 2,404 304,904 21,890 46,060 -1,003 8,088 1,258,879 2004 443,547 33,574 7,410 427,510 3,194 312,846 19,518 48,636 -962 7,856 1,303,129 2005 507,199 37,096 9,664 445,625 3,767 345,690 21,486 51,708 -1,174 6,285 1,427,346 2006 498,316 10,396 8,409 452,329 4,223 361,877 24,390 59,345 -1,277 6,412 1,424,421 2007 507,406 13,645 6,942 500,967 3,901 378,869 19,109 65,751 -1,569 6,191 1,501,212 2008 502,442 8,021 6,737 482,182 3,154 381,952 23,451 85,776 -1,145 6,414 1,498,982 2009 419,031 6,306 4,288 491,839 2,962 381,579 24,308 101,860 -1,259 6,146 1,437,061 2010 449,709 5,117 3,497 508,774 2,915 382,126 22,351 120,956 -1,035 6,345 1,500,754 2011 416,783 3,655 3,431 511,447 2,911 374,906 26,117 141,954 -928 7,059 1,487,335 2012 354,076 2,757 1,758 627,833 2,984 374,509 20,923 160,064 -748 7,030 1,551,186

January 42,381 655 302 37,515 269 33,224 1,909 9,142 -138 507 125,766 February 37,605 266 314 33,676 241 30,300 1,669 7,669 -105 463 112,099 March 35,039 192 281 30,809 269 31,174 2,145 10,760 -93 502 111,080

April 29,824 228 283 32,403 268 26,666 2,087 11,509 -91 505 103,681 May 33,119 333 335 36,313 273 32,152 2,100 10,747 -84 533 115,821 June 39,461 459 364 48,503 259 32,466 2,050 10,402 -80 550 134,434

July 43,559 900 403 62,363 262 33,377 1,794 9,305 -83 558 152,439 August 43,105 568 265 65,487 244 33,553 1,554 9,193 -57 553 154,465 September 36,515 401 197 48,806 238 32,183 1,334 9,391 -68 540 129,537 October 33,051 267 248 39,263 169 31,525 1,843 9,914 -77 527 116,729 November 34,012 310 224 34,738 218 30,543 1,813 11,642 -70 545 113,975 December 42,038 540 280 38,897 205 34,962 2,054 11,282 -91 562 130,729

January 42,852 588 349 37,417 242 35,000 1,785 10,446 -108 530 129,100 February 33,475 252 298 33,924 206 30,670 1,782 11,904 -82 503 112,932 March 31,255 229 393 32,750 251 31,461 2,544 12,260 -72 589 111,660

April 29,625 221 258 34,103 243 25,583 2,728 13,669 -63 584 106,952 May 31,525 242 259 36,802 235 28,511 2,950 13,346 -51 590 114,409 June 36,936 347 284 45,115 253 30,635 2,367 12,911 -76 621 129,393

July 42,051 554 358 62,024 261 33,901 1,993 9,969 -96 645 151,659 August 40,884 320 298 61,922 263 33,903 1,800 9,991 -94 614 149,901 September 34,521 246 261 46,908 251 32,210 1,965 9,121 -83 569 125,969 October 31,395 213 225 38,745 239 29,779 2,150 12,071 -84 582 115,317 November 30,220 204 207 37,730 224 30,367 1,801 13,840 -60 593 115,124 December 32,045 238 241 44,007 244 32,885 2,252 12,425 -59 639 124,919

January 31,101 224 206 46,574 263 34,111 1,995 14,684 -47 577 129,688 February 26,312 147 169 48,027 256 30,730 1,678 12,406 -35 546 120,236 March 23,721 127 138 48,085 261 31,128 2,117 15,075 -71 587 121,167

April 20,138 141 87 49,080 254 27,987 1,940 13,914 -15 561 114,087 May 27,005 210 121 53,993 244 30,697 2,379 13,838 -80 599 129,007 June 30,125 314 119 59,262 253 31,088 1,942 13,609 -78 612 137,247

July 38,127 340 146 72,301 266 33,130 1,586 11,293 -89 620 157,719 August 35,897 235 202 69,198 266 33,453 1,305 10,855 -84 588 151,914 September 29,513 186 151 55,837 232 31,126 1,135 11,021 -62 575 129,715 October 29,028 204 156 45,919 225 28,455 1,395 14,180 -55 575 120,080 November 31,554 213 130 39,163 211 27,674 1,590 13,150 -54 580 114,213 December 31,555 415 133 40,394 253 34,928 1,862 16,039 -77 610 126,112
Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Other Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, solar thermal, photovoltaic energy, and wind. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.3.A. Net Generation by Energy Source: Independent Power Producers, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Wind Solar Photovoltaic Solar Thermal Wood and Wood-Derived Fuels Landfill Gas Biogenic Municipal Solid Waste Other Waste Biomass Geothermal Conventional Hydroelectric Total Renewable Sources

2002 10,141 N/A N/A 8,300 N/A N/A N/A 13,089 18,189 N/A 2003 10,834 0 532 8,645 4,435 7,227 1,211 13,175 21,890 67,949 2004 13,739 0 569 8,528 4,377 6,978 884 13,563 19,518 68,154 2005 16,764 0 535 8,741 4,308 7,092 701 13,566 21,486 73,195 2006 24,238 0 493 8,404 4,771 7,259 774 13,406 24,390 83,736 2007 30,089 6 595 8,486 5,177 7,061 839 13,498 19,109 84,860 2008 48,464 60 787 8,750 6,057 6,975 1,040 13,643 23,451 109,226 2009 63,538 129 734 8,990 6,718 6,829 1,095 13,826 24,308 126,168 2010 81,547 316 789 9,118 7,227 6,742 1,116 14,101 22,351 143,306 2011 102,981 734 777 8,709 7,120 6,217 1,237 14,180 26,117 168,071 2012 117,822 2,737 787 9,214 7,852 6,056 1,176 14,419 20,923 180,987

January 5,936 2 4 795 574 538 82 1,211 1,909 11,051 February 4,725 6 22 741 530 484 91 1,069 1,669 9,337 March 7,443 14 55 772 610 564 86 1,217 2,145 12,905

April 8,356 23 78 671 596 562 68 1,155 2,087 13,596 May 7,468 32 110 662 595 583 74 1,223 2,100 12,847 June 7,005 40 124 764 623 582 94 1,171 2,050 12,452

July 5,812 36 114 855 619 582 108 1,178 1,794 11,099 August 5,683 39 107 861 623 574 105 1,203 1,554 10,747 September 6,068 38 89 776 614 557 89 1,159 1,334 10,724 October 6,796 26 40 706 578 550 94 1,124 1,843 11,757 November 8,392 35 34 716 622 576 109 1,159 1,813 13,455 December 7,864 24 12 801 643 589 116 1,233 2,054 13,335

January 7,237 25 3 789 576 459 108 1,249 1,785 12,231 February 8,929 34 34 712 532 433 101 1,129 1,782 13,686 March 9,032 47 49 713 577 516 89 1,238 2,544 14,804

April 10,657 58 81 586 542 515 85 1,145 2,728 16,397 May 10,145 66 97 634 574 524 85 1,222 2,950 16,296 June 9,590 72 125 749 605 549 93 1,129 2,367 15,279

July 6,489 64 103 845 625 557 111 1,174 1,993 11,962 August 6,512 89 109 818 633 531 115 1,183 1,800 11,791 September 5,900 75 74 736 598 504 101 1,132 1,965 11,085 October 8,882 70 60 653 589 528 108 1,182 2,150 14,222 November 10,618 55 22 691 624 536 120 1,173 1,801 15,640 December 8,990 78 20 783 644 565 121 1,224 2,252 14,677

January 11,402 63 8 799 650 498 98 1,165 1,995 16,679 February 9,301 82 26 754 582 471 89 1,101 1,678 14,084 March 11,713 123 58 757 644 496 94 1,190 2,117 17,192

April 10,680 172 84 624 606 492 96 1,161 1,940 15,854 May 10,338 267 116 656 639 522 93 1,207 2,379 16,217 June 9,948 303 127 802 633 526 84 1,185 1,942 15,551

July 7,457 309 106 882 687 537 91 1,225 1,586 12,878 August 7,095 293 85 876 687 504 107 1,208 1,305 12,160 September 7,411 297 79 792 649 491 96 1,205 1,135 12,156 October 10,550 297 59 752 689 490 112 1,231 1,395 15,574 November 9,613 256 27 733 661 499 111 1,250 1,590 14,740 December 12,313 275 12 786 725 531 106 1,291 1,862 17,901

Wood and Wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Waste Biomass includes sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.3.B. Net Generation from Renewable Sources: Independent Power Producers, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Nuclear Hydroelectric Conventional Renewable Sources Excluding Hydroelectric Hydroelectric Pumped Storage Other Total

2002 992 426 6 4,310 0 0 13 1,065 0 603 7,415 2003 1,206 416 8 3,899 0 0 72 1,302 0 594 7,496 2004 1,340 493 7 3,969 0 0 105 1,575 0 781 8,270 2005 1,353 368 7 4,249 0 0 86 1,673 0 756 8,492 2006 1,310 228 7 4,355 0 0 93 1,619 0 758 8,371 2007 1,371 180 9 4,257 0 0 77 1,614 0 764 8,273 2008 1,261 136 6 4,188 0 0 60 1,555 0 720 7,926 2009 1,096 157 5 4,225 0 0 71 1,769 0 842 8,165 2010 1,111 117 7 4,725 3 0 80 1,714 0 834 8,592 2011 1,049 86 3 5,487 3 0 26 2,476 0 950 10,080 2012 883 191 6 6,603 0 0 28 2,545 0 1,046 11,301

January 116 12 1 367 0 0 6 140 0 66 709 February 102 10 1 339 0 0 6 114 0 51 623 March 91 7 1 351 0 0 7 137 0 66 661

April 80 8 1 326 0 0 11 147 0 73 645 May 84 12 0 326 0 0 12 152 0 79 666 June 97 10 0 350 0 0 11 153 0 77 699

July 110 18 0 459 0 0 4 149 0 72 812 August 105 11 1 490 0 0 1 155 0 77 838 September 89 9 1 421 0 0 2 152 0 77 750 October 80 6 1 419 0 0 4 137 0 66 712 November 69 3 1 401 0 0 6 138 0 64 683 December 88 11 1 476 0 0 11 141 0 66 793

January 108 20 1 421 0 0 2 194 0 71 817 February 104 10 1 367 0 0 2 180 0 61 725 March 100 6 1 373 0 0 3 200 0 71 753

April 77 4 0 357 0 0 3 195 0 71 706 May 82 5 0 471 0 0 3 218 0 88 867 June 90 3 0 463 0 0 2 218 0 84 860

July 104 7 0 605 0 0 2 220 0 85 1,023 August 94 7 0 571 0 0 2 225 0 87 985 September 84 7 0 487 0 0 2 208 0 83 870 October 65 6 0 438 0 0 2 204 0 84 799 November 62 6 0 437 0 0 2 208 0 84 800 December 78 5 1 499 0 0 2 207 0 81 874

January 83 14 1 543 0 0 3 197 0 76 916 February 81 15 1 531 0 0 2 194 0 77 900 March 74 12 1 537 0 0 2 204 0 82 911

April 66 17 0 510 0 0 2 207 0 86 888 May 69 12 0 541 0 0 3 215 0 90 930 June 79 21 0 585 0 0 2 204 0 84 975

July 83 18 1 716 0 0 2 219 0 96 1,135 August 81 18 1 620 0 0 2 228 0 96 1,046 September 66 14 1 537 0 0 2 219 0 91 930 October 57 19 1 513 0 0 2 222 0 91 904 November 67 15 1 488 0 0 2 217 0 86 876 December 77 15 1 483 0 0 2 219 0 91 888
Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Other Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, solar thermal, photovoltaic energy, and wind. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.4.A. Net Generation by Energy Source: Commerical Sector, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Wind Solar Photovoltaic Solar Thermal Wood and Wood-Derived Fuels Landfill Gas Biogenic Municipal Solid Waste Other Waste Biomass Geothermal Conventional Hydroelectric Total Renewable Sources

2002 0 N/A N/A 13 N/A N/A N/A 0 13 N/A 2003 0 0 0 13 152 717 420 0 72 1,374 2004 0 0 0 13 172 945 444 0 105 1,680 2005 0 0 0 16 218 953 486 0 86 1,759 2006 0 0 0 21 173 956 470 0 93 1,713 2007 0 0 0 15 203 962 434 0 77 1,691 2008 0 0 0 21 234 911 389 0 60 1,615 2009 0 0 0 20 318 1,045 386 0 71 1,839 2010 16 5 0 21 256 1,031 386 0 80 1,794 2011 51 84 0 26 952 971 393 0 26 2,502 2012 54 148 0 24 848 1,070 402 0 28 2,573

January 1 0 0 2 21 83 33 0 6 146 February 1 0 0 2 18 63 30 0 6 120 March 2 0 0 2 20 83 31 0 7 144

April 2 0 0 2 22 91 31 0 11 158 May 2 0 0 2 20 99 30 0 12 164 June 1 1 0 2 22 95 33 0 11 164

July 1 1 0 2 23 88 35 0 4 153 August 1 0 2 23 94 35 0 1 156 September 1 1 0 2 21 96 32 0 2 153 October 2 0 0 2 22 80 31 0 4 141 November 2 0 0 2 23 78 33 0 6 144 December 1 0 2 22 81 33 0 11 151

January 3 2 0 2 80 73 33 0 2 196 February 4 4 0 3 75 62 32 0 2 182 March 4 6 0 2 83 72 34 0 3 202

April 5 8 0 2 75 73 31 0 3 197 May 5 9 0 2 79 90 33 0 3 220 June 4 11 0 2 81 85 34 0 2 220

July 3 10 0 3 85 87 33 0 2 222 August 3 11 0 2 85 89 36 0 2 227 September 3 8 0 2 80 84 31 0 2 210 October 6 7 0 1 73 86 31 0 2 206 November 6 4 0 2 77 87 32 0 2 209 December 6 4 0 3 79 83 33 0 2 209

January 6 4 0 2 73 77 35 0 3 200 February 5 5 0 2 70 78 34 0 2 196 March 5 9 0 2 70 85 33 0 2 206

April 5 13 0 2 69 88 31 0 2 210 May 4 16 0 2 68 92 33 0 3 218 June 4 18 0 2 66 85 29 0 2 206

July 3 16 0 2 68 98 31 0 2 221 August 3 15 0 2 74 98 36 0 2 230 September 3 18 0 2 70 93 33 0 2 221 October 5 15 0 2 73 93 34 0 2 225 November 5 11 0 2 75 88 37 0 2 219 December 5 9 0 2 72 93 37 0 2 222

Wood and Wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Waste Biomass includes sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.4.B. Net Generation from Renewable Sources: Commerical Sector, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Nuclear Hydroelectric Conventional Renewable Sources Excluding Hydroelectric Hydroelectric Pumped Storage Other Total

2002 21,525 3,196 1,207 79,013 9,493 0 3,825 30,489 0 3,832 152,580 2003 19,817 3,726 1,559 78,705 12,953 0 4,222 28,704 0 4,843 154,530 2004 19,773 4,128 1,839 78,959 11,684 0 3,248 29,164 0 5,129 153,925 2005 19,466 3,804 1,564 72,882 9,687 0 3,195 29,003 0 5,137 144,739 2006 19,464 2,567 1,656 77,669 9,923 0 2,899 28,972 0 5,103 148,254 2007 16,694 2,355 1,889 77,580 9,411 0 1,590 28,919 0 4,690 143,128 2008 15,703 1,555 1,664 76,421 8,507 0 1,676 27,462 0 4,125 137,113 2009 13,686 1,474 1,489 75,748 7,574 0 1,868 26,033 0 4,457 132,329 2010 18,441 844 1,414 81,583 8,343 0 1,668 26,576 0 5,214 144,082 2011 14,490 657 1,234 81,911 8,624 0 1,799 27,619 0 5,541 141,875 2012 12,603 563 2,359 86,500 8,913 0 2,353 27,707 0 5,108 146,107

January 1,544 102 123 6,959 634 0 169 2,185 0 404 12,120 February 1,481 86 111 6,303 578 0 162 2,031 0 366 11,118 March 1,649 63 100 6,588 735 0 188 2,217 0 397 11,936

April 1,258 61 108 6,194 669 0 187 2,174 0 382 11,034 May 1,519 63 118 6,477 738 0 164 2,130 0 406 11,614 June 1,482 55 132 6,885 700 0 132 2,205 0 485 12,075

July 1,713 67 128 7,205 696 0 107 2,321 0 482 12,718 August 1,792 55 133 7,701 812 0 99 2,321 0 482 13,395 September 1,499 58 107 7,085 713 0 76 2,244 0 455 12,238 October 1,527 71 113 6,443 637 0 117 2,199 0 455 11,562 November 1,301 72 124 6,520 688 0 130 2,224 0 436 11,493 December 1,677 92 118 7,223 744 0 134 2,326 0 464 12,777

January 1,304 84 123 6,901 687 0 143 2,389 0 423 12,054 February 1,125 68 100 6,177 600 0 160 2,126 0 414 10,770 March 1,161 59 101 6,212 693 0 187 2,260 0 474 11,149

April 1,139 56 107 6,416 674 0 184 2,164 0 436 11,175 May 1,199 47 109 6,597 633 0 198 2,099 0 477 11,359 June 1,249 48 104 6,802 753 0 150 2,360 0 471 11,938

July 1,353 43 98 7,517 836 0 109 2,384 0 529 12,868 August 1,389 45 94 7,745 823 0 96 2,420 0 474 13,085 September 1,209 46 99 6,953 752 0 122 2,336 0 432 11,948 October 1,120 58 104 6,419 700 0 126 2,233 0 463 11,224 November 1,077 49 95 6,742 715 0 146 2,374 0 465 11,663 December 1,165 55 100 7,429 758 0 178 2,474 0 483 12,642

January 1,135 84 247 7,096 754 0 275 2,405 0 431 12,425 February 1,017 46 167 6,771 788 0 240 2,272 0 396 11,699 March 1,041 49 176 6,713 815 0 234 2,225 0 428 11,681

April 935 41 158 6,571 803 0 178 2,068 0 403 11,158 May 984 41 150 7,186 758 0 212 2,200 0 458 11,988 June 1,035 37 170 7,327 719 0 175 2,210 0 418 12,091

July 1,189 39 195 8,013 776 0 137 2,385 0 454 13,190 August 1,159 43 235 7,956 784 0 152 2,396 0 434 13,160 September 1,026 40 210 7,209 672 0 159 2,347 0 406 12,069 October 990 50 179 7,006 670 0 192 2,332 0 422 11,841 November 1,012 41 239 7,080 664 0 213 2,376 0 428 12,052 December 1,079 51 233 7,573 709 0 186 2,490 0 430 12,751
Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Other Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, solar thermal, photovoltaic energy, and wind. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.5.A. Net Generation by Energy Source: Industrial Sector, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Period Wind Solar Photovoltaic Solar Thermal Wood and Wood-Derived Fuels Landfill Gas Biogenic Municipal Solid Waste Other Waste Biomass Geothermal Conventional Hydroelectric Total Renewable Sources

2002 0 N/A N/A 29,643 N/A N/A N/A 0 3,825 N/A 2003 0 0 0 27,988 96 36 583 0 4,222 32,926 2004 0 0 0 28,367 120 30 647 0 3,248 32,413 2005 0 0 0 28,271 113 34 585 0 3,195 32,199 2006 0 0 0 28,400 29 35 509 0 2,899 31,872 2007 0 0 0 28,287 27 40 565 0 1,590 30,509 2008 0 0 0 26,641 21 0 800 0 1,676 29,138 2009 0 0 0 25,292 22 0 718 0 1,868 27,901 2010 0 2 0 25,706 15 0 853 0 1,668 28,244 2011 5 7 0 26,691 15 2 900 0 1,799 29,418 2012 19 14 0 26,725 81 10 857 0 2,353 30,060

January 0 0 0 2,114 1 0 71 0 169 2,355 February 0 0 0 1,967 1 0 63 0 162 2,193 March 0 0 0 2,149 2 0 66 0 188 2,404

April 0 0 0 2,094 2 0 79 0 187 2,362 May 0 0 0 2,061 2 0 67 0 164 2,294 June 0 0 0 2,137 1 0 66 0 132 2,337

July 0 0 0 2,246 1 0 74 0 107 2,429 August 0 0 0 2,243 1 0 77 0 99 2,420 September 0 0 0 2,182 1 0 60 0 76 2,320 October 0 0 0 2,114 1 0 83 0 117 2,316 November 0 0 0 2,145 1 0 78 0 130 2,353 December 0 0 0 2,255 1 0 70 0 134 2,460

January 0 0 0 2,307 1 0 81 0 143 2,532 February 0 0 0 2,048 1 0 76 0 160 2,286 March 0 0 0 2,181 1 0 77 0 187 2,447

April 0 1 0 2,090 1 0 71 0 184 2,348 May 0 1 0 2,033 1 0 64 0 198 2,297 June 0 1 0 2,292 1 0 65 0 150 2,510

July 0 1 0 2,312 1 0 70 0 109 2,493 August 0 1 0 2,343 1 1 74 0 96 2,516 September 0 1 0 2,260 1 0 73 0 122 2,458 October 1 1 0 2,146 1 0 85 0 126 2,359 November 1 0 0 2,286 1 0 84 0 146 2,520 December 1 0 0 2,392 1 0 79 0 178 2,651

January 2 1 0 2,340 7 1 55 0 275 2,680 February 2 1 0 2,197 6 0 66 0 240 2,513 March 2 1 0 2,140 7 0 76 0 234 2,459

April 2 1 0 1,986 7 1 71 0 178 2,247 May 1 1 0 2,122 7 1 67 0 212 2,412 June 1 1 0 2,144 7 1 55 0 175 2,384

July 1 2 0 2,303 7 1 72 0 137 2,522 August 1 2 0 2,308 7 1 77 0 152 2,548 September 1 2 0 2,277 6 1 61 0 159 2,506 October 2 1 0 2,235 7 1 86 0 192 2,525 November 1 1 0 2,277 7 1 88 0 213 2,588 December 2 NM 0 2,394 8 1 84 0 186 2,676

Wood and Wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Waste Biomass includes sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.5.B. Net Generation from Renewable Sources: Industrial Sector, 2002 - 2012 (Thousand Megawatthours)

Annual Totals

2010

2011

2012Census Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 120,887 123,338 -2.0% 3,278 4,408 111,191 112,613 1,178 949 5,240 5,368 Connecticut 36,118 33,745 7.0% 37 93 35,347 33,208 397 211 337 233 Maine 14,429 15,974 -9.7% 0 1 10,186 10,890 208 176 4,035 4,907 Massachusetts 36,198 38,055 -4.9% 591 610 34,321 36,783 469 490 817 172 New Hampshire 19,264 20,066 -4.0% 2,017 2,994 17,170 17,020 49 20 29 31 Rhode Island 8,309 8,722 -4.7% 11 10 8,246 8,664 52 48 0 0 Vermont 6,570 6,776 -3.0% 623 700 5,920 6,049 3 4 23 24 Middle Atlantic 424,451 429,489 -1.2% 35,091 37,522 383,441 386,021 1,957 1,518 3,962 4,428 New Jersey 65,263 64,694 0.9% -88 -173 64,043 63,548 534 509 774 811 New York 135,768 137,480 -1.2% 34,142 35,936 99,621 99,807 1,061 732 945 1,005 Pennsylvania 223,420 227,315 -1.7% 1,038 1,760 219,777 222,666 362 277 2,243 2,612 East North Central 613,916 629,676 -2.5% 308,307 334,633 292,989 283,163 2,046 1,747 10,573 10,133 Illinois 197,565 199,500 -1.0% 12,424 12,242 182,021 183,947 492 447 2,628 2,863 Indiana 114,696 122,131 -6.1% 99,681 104,840 11,522 14,049 232 224 3,261 3,019 Michigan 108,166 109,170 -0.9% 80,483 87,609 25,352 19,532 968 789 1,363 1,240 Ohio 129,746 135,586 -4.3% 75,184 85,007 52,962 49,445 283 172 1,317 962 Wisconsin 63,743 63,289 0.7% 40,535 44,934 21,132 16,191 72 115 2,004 2,050 West North Central 327,475 332,902 -1.6% 288,973 298,430 33,973 29,881 554 556 3,975 4,034 Iowa 56,675 56,372 0.5% 43,386 43,305 11,018 10,896 204 227 2,067 1,944 Kansas 44,425 45,360 -2.1% 39,949 42,583 4,411 2,776 0 0 65 1 Minnesota 52,194 53,120 -1.7% 42,338 44,311 8,358 7,072 173 167 1,324 1,570 Missouri 91,804 94,876 -3.2% 88,747 92,621 2,846 2,039 160 146 52 71 Nebraska 34,217 36,095 -5.2% 32,783 34,978 1,072 822 18 17 345 278 North Dakota 36,125 35,080 3.0% 31,983 30,795 4,019 4,116 0 0 123 169 South Dakota 12,034 11,999 0.3% 9,786 9,839 2,248 2,160 0 0 0 0 South Atlantic 747,508 762,286 -1.9% 603,305 625,341 124,669 117,707 701 782 18,833 18,456 Delaware 8,634 6,590 31.0% 12 20 7,846 6,169 4 5 771 397 District of Columbia 72 201 -64.3% 0 71 9 130 62 0 0 0 Florida 221,096 221,895 -0.4% 198,199 200,023 17,418 16,115 65 67 5,414 5,689 Georgia 122,306 124,749 -2.0% 100,995 106,662 16,512 13,327 31 25 4,769 4,736 Maryland 37,810 41,818 -9.6% 9 8 37,021 40,960 235 236 545 614 North Carolina 116,682 118,390 -1.4% 107,716 110,370 6,542 5,832 50 62 2,374 2,126 South Carolina 96,756 102,973 -6.0% 92,822 99,328 1,970 1,592 0 0 1,964 2,053 Virginia 70,739 66,671 6.1% 56,188 53,329 12,309 11,150 253 387 1,989 1,805 West Virginia 73,413 79,000 -7.1% 47,363 55,530 25,043 22,434 0 0 1,007 1,036 East South Central 375,137 387,365 -3.2% 313,555 336,824 51,152 41,317 186 150 10,244 9,074 Alabama 152,879 156,339 -2.2% 108,425 118,835 40,206 33,198 0 0 4,247 4,306 Kentucky 89,950 98,351 -8.5% 89,156 97,617 326 154 0 0 468 579 Mississippi 54,584 51,571 5.8% 41,077 41,831 10,505 7,884 22 24 2,980 1,831 Tennessee 77,724 81,104 -4.2% 74,897 78,540 114 81 164 126 2,548 2,356 West South Central 676,122 676,881 -0.1% 248,120 257,463 355,233 349,653 768 572 72,002 69,192 Arkansas 65,006 61,308 6.0% 44,190 44,715 18,867 14,657 6 6 1,942 1,930 Louisiana 103,408 105,491 -2.0% 52,048 54,924 23,325 22,195 45 47 27,990 28,325 Oklahoma 77,897 74,606 4.4% 56,746 58,374 20,286 15,411 10 23 855 798 Texas 429,813 435,477 -1.3% 95,135 99,451 292,756 297,390 707 497 41,215 38,138 Mountain 367,566 364,847 0.7% 289,964 295,901 73,862 65,460 357 262 3,383 3,224 Arizona 110,905 108,125 2.6% 92,800 94,062 17,791 13,699 121 68 193 296 Colorado 52,557 51,433 2.2% 41,539 44,123 10,920 7,224 25 22 72 64 Idaho 15,499 16,569 -6.5% 10,633 12,616 4,274 3,330 0 0 592 623 Montana 27,805 30,129 -7.7% 8,486 9,548 19,310 20,572 0 0 9 9 Nevada 35,173 31,936 10.1% 24,186 21,673 10,631 10,002 92 92 264 169 New Mexico 36,636 38,181 -4.0% 30,705 32,292 5,850 5,767 81 80 0 43 Utah 39,403 40,836 -3.5% 36,386 38,393 1,957 1,638 38 0 1,022 806 Wyoming 49,589 47,638 4.1% 45,228 43,195 3,128 3,228 0 0 1,232 1,215 Pacific Contiguous 377,287 375,763 0.4% 236,204 257,680 120,728 97,673 2,974 2,950 17,380 17,460 California 199,519 200,805 -0.6% 82,486 105,360 98,738 76,912 2,894 2,880 15,400 15,653 Oregon 60,933 59,695 2.1% 47,144 48,985 13,102 10,188 73 63 613 459 Washington 116,835 115,263 1.4% 106,574 103,334 8,888 10,573 7 7 1,366 1,349 Pacific Noncontiguous 17,416 17,594 -1.0% 12,375 12,650 3,949 3,846 579 593 513 506 Alaska 6,946 6,871 1.1% 6,362 6,274 220 209 278 275 87 113 Hawaii 10,469 10,723 -2.4% 6,013 6,376 3,729 3,636 301 318 426 393 U.S. Total 4,047,7654,100,141 -1.3%2,339,1722,460,8511,551,1861,487,335 11,301 10,080 146,107 141,875

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.6. Net Generation by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 4,103 6,848 -40.1% 1,268 2,208 2,793 4,592 0 0 42 47 Connecticut 653 526 24.2% 0 0 653 526 0 0 0 0 Maine 45 55 -18.0% 0 0 30 38 0 0 15 18 Massachusetts 2,137 4,059 -47.4% 0 0 2,110 4,029 0 0 27 30 New Hampshire 1,268 2,208 -42.6% 1,268 2,208 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 93,597 114,184 -18.0% 36 25 92,867 112,953 11 4 683 1,202 New Jersey 1,897 4,155 -54.3% 0 0 1,897 4,155 0 0 0 0 New York 4,551 9,426 -51.7% 36 25 4,200 9,037 0 1 315 363 Pennsylvania 87,148 100,603 -13.4% 0 0 86,769 99,761 11 3 368 839 East North Central 344,771 398,389 -13.5% 250,318 285,135 91,071 109,458 308 401 3,075 3,395 Illinois 80,827 90,013 -10.2% 10,887 11,093 68,154 77,020 52 46 1,734 1,854 Indiana 92,461 104,153 -11.2% 86,532 95,404 5,747 8,570 133 132 49 46 Michigan 53,136 58,948 -9.9% 52,471 58,183 343 318 118 202 204 246 Ohio 85,589 105,337 -18.7% 68,519 81,470 16,827 23,551 2 1 240 315 Wisconsin 32,758 39,938 -18.0% 31,909 38,984 0 0 2 20 848 934 West North Central 214,964 232,119 -7.4% 211,689 228,675 0 0 228 275 3,048 3,170 Iowa 35,331 38,229 -7.6% 33,179 36,122 0 0 159 183 1,993 1,925 Kansas 27,983 31,656 -11.6% 27,983 31,656 0 0 0 0 0 0 Minnesota 22,723 28,259 -19.6% 22,107 27,429 0 0 0 5 616 824 Missouri 72,775 78,316 -7.1% 72,661 78,164 0 0 68 87 46 65 Nebraska 25,019 25,965 -3.6% 24,686 25,708 0 0 0 0 334 257 North Dakota 28,214 27,109 4.1% 28,155 27,011 0 0 0 0 60 98 South Dakota 2,919 2,586 12.9% 2,919 2,586 0 0 0 0 0 0 South Atlantic 266,385 324,436 -17.9% 219,174 272,063 44,770 49,415 48 77 2,393 2,882 Delaware 1,423 1,455 -2.2% 0 0 1,423 1,455 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 44,286 51,991 -14.8% 42,603 49,487 1,451 2,186 0 0 233 317 Georgia 40,715 60,159 -32.3% 40,197 59,452 0 0 0 0 518 707 Maryland 16,185 21,059 -23.1% 0 0 16,005 20,860 10 0 169 199 North Carolina 50,932 59,758 -14.8% 48,888 57,250 1,745 2,156 29 51 270 301 South Carolina 28,396 34,169 -16.9% 28,208 33,772 26 135 0 0 161 262 Virginia 14,181 19,881 -28.7% 12,573 17,243 970 1,959 9 26 628 653 West Virginia 70,267 75,964 -7.5% 46,704 54,859 23,150 20,664 0 0 413 441 East South Central 171,000 198,964 -14.1% 166,844 194,873 2,789 2,533 20 23 1,347 1,535 Alabama 45,607 56,807 -19.7% 45,378 56,539 32 58 0 0 197 211 Kentucky 82,762 91,656 -9.7% 82,762 91,656 0 0 0 0 0 0 Mississippi 7,212 9,723 -25.8% 4,455 7,248 2,757 2,476 0 0 0 0 Tennessee 35,419 40,777 -13.1% 34,249 39,430 0 0 20 23 1,150 1,324 West South Central 217,243 246,421 -11.8% 119,496 133,827 97,271 112,074 0 0 476 520 Arkansas 28,431 29,418 -3.4% 23,979 25,158 4,353 4,159 0 0 99 101 Louisiana 21,422 24,628 -13.0% 11,163 11,860 10,258 12,749 0 0 0 19 Oklahoma 29,302 34,479 -15.0% 27,142 32,204 1,783 1,882 0 0 377 393 Texas 138,088 157,897 -12.5% 57,211 64,604 80,877 93,285 0 0 0 7 Mountain 191,985 199,443 -3.7% 174,807 180,790 16,083 17,363 0 0 1,095 1,290 Arizona 40,116 43,702 -8.2% 39,930 43,412 0 0 0 0 185 291 Colorado 34,521 33,955 1.7% 34,371 33,792 142 163 0 0 8 0 Idaho 77 83 -8.0% 0 0 0 0 0 0 77 83 Montana 13,987 15,056 -7.1% 253 300 13,726 14,747 0 0 9 9 Nevada 4,079 5,407 -24.6% 2,964 4,093 1,115 1,315 0 0 0 0 New Mexico 24,994 27,141 -7.9% 24,994 27,141 0 0 0 0 0 0 Utah 30,799 33,138 -7.1% 29,976 32,277 418 419 0 0 405 441 Wyoming 43,412 40,961 6.0% 42,317 39,775 684 719 0 0 411 467 Pacific Contiguous 7,772 10,544 -26.3% 2,634 3,334 4,733 6,808 0 0 405 403 California 1,375 1,982 -30.6% 0 0 1,005 1,608 0 0 371 374 Oregon 2,634 3,334 -21.0% 2,634 3,334 0 0 0 0 0 0 Washington 3,763 5,229 -28.0% 0 0 3,728 5,200 0 0 35 29 Pacific Noncontiguous 2,222 2,080 6.8% 215 178 1,699 1,586 268 269 40 47 Alaska 685 656 4.4% 215 178 201 209 268 269 0 0 Hawaii 1,537 1,424 8.0% 0 0 1,498 1,377 0 0 40 47 U.S. Total 1,514,0431,733,430 -12.7%1,146,4801,301,107 354,076 416,783 883 1,049 12,603 14,490

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.7. Net Generation from Coal by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 413 639 -35.4% 52 120 267 374 49 55 45 90 Connecticut 112 166 -32.6% 4 5 104 155 0 0 4 5 Maine 84 178 -52.8% 0 1 65 89 2 3 16 85 Massachusetts 174 197 -11.2% 15 40 98 128 37 28 25 NM New Hampshire 22 78 -72.1% 20 57 0 1 2 20 0 0 Rhode Island 18 14 31.0% 11 10 0 1 7 2 0 0 Vermont 3 8 -58.1% 2 6 0 0 1 2 0 0 Middle Atlantic 859 1,452 -40.9% 324 479 438 860 24 13 73 100 New Jersey 30 107 -71.7% 4 4 24 101 1 1 2 1 New York 580 926 -37.4% 319 475 169 345 22 11 70 96 Pennsylvania 248 419 -40.7% 0 0 245 414 2 2 2 3 East North Central 621 784 -20.8% 516 650 90 110 3 5 13 19 Illinois 71 84 -15.3% 24 28 47 56 0 0 0 0 Indiana 114 172 -33.3% 108 157 0 0 0 2 6 13 Michigan 138 179 -22.8% 134 174 0 0 2 3 3 2 Ohio 258 313 -17.5% 215 264 41 48 0 0 2 2 Wisconsin 39 36 9.0% 35 28 2 6 0 0 1 1 West North Central 292 311 -6.0% 282 301 7 4 1 2 3 4 Iowa 89 69 29.4% 87 68 2 1 0 0 0 0 Kansas 35 38 -8.1% 35 38 0 0 0 0 0 0 Minnesota 30 38 -21.9% 23 33 4 2 1 2 1 1 Missouri 78 80 -2.6% 78 79 0 0 0 0 0 1 Nebraska 23 37 -39.3% 23 37 0 0 0 0 0 0 North Dakota 33 42 -21.3% 32 40 0 0 0 0 1 2 South Dakota 6 8 -24.2% 5 7 1 1 0 0 0 0 South Atlantic 1,756 2,936 -40.2% 1,340 2,266 257 485 19 3 141 182 Delaware 22 38 -42.7% 1 2 21 36 0 0 0 0 District of Columbia 9 130 -92.8% 0 0 9 130 0 0 0 0 Florida 720 1,383 -47.9% 670 1,326 9 12 0 0 41 44 Georgia 73 137 -46.3% 27 71 2 4 1 2 43 59 Maryland 137 229 -40.0% 6 7 108 218 16 0 8 3 North Carolina 178 218 -18.1% 160 186 6 4 0 0 12 27 South Carolina 108 112 -2.8% 99 101 2 0 0 0 8 11 Virginia 364 503 -27.6% 234 394 100 69 1 1 29 37 West Virginia 143 188 -23.9% 143 178 1 10 0 0 0 0 East South Central 378 491 -23.0% 339 461 1 5 0 0 38 25 Alabama 110 120 -9.0% 74 96 1 5 0 0 34 19 Kentucky 107 139 -22.9% 107 139 0 0 0 0 0 0 Mississippi 17 36 -53.0% 13 33 0 0 0 0 4 3 Tennessee 144 195 -26.0% 144 193 0 0 0 0 0 2 West South Central 173 257 -32.8% 66 133 94 110 1 2 12 13 Arkansas 33 56 -41.7% 18 32 13 21 0 0 1 2 Louisiana 38 49 -22.7% 10 23 19 19 0 0 9 8 Oklahoma 11 16 -29.6% 11 15 0 0 0 1 0 0 Texas 91 137 -33.1% 27 63 62 70 1 1 2 3 Mountain 222 255 -12.6% 197 230 20 22 0 0 6 2 Arizona 42 53 -21.3% 41 52 0 0 0 0 1 2 Colorado 11 22 -50.3% 11 22 0 0 0 0 0 0 Idaho 0 0 -26.9% 0 0 0 0 0 0 0 0 Montana 13 18 -27.5% 0 2 13 16 0 0 0 0 Nevada 19 14 32.8% 13 10 6 4 0 0 0 0 New Mexico 46 38 22.1% 46 35 1 2 0 0 0 0 Utah 40 54 -26.3% 39 54 1 0 0 0 0 0 Wyoming 52 55 -6.5% 48 55 0 0 0 0 4 0 Pacific Contiguous 167 92 81.7% 45 49 21 17 86 1 14 24 California 134 47 187.5% 34 37 13 7 86 1 2 3 Oregon 6 8 -25.5% 6 7 0 0 0 0 0 1 Washington 27 37 -28.1% 5 6 9 11 0 0 13 20 Pacific Noncontiguous 8,521 8,869 -3.9% 6,732 6,999 1,561 1,667 8 4 219 199 Alaska 1,038 945 9.8% 986 892 0 0 7 3 45 50 Hawaii 7,483 7,924 -5.6% 5,746 6,107 1,561 1,667 1 1 174 149 U.S. Total 13,403 16,086 -16.7% 9,892 11,688 2,757 3,655 191 86 563 657

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.8. Net Generation from Petroleum Liquids by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 0 0

-- 0 0 0 0 0 0 0 0 Connecticut 0 0

-- 0 0 0 0 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts 0 0

-- 0 0 0 0 0 0 0 0 New Hampshire 0 0

-- 0 0 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 76 344 -78.0% 0 0 0 263 0 0 76 81 New Jersey 40 58 -30.6% 0 0 0 0 0 0 40 58 New York 0 263 -100.0% 0 0 0 263 0 0 0 0 Pennsylvania 35 23 53.8% 0 0 0 0 0 0 35 23 East North Central 2,320 2,946 -21.3% 887 1,490 1,093 1,141 0 0 340 314 Illinois 0 0

-- 0 0 0 0 0 0 0 0 Indiana 831 1,161 -28.4% 831 1,161 0 0 0 0 0 0 Michigan 187 163 14.2% 0 0 73 67 0 0 114 97 Ohio 1,023 1,075 -4.9% 0 0 1,020 1,075 0 0 3 0 Wisconsin 279 547 -49.0% 55 329 0 0 0 0 223 217 West North Central 17 91 -80.9% 12 88 0 0 6 3 0 0 Iowa 18 72 -75.7% 12 69 0 0 6 3 0 0 Kansas 0 19 -100.7% 0 19 0 0 0 0 0 0 Minnesota 0 0

-- 0 0 0 0 0 0 0 0 Missouri 0 0

-- 0 0 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 950 2,313 -58.9% 646 1,898 0 0 0 0 305 415 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 646 1,898 -66.0% 646 1,898 0 0 0 0 0 0 Georgia 305 415 -26.5% 0 0 0 0 0 0 305 415 Maryland 0 0

-- 0 0 0 0 0 0 0 0 North Carolina 0 0

-- 0 0 0 0 0 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 0 0

-- 0 0 0 0 0 0 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central 1,429 1,596 -10.4% 1,429 1,596 0 0 0 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 1,429 1,596 -10.4% 1,429 1,596 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 0 0

-- 0 0 0 0 0 0 0 0 West South Central 4,385 5,498 -20.3% 2,691 4,355 55 719 0 0 1,639 424 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 2,992 4,658 -35.8% 2,691 4,355 0 0 0 0 301 303 Oklahoma 0 0

-- 0 0 0 0 0 0 0 0 Texas 1,393 840 65.8% 0 0 55 719 0 0 1,337 121 Mountain 454 443 2.5% 0 0 454 443 0 0 0 0 Arizona 0 0

-- 0 0 0 0 0 0 0 0 Colorado 0 0

-- 0 0 0 0 0 0 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 454 443 2.5% 0 0 454 443 0 0 0 0 Nevada 0 0

-- 0 0 0 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 0 0

-- 0 0 0 0 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 156 864 -82.0% 0 0 156 864 0 0 0 0 California 156 864 -82.0% 0 0 156 864 0 0 0 0 Oregon 0 0

-- 0 0 0 0 0 0 0 0 Washington 0 0

-- 0 0 0 0 0 0 0 0 Pacific Noncontiguous 0 0

-- 0 0 0 0 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 9,787 14,096 -30.6% 5,664 9,428 1,758 3,431 6 3 2,359 1,234

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.9. Net Generation from Petroleum Coke by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 62,490 63,236 -1.2% 345 357 58,757 59,763 901 700 2,488 2,416 Connecticut 16,537 15,188 8.9% 6 NM 15,801 14,715 397 211 333 227 Maine 6,044 6,877 -12.1% 0 0 4,057 4,850 26 0 1,960 2,026 Massachusetts 24,672 25,940 -4.9% 278 240 23,812 25,120 416 443 166 136 New Hampshire 7,050 6,658 5.9% 58 80 6,947 6,552 16 0 29 26 Rhode Island 8,185 8,571 -4.5% 0 0 8,140 8,525 45 46 0 0 Vermont 3 3 -22.5% 3 3 0 0 0 0 0 0 Middle Atlantic 140,809 117,798 19.5% 13,508 13,073 124,893 102,605 909 671 1,500 1,448 New Jersey 28,285 25,201 12.2% 33 0 27,578 24,587 192 121 481 493 New York 59,462 50,805 17.0% 13,472 13,068 45,132 36,993 605 499 253 246 Pennsylvania 53,062 41,792 27.0% 3 5 52,182 41,026 112 52 765 709 East North Central 81,616 47,583 71.5% 29,266 16,805 49,915 28,608 1,292 981 1,143 1,188 Illinois 11,189 5,956 87.9% 1,450 1,063 8,993 4,094 437 401 309 398 Indiana 14,471 10,064 43.8% 11,432 7,338 2,565 2,195 56 49 417 482 Michigan 21,748 12,982 67.5% 4,401 2,688 16,697 9,866 468 279 183 149 Ohio 22,665 12,338 83.7% 6,015 2,873 16,270 9,230 280 171 100 63 Wisconsin 11,542 6,243 84.9% 5,968 2,842 5,390 3,223 51 81 134 97 West North Central 19,062 12,000 58.8% 15,878 10,228 2,737 1,485 208 175 239 111 Iowa 1,941 991 95.8% 1,868 980 0 0 11 7 62 4 Kansas 2,860 2,535 12.8% 2,795 2,534 0 0 0 0 65 1 Minnesota 7,088 3,351 111.5% 5,746 2,533 1,157 648 105 107 79 64 Missouri 6,167 4,548 35.6% 4,495 3,651 1,580 838 91 58 1 1 Nebraska 770 426 80.8% 758 402 0 0 1 3 11 21 North Dakota 22 20 9.0% 0 0 0 0 0 0 22 20 South Dakota 214 129 65.6% 214 129 0 0 0 0 0 0 South Atlantic 262,975 212,696 23.6% 204,630 168,055 54,865 42,097 269 210 3,212 2,333 Delaware 6,815 4,731 44.0% 9 18 6,277 4,525 0 0 528 188 District of Columbia 62 71 -12.4% 0 71 0 0 62 0 0 0 Florida 149,700 136,364 9.8% 136,017 124,926 12,279 10,060 28 29 1,376 1,349 Georgia 42,539 26,544 60.3% 25,455 12,886 16,285 13,151 0 0 799 507 Maryland 4,945 2,311 114.0% 0 0 4,658 2,022 172 181 114 107 North Carolina 19,302 11,155 73.0% 15,966 8,539 3,258 2,556 6 1 72 60 South Carolina 14,332 12,936 10.8% 12,441 11,522 1,801 1,392 0 0 91 22 Virginia 25,038 18,332 36.6% 14,709 10,062 10,112 8,176 0 0 217 94 West Virginia 243 251 -3.4% 33 31 194 215 0 0 15 6 East South Central 105,279 82,452 27.7% 54,302 42,418 48,046 38,458 163 127 2,768 1,448 Alabama 55,705 47,681 16.8% 14,696 13,959 39,983 32,905 0 0 1,026 818 Kentucky 2,949 1,546 90.8% 2,401 1,163 317 144 0 0 231 238 Mississippi 38,550 29,966 28.6% 29,313 24,213 7,746 5,409 22 24 1,470 320 Tennessee 8,075 3,259 147.8% 7,892 3,083 0 0 142 103 41 73 West South Central 328,607 300,606 9.3% 89,027 82,714 177,322 157,723 726 528 61,532 59,641 Arkansas 17,117 12,947 32.2% 2,502 2,376 14,392 10,362 1 0 222 208 Louisiana 58,564 54,322 7.8% 22,525 22,071 12,042 8,058 45 47 23,952 24,147 Oklahoma 39,024 32,837 18.8% 26,971 24,140 11,939 8,585 10 22 105 90 Texas 213,901 200,500 6.7% 37,029 34,127 138,948 130,718 671 458 37,253 35,197 Mountain 84,720 71,090 19.2% 50,390 43,981 32,753 26,045 293 202 1,284 862 Arizona 30,295 23,253 30.3% 13,911 9,960 16,265 13,227 113 61 7 4 Colorado 10,524 10,186 3.3% 5,898 8,564 4,607 1,606 4 4 16 12 Idaho 1,898 1,111 70.9% 558 146 1,291 923 0 0 49 42 Montana 464 418 11.0% 439 406 25 12 0 0 0 0 Nevada 25,647 21,841 17.4% 18,798 15,389 6,527 6,225 60 60 262 168 New Mexico 8,799 8,566 2.7% 5,394 4,921 3,327 3,526 78 76 0 43 Utah 6,580 5,256 25.2% 5,363 4,566 695 518 38 0 484 172 Wyoming 513 459 11.8% 30 30 16 8 0 0 467 422 Pacific Contiguous 136,731 102,321 33.6% 44,048 33,363 78,546 54,662 1,839 1,890 12,298 12,406 California 119,668 88,974 34.5% 35,717 26,905 70,066 47,960 1,782 1,844 12,104 12,264 Oregon 11,625 8,498 36.8% 4,025 2,839 7,416 5,534 51 39 133 86 Washington 5,438 4,850 12.1% 4,307 3,620 1,064 1,168 7 6 61 56 Pacific Noncontiguous 3,606 3,906 -7.7% 3,566 3,846 0 0 3 3 37 57 Alaska 3,606 3,906 -7.7% 3,566 3,846 0 0 3 3 37 57 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 1,225,8941,013,689 20.9% 504,958 414,843 627,833 511,447 6,603 5,487 86,500 81,911

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.10. Net Generation from Natural Gas by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 0 0

-- 0 0 0 0 0 0 0 0 Connecticut 0 0

-- 0 0 0 0 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts 0 0

-- 0 0 0 0 0 0 0 0 New Hampshire 0 0

-- 0 0 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 740 755 -2.0% 0 0 0 41 0 3 740 711 New Jersey 142 139 2.2% 0 0 0 0 0 3 142 136 New York 0 0

-- 0 0 0 0 0 0 0 0 Pennsylvania 598 616 -3.0% 0 0 0 41 0 0 598 575 East North Central 4,059 3,075 32.0% 0 0 673 386 0 0 3,386 2,689 Illinois 294 319 -7.8% 0 0 8 0 0 0 286 318 Indiana 2,491 2,183 14.1% 0 0 0 0 0 0 2,491 2,183 Michigan 315 269 16.9% 0 0 315 269 0 0 0 0 Ohio 959 304 215.7% 0 0 350 116 0 0 609 188 Wisconsin 0 0

-- 0 0 0 0 0 0 0 0 West North Central 35 39 -10.9% 0 0 0 0 0 0 35 39 Iowa 0 0

-- 0 0 0 0 0 0 0 0 Kansas 0 0

-- 0 0 0 0 0 0 0 0 Minnesota 0 0

-- 0 0 0 0 0 0 0 0 Missouri 0 0

-- 0 0 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 35 39 -10.9% 0 0 0 0 0 0 35 39 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 394 400 -1.5% 0 0 0 0 0 0 394 400 Delaware 244 208 17.0% 0 0 0 0 0 0 244 208 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 6 6 -2.2% 0 0 0 0 0 0 6 6 Georgia 0 0

-- 0 0 0 0 0 0 0 0 Maryland 112 155 -27.4% 0 0 0 0 0 0 112 155 North Carolina 0 0

-- 0 0 0 0 0 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 0 0

-- 0 0 0 0 0 0 0 0 West Virginia 32 30 3.8% 0 0 0 0 0 0 32 30 East South Central 191 308 -38.0% 0 0 0 0 0 0 191 308 Alabama 178 292 -39.1% 0 0 0 0 0 0 178 292 Kentucky 0 0

-- 0 0 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 13 17 -19.2% 0 0 0 0 0 0 13 17 West South Central 4,246 4,682 -9.3% 0 0 1,899 2,180 0 0 2,348 2,503 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 1,247 1,292 -3.5% 0 0 266 255 0 0 982 1,037 Oklahoma 0 0

-- 0 0 0 0 0 0 0 0 Texas 2,999 3,390 -11.5% 0 0 1,633 1,925 0 0 1,366 1,465 Mountain 294 305 -3.6% 0 0 7 7 0 0 286 298 Arizona 0 0

-- 0 0 0 0 0 0 0 0 Colorado 0 0

-- 0 0 0 0 0 0 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 0 0 -30.0% 0 0 0 0 0 0 0 0 Nevada 7 7 0.9% 0 0 7 7 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 4 33 -88.0% 0 0 0 0 0 0 4 33 Wyoming 282 265 6.6% 0 0 0 0 0 0 282 265 Pacific Contiguous 1,890 1,964 -3.8% 0 29 405 297 0 0 1,484 1,638 California 1,484 1,667 -11.0% 0 29 0 0 0 0 1,484 1,638 Oregon 0 0

-- 0 0 0 0 0 0 0 0 Washington 405 297 36.4% 0 0 405 297 0 0 0 0 Pacific Noncontiguous 50 38 30.8% 0 0 0 0 0 0 50 38 Alaska 3 3 -2.9% 0 0 0 0 0 0 3 3 Hawaii 47 35 33.4% 0 0 0 0 0 0 47 35 U.S. Total 11,898 11,566 2.9% 0 29 2,984 2,911 0 3 8,913 8,624

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.11. Net Generation from Other Gases by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 36,116 34,283 5.3% 0 0 36,116 34,283 0 0 0 0 Connecticut 17,078 15,928 7.2% 0 0 17,078 15,928 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts 5,860 5,085 15.2% 0 0 5,860 5,085 0 0 0 0 New Hampshire 8,189 8,363 -2.1% 0 0 8,189 8,363 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 4,989 4,907 1.7% 0 0 4,989 4,907 0 0 0 0 Middle Atlantic 149,059 152,448 -2.2% 0 0 149,059 152,448 0 0 0 0 New Jersey 33,110 33,606 -1.5% 0 0 33,110 33,606 0 0 0 0 New York 40,775 42,695 -4.5% 0 0 40,775 42,695 0 0 0 0 Pennsylvania 75,174 76,147 -1.3% 0 0 75,174 76,147 0 0 0 0 East North Central 155,808 155,162 0.4% 22,842 26,248 132,966 128,914 0 0 0 0 Illinois 96,401 95,823 0.6% 0 0 96,401 95,823 0 0 0 0 Indiana 0 0

-- 0 0 0 0 0 0 0 0 Michigan 28,020 32,889 -14.8% 22,842 26,248 5,178 6,641 0 0 0 0 Ohio 17,087 14,890 14.8% 0 0 17,087 14,890 0 0 0 0 Wisconsin 14,300 11,560 23.7% 0 0 14,300 11,560 0 0 0 0 West North Central 41,096 40,797 0.7% 36,749 35,582 4,347 5,215 0 0 0 0 Iowa 4,347 5,215 -16.6% 0 0 4,347 5,215 0 0 0 0 Kansas 8,285 7,319 13.2% 8,285 7,319 0 0 0 0 0 0 Minnesota 11,944 11,959 -0.1% 11,944 11,959 0 0 0 0 0 0 Missouri 10,718 9,371 14.4% 10,718 9,371 0 0 0 0 0 0 Nebraska 5,802 6,933 -16.3% 5,802 6,933 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 184,645 187,696 -1.6% 171,066 173,299 13,579 14,397 0 0 0 0 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 17,870 22,015 -18.8% 17,870 22,015 0 0 0 0 0 0 Georgia 33,942 32,306 5.1% 33,942 32,306 0 0 0 0 0 0 Maryland 13,579 14,397 -5.7% 0 0 13,579 14,397 0 0 0 0 North Carolina 39,386 40,527 -2.8% 39,386 40,527 0 0 0 0 0 0 South Carolina 51,145 52,903 -3.3% 51,145 52,903 0 0 0 0 0 0 Virginia 28,723 25,548 12.4% 28,723 25,548 0 0 0 0 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central 73,239 76,612 -4.4% 73,239 76,612 0 0 0 0 0 0 Alabama 40,841 39,356 3.8% 40,841 39,356 0 0 0 0 0 0 Kentucky 0 0

-- 0 0 0 0 0 0 0 0 Mississippi 7,296 10,337 -29.4% 7,296 10,337 0 0 0 0 0 0 Tennessee 25,102 26,919 -6.8% 25,102 26,919 0 0 0 0 0 0 West South Central 69,593 70,458 -1.2% 31,152 30,809 38,441 39,648 0 0 0 0 Arkansas 15,493 14,194 9.1% 15,493 14,194 0 0 0 0 0 0 Louisiana 15,659 16,615 -5.8% 15,659 16,615 0 0 0 0 0 0 Oklahoma 0 0

-- 0 0 0 0 0 0 0 0 Texas 38,441 39,648 -3.0% 0 0 38,441 39,648 0 0 0 0 Mountain 31,934 31,278 2.1% 31,934 31,278 0 0 0 0 0 0 Arizona 31,934 31,278 2.1% 31,934 31,278 0 0 0 0 0 0 Colorado 0 0

-- 0 0 0 0 0 0 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 0 0

-- 0 0 0 0 0 0 0 0 Nevada 0 0

-- 0 0 0 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 0 0

-- 0 0 0 0 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 27,841 41,470 -32.9% 27,841 41,470 0 0 0 0 0 0 California 18,507 36,663 -49.5% 18,507 36,663 0 0 0 0 0 0 Oregon 0 0

-- 0 0 0 0 0 0 0 0 Washington 9,334 4,806 94.2% 9,334 4,806 0 0 0 0 0 0 Pacific Noncontiguous 0 0

-- 0 0 0 0 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 769,331 790,204 -2.6% 394,823 415,298 374,509 374,906 0 0 0 0

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.12. Net Generation from Nuclear Energy by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 7,360 8,732 -15.7% 950 1,148 5,966 6,795 5 6 440 783 Connecticut 312 567 -45.0% 27 53 286 514 0 0 0 0 Maine 3,733 3,979 -6.2% 0 0 3,320 3,231 0 0 412 748 Massachusetts 912 1,149 -20.6% 230 281 673 856 5 6 4 6 New Hampshire 1,289 1,605 -19.7% 324 359 965 1,241 0 0 0 5 Rhode Island 4 7 -42.4% 0 0 4 7 0 0 0 0 Vermont 1,109 1,425 -22.1% 369 455 717 945 0 0 23 24 Middle Atlantic 26,905 31,239 -13.9% 21,762 24,556 5,079 6,603 4 6 61 75 New Jersey 11 24 -55.9% 0 0 11 24 0 0 0 0 New York 24,652 27,997 -11.9% 20,728 22,801 3,860 5,116 4 6 61 75 Pennsylvania 2,242 3,217 -30.3% 1,035 1,755 1,207 1,462 0 0 0 0 East North Central 3,696 4,437 -16.7% 3,340 3,979 208 276 4 0 143 183 Illinois 111 140 -20.8% 50 47 59 93 2 0 0 0 Indiana 434 409 6.0% 434 409 0 0 0 0 0 0 Michigan 1,215 1,357 -10.5% 1,111 1,231 78 97 0 0 26 29 Ohio 414 384 8.0% 414 384 0 0 0 0 0 0 Wisconsin 1,522 2,147 -29.1% 1,332 1,909 71 85 2 0 117 153 West North Central 11,767 13,677 -14.0% 11,529 13,377 164 183 0 0 74 117 Iowa 766 925 -17.2% 761 917 6 8 0 0 0 0 Kansas 10 15 -29.5% 0 0 10 15 0 0 0 0 Minnesota 561 746 -24.8% 339 469 148 160 0 0 74 117 Missouri 714 1,185 -39.7% 714 1,185 0 0 0 0 0 0 Nebraska 1,257 1,617 -22.3% 1,257 1,617 0 0 0 0 0 0 North Dakota 2,477 2,580 -4.0% 2,477 2,580 0 0 0 0 0 0 South Dakota 5,981 6,608 -9.5% 5,981 6,608 0 0 0 0 0 0 South Atlantic 11,667 13,545 -13.9% 8,493 9,825 2,209 3,121 12 10 953 590 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 151 182 -17.3% 151 182 0 0 0 0 0 0 Georgia 2,236 2,705 -17.3% 2,212 2,679 6 7 0 0 19 19 Maryland 1,657 2,547 -35.0% 0 0 1,657 2,547 0 0 0 0 North Carolina 3,728 3,893 -4.2% 3,311 3,859 30 24 11 10 375 1 South Carolina 1,420 1,554 -8.6% 1,367 1,511 53 43 0 0 0 0 Virginia 1,044 1,210 -13.8% 969 1,132 62 68 0 0 12 11 West Virginia 1,431 1,453 -1.5% 483 462 401 433 0 0 547 559 East South Central 18,093 21,429 -15.6% 17,461 21,419 8 10 0 0 623 0 Alabama 7,435 8,884 -16.3% 7,435 8,884 0 0 0 0 0 0 Kentucky 2,362 2,969 -20.5% 2,353 2,960 8 10 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 8,296 9,576 -13.4% 7,673 9,576 0 0 0 0 623 0 West South Central 4,608 6,072 -24.1% 3,850 4,949 758 1,123 0 0 0 0 Arkansas 2,198 2,958 -25.7% 2,156 2,919 43 39 0 0 0 0 Louisiana 680 1,044 -34.9% 0 0 680 1,044 0 0 0 0 Oklahoma 1,146 1,507 -24.0% 1,146 1,507 0 0 0 0 0 0 Texas 584 563 3.8% 549 523 36 40 0 0 0 0 Mountain 34,743 42,097 -17.5% 30,089 37,070 4,653 5,026 0 0 0 0 Arizona 6,717 9,174 -26.8% 6,717 9,174 0 0 0 0 0 0 Colorado 1,497 2,083 -28.1% 1,430 1,915 68 167 0 0 0 0 Idaho 10,940 13,405 -18.4% 10,005 12,470 935 934 0 0 0 0 Montana 11,283 12,596 -10.4% 7,693 8,740 3,590 3,856 0 0 0 0 Nevada 2,440 2,191 11.4% 2,399 2,144 42 46 0 0 0 0 New Mexico 223 195 14.4% 223 195 0 0 0 0 0 0 Utah 748 1,230 -39.2% 740 1,217 8 13 0 0 0 0 Wyoming 893 1,224 -27.0% 883 1,214 10 10 0 0 0 0 Pacific Contiguous 155,712 176,690 -11.9% 153,857 173,726 1,851 2,956 3 5 1 3 California 26,837 42,557 -36.9% 25,548 40,157 1,286 2,396 3 5 0 0 Oregon 39,410 42,315 -6.9% 39,111 42,017 299 298 0 0 0 0 Washington 89,464 91,818 -2.6% 89,197 91,552 265 263 0 0 1 3 Pacific Noncontiguous 1,690 1,438 17.5% 1,604 1,365 27 25 0 0 59 49 Alaska 1,575 1,345 17.1% 1,575 1,345 0 0 0 0 0 0 Hawaii 115 93 23.0% 29 20 27 25 0 0 59 49 U.S. Total 276,240 319,355 -13.5% 252,936 291,413 20,923 26,117 28 26 2,353 1,799

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.13. Net Generation from Hydroelectric (Conventional) Power by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 8,557 8,015 6.8% 664 574 5,652 5,352 136 104 2,105 1,985 Connecticut 667 660 1.0% 0 0 667 660 0 0 0 0 Maine 4,099 4,495 -8.8% 0 0 2,468 2,421 92 89 1,539 1,985 Massachusetts 1,843 1,207 52.8% 68 48 1,198 1,145 11 13 566 0 New Hampshire 1,381 1,091 26.6% 347 291 1,003 800 31 0 0 0 Rhode Island 102 130 -21.8% 0 0 102 130 0 0 0 0 Vermont 465 433 7.5% 249 235 214 196 2 2 0 0 Middle Atlantic 10,932 9,950 9.9% 41 19 9,625 8,766 544 476 722 689 New Jersey 1,281 956 34.0% 41 19 1,044 690 194 246 1 0 New York 5,192 4,896 6.1% 0 0 4,727 4,559 220 110 246 226 Pennsylvania 4,459 4,099 8.8% 0 0 3,854 3,516 130 120 475 463 East North Central 20,666 17,149 20.5% 1,791 1,137 16,813 14,107 235 194 1,828 1,711 Illinois 8,373 6,865 22.0% 14 11 8,358 6,854 0 0 0 1 Indiana 3,546 3,621 -2.1% 286 295 3,209 3,284 22 21 29 20 Michigan 3,785 2,962 27.8% 274 5 2,510 2,116 196 158 806 683 Ohio 1,739 936 85.8% 20 16 1,367 536 0 0 352 384 Wisconsin 3,223 2,765 16.6% 1,197 810 1,370 1,317 16 15 641 624 West North Central 39,730 33,325 19.2% 12,555 9,852 26,570 22,844 83 78 521 552 Iowa 14,183 10,870 30.5% 7,479 5,149 6,664 5,671 28 34 12 15 Kansas 5,253 3,779 39.0% 852 1,018 4,401 2,761 0 0 0 0 Minnesota 9,454 8,406 12.5% 2,016 1,741 6,901 6,113 38 30 499 522 Missouri 1,299 1,240 4.7% 28 35 1,266 1,201 0 0 5 4 Nebraska 1,347 1,116 20.6% 258 280 1,072 822 17 14 0 0 North Dakota 5,280 5,245 0.7% 1,256 1,120 4,019 4,116 0 0 6 10 South Dakota 2,915 2,668 9.2% 667 509 2,248 2,160 0 0 0 0 South Atlantic 17,334 16,621 4.3% 1,056 1,027 6,784 6,008 241 305 9,253 9,281 Delaware 131 158 -17.0% 2 0 125 153 4 5 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 4,524 4,670 -3.1% 243 188 2,243 2,371 37 39 2,001 2,073 Georgia 3,279 3,190 2.8% 0 0 219 165 29 23 3,030 3,001 Maryland 898 822 9.3% 3 0 717 616 36 55 141 150 North Carolina 2,704 2,345 15.3% 4 10 1,362 986 4 0 1,334 1,350 South Carolina 2,143 2,129 0.7% 458 410 40 22 0 0 1,646 1,698 Virginia 2,358 2,196 7.4% 345 419 782 585 130 183 1,101 1,009 West Virginia 1,297 1,112 16.6% 0 0 1,297 1,112 0 0 0 0 East South Central 5,455 5,779 -5.6% 96 96 307 312 NM 0 5,050 5,371 Alabama 2,777 2,817 -1.4% 1 1 190 231 0 0 2,586 2,585 Kentucky 333 436 -23.7% 95 95 0 0 0 0 238 342 Mississippi 1,509 1,506 0.2% 0 0 3 0 0 0 1,506 1,506 Tennessee 836 1,020 -18.0% 0 0 114 81 NM 0 720 939 West South Central 46,628 42,213 10.5% 1,912 794 39,392 36,075 41 43 5,282 5,300 Arkansas 1,660 1,668 -0.4% 0 0 65 76 6 5 1,590 1,587 Louisiana 2,430 2,443 -0.5% 0 0 60 70 0 0 2,370 2,372 Oklahoma 8,521 5,919 43.9% 1,594 660 6,564 4,945 0 0 363 314 Texas 34,017 32,183 5.7% 319 134 32,704 30,984 36 38 958 1,027 Mountain 22,677 19,305 17.5% 2,700 2,636 19,510 16,185 64 60 403 424 Arizona 1,698 529 220.7% 188 65 1,502 457 8 7 0 0 Colorado 6,192 5,367 15.4% 74 73 6,093 5,273 21 18 3 3 Idaho 2,515 1,892 32.9% 70 0 2,048 1,472 0 0 397 420 Montana 1,262 1,265 -0.3% 101 99 1,161 1,166 0 0 0 0 Nevada 2,969 2,437 21.8% 0 0 2,934 2,404 32 32 3 1 New Mexico 2,574 2,242 14.8% 48 0 2,522 2,238 4 3 0 0 Utah 1,100 961 14.4% 269 278 831 683 0 0 0 0 Wyoming 4,369 4,612 -5.3% 1,951 2,120 2,418 2,491 0 0 0 0 Pacific Contiguous 45,388 40,727 11.4% 7,160 5,746 34,748 31,737 1,046 1,054 2,434 2,190 California 29,967 27,222 10.1% 2,105 1,658 26,055 23,858 1,024 1,031 783 675 Oregon 7,207 5,490 31.3% 1,369 789 5,344 4,314 22 24 472 363 Washington 8,214 8,014 2.5% 3,687 3,298 3,348 3,565 0 0 1,179 1,151 Pacific Noncontiguous 965 897 7.6% 41 51 662 568 153 161 109 116 Alaska 40 16 154.0% 19 12 18 0 0 0 3 3 Hawaii 925 881 5.0% 22 39 644 568 153 161 106 112 U.S. Total 218,333 193,981 12.6% 28,017 21,933 160,064 141,954 2,545 2,476 27,707 27,619

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.14. Net Generation from Renewable Sources Excluding Hydroelectric by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England -305 -435 -29.9% 0 0 -305 -435 0 0 0 0 Connecticut 3 6 -51.5% 0 0 3 6 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts -308 -440 -30.1% 0 0 -308 -440 0 0 0 0 New Hampshire 0 0

-- 0 0 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic -1,022 -1,124 -9.0% -579 -630 -443 -494 0 0 0 0 New Jersey -166 -197 -15.6% -166 -197 0 0 0 0 0 0 New York -413 -433 -4.6% -413 -433 0 0 0 0 0 0 Pennsylvania -443 -494 -10.2% 0 0 -443 -494 0 0 0 0 East North Central -773 -945 -18.2% -773 -945 0 0 0 0 0 0 Illinois 0 0

-- 0 0 0 0 0 0 0 0 Indiana 0 0

-- 0 0 0 0 0 0 0 0 Michigan -773 -945 -18.2% -773 -945 0 0 0 0 0 0 Ohio 0 0

-- 0 0 0 0 0 0 0 0 Wisconsin 0 0

-- 0 0 0 0 0 0 0 0 West North Central 33 114 -70.7% 33 114 0 0 0 0 0 0 Iowa 0 0

-- 0 0 0 0 0 0 0 0 Kansas 0 0

-- 0 0 0 0 0 0 0 0 Minnesota 0 0

-- 0 0 0 0 0 0 0 0 Missouri 33 114 -70.7% 33 114 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic -3,099 -3,093 0.2% -3,099 -3,093 0 0 0 0 0 0 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 0 0

-- 0 0 0 0 0 0 0 0 Georgia -838 -734 14.2% -838 -734 0 0 0 0 0 0 Maryland 0 0

-- 0 0 0 0 0 0 0 0 North Carolina 0 0

-- 0 0 0 0 0 0 0 0 South Carolina -896 -890 0.7% -896 -890 0 0 0 0 0 0 Virginia -1,366 -1,470 -7.1% -1,366 -1,470 0 0 0 0 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central -163 -660 -75.3% -163 -660 0 0 0 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 0 0

-- 0 0 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee -163 -660 -75.3% -163 -660 0 0 0 0 0 0 West South Central -74 -119 -37.4% -74 -119 0 0 0 0 0 0 Arkansas 42 34 23.2% 42 34 0 0 0 0 0 0 Louisiana 0 0

-- 0 0 0 0 0 0 0 0 Oklahoma -117 -153 -23.8% -117 -153 0 0 0 0 0 0 Texas 0 0

-- 0 0 0 0 0 0 0 0 Mountain -165 -122 34.9% -165 -122 0 0 0 0 0 0 Arizona 79 121 -34.4% 79 121 0 0 0 0 0 0 Colorado -244 -243 0.4% -244 -243 0 0 0 0 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 0 0

-- 0 0 0 0 0 0 0 0 Nevada 0 0

-- 0 0 0 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 0 0

-- 0 0 0 0 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 618 -37 NM 618 -37 0 0 0 0 0 0 California 575 -89 -747.4% 575 -89 0 0 0 0 0 0 Oregon 0 0

-- 0 0 0 0 0 0 0 0 Washington 44 52 -16.1% 44 52 0 0 0 0 0 0 Pacific Noncontiguous 0 0

-- 0 0 0 0 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total -4,950 -6,421 -22.9% -4,202 -5,492 -748 -928 0 0 0 0

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.15. Net Generation from Hydroelectric (Pumped Storage) Power by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 2,153 2,019 6.7% 0 0 1,944 1,888 88 84 121 46 Connecticut 756 705 7.3% 0 0 756 704 0 0 0 1 Maine 424 390 8.7% 0 0 245 261 88 84 92 45 Massachusetts 906 860 5.5% 0 0 877 860 0 0 29 0 New Hampshire 66 64 2.6% 0 0 66 64 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 2,497 2,441 2.3% 0 0 1,924 1,975 465 344 107 122 New Jersey 633 644 -1.7% 0 0 378 383 147 138 107 122 New York 968 905 7.0% 0 0 757 799 211 106 0 0 Pennsylvania 896 893 0.4% 0 0 789 792 107 100 0 0 East North Central 1,133 1,095 3.4% 121 133 159 163 205 166 648 633 Illinois 299 299 0.2% 0 0 0 6 0 0 299 293 Indiana 347 369 -6.1% 57 76 0 0 20 19 269 274 Michigan 395 363 8.7% 25 26 159 157 185 146 27 34 Ohio 12 10 19.2% 0 0 0 0 0 0 12 10 Wisconsin 80 54 47.4% 39 31 0 0 0 0 41 23 West North Central 478 428 11.7% 246 213 149 150 28 24 55 41 Iowa 0 0

-- 0 0 0 0 0 0 0 0 Kansas 0 0

-- 0 0 0 0 0 0 0 0 Minnesota 394 362 9.0% 163 148 149 150 28 23 55 41 Missouri 20 21 -7.6% 20 21 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 64 44 44.0% 64 44 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 4,501 4,735 -4.9% 0 0 2,205 2,183 113 177 2,183 2,375 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 3,194 3,385 -5.7% 0 0 1,436 1,486 0 0 1,757 1,899 Georgia 56 28 101.1% 0 0 0 0 0 0 56 28 Maryland 296 299 -0.7% 0 0 296 298 1 0 0 0 North Carolina 452 493 -8.3% 0 0 141 106 0 0 311 387 South Carolina 106 60 76.1% 0 0 48 0 0 0 58 60 Virginia 397 470 -15.6% 0 0 284 293 113 176 1 1 West Virginia 0 0 -100.0% 0 0 0 0 0 0 0 0 East South Central 235 396 -40.5% 8 9 0 0 0 0 227 387 Alabama 227 383 -40.8% 0 0 0 0 0 0 227 383 Kentucky 8 9 -9.8% 8 9 0 0 0 0 0 0 Mississippi 0 3 -99.2% 0 0 0 0 0 0 0 3 Tennessee 1 1 -50.1% 0 0 0 0 0 0 1 1 West South Central 714 792 -9.9% 0 0 0 0 0 0 714 792 Arkansas 30 32 -6.2% 0 0 0 0 0 0 30 32 Louisiana 376 440 -14.5% 0 0 0 0 0 0 376 440 Oklahoma 10 2 552.9% 0 0 0 0 0 0 10 2 Texas 298 319 -6.6% 0 0 0 0 0 0 298 319 Mountain 702 753 -6.8% 12 38 381 367 0 0 309 348 Arizona 24 15 65.8% 0 0 24 15 0 0 0 0 Colorado 55 63 -12.7% 0 0 11 15 0 0 45 48 Idaho 69 78 -10.8% 0 0 0 0 0 0 69 78 Montana 341 333 2.5% 0 0 341 333 0 0 0 0 Nevada 12 38 -68.5% 12 38 0 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 133 165 -19.2% 0 0 5 5 0 0 128 160 Wyoming 67 62 7.9% 0 0 0 0 0 0 67 62 Pacific Contiguous 1,012 1,128 -10.3% 0 0 268 332 0 0 744 796 California 815 917 -11.2% 0 0 158 219 0 0 657 698 Oregon 50 51 -1.9% 0 0 42 43 0 0 8 9 Washington 147 160 -8.1% 0 0 69 70 0 0 78 90 Pacific Noncontiguous 363 366 -0.9% 216 211 0 0 147 155 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 363 366 -0.9% 216 211 0 0 147 155 0 0 U.S. Total 13,787 14,154 -2.6% 603 604 7,030 7,059 1,046 950 5,108 5,541

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.16. Net Generation from Other Energy Sources by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 1,294 870 48.6% 85 55 1,199 806 9 9 0 0 Connecticut 0 0

-- 0 0 0 0 0 0 0 0 Maine 887 707 25.5% 0 0 887 707 0 0 0 0 Massachusetts 90 61 46.1% 59 44 21 8 9 9 0 0 New Hampshire 209 66 215.8% 0 0 209 66 0 0 0 0 Rhode Island 1 3 -52.6% 0 0 1 3 0 0 0 0 Vermont 107 33 222.1% 26 11 81 22 0 0 0 0 Middle Atlantic 5,132 4,633 10.8% 0 0 5,128 4,633 0 0 4 0 New Jersey 12 11 9.9% 0 0 12 11 0 0 0 0 New York 2,992 2,828 5.8% 0 0 2,988 2,828 0 0 4 0 Pennsylvania 2,129 1,794 18.6% 0 0 2,129 1,794 0 0 0 0 East North Central 14,612 11,341 28.8% 1,242 602 13,357 10,736 1 1 12 2 Illinois 7,727 6,213 24.4% 14 11 7,713 6,202 0 0 0 0 Indiana 3,210 3,285 -2.3% 0 0 3,209 3,284 1 1 0 0 Michigan 1,132 456 147.9% 274 3 858 454 0 0 0 0 Ohio 985 198 396.6% 14 14 959 182 0 0 12 2 Wisconsin 1,558 1,188 31.1% 939 574 618 614 0 0 0 0 West North Central 37,561 31,288 20.0% 12,051 9,376 25,479 21,885 31 26 0 0 Iowa 14,032 10,709 31.0% 7,452 5,122 6,578 5,583 3 4 0 0 Kansas 5,195 3,720 39.7% 852 1,018 4,343 2,702 0 0 0 0 Minnesota 7,615 6,726 13.2% 1,613 1,379 5,975 5,324 28 23 0 0 Missouri 1,245 1,178 5.6% 0 0 1,245 1,178 0 0 0 0 Nebraska 1,284 1,051 22.1% 212 229 1,072 822 0 0 0 0 North Dakota 5,275 5,236 0.7% 1,256 1,120 4,019 4,116 0 0 0 0 South Dakota 2,915 2,668 9.2% 667 509 2,248 2,160 0 0 0 0 South Atlantic 1,611 1,378 16.9% 0 0 1,608 1,373 4 5 0 0 Delaware 4 5 -24.6% 0 0 0 0 4 5 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 0 0

-- 0 0 0 0 0 0 0 0 Georgia 0 0

-- 0 0 0 0 0 0 0 0 Maryland 322 271 18.8% 0 0 322 271 0 0 0 0 North Carolina 0 0

-- 0 0 0 0 0 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 0 0

-- 0 0 0 0 0 0 0 0 West Virginia 1,286 1,103 16.6% 0 0 1,286 1,103 0 0 0 0 East South Central 47 53 -10.6% 0 0 47 53 0 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 0 0

-- 0 0 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 47 53 -10.6% 0 0 47 53 0 0 0 0 West South Central 40,372 36,153 11.7% 1,912 794 38,459 35,359 0 0 0 0 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 0 0

-- 0 0 0 0 0 0 0 0 Oklahoma 8,158 5,605 45.5% 1,594 660 6,564 4,945 0 0 0 0 Texas 32,214 30,548 5.5% 319 134 31,895 30,414 0 0 0 0 Mountain 17,080 15,317 11.5% 2,186 2,292 14,882 13,013 9 9 3 3 Arizona 532 256 108.0% 0 0 532 256 0 0 0 0 Colorado 5,969 5,200 14.8% 74 73 5,886 5,119 5 6 3 3 Idaho 1,891 1,307 44.7% 60 0 1,830 1,307 0 0 0 0 Montana 1,262 1,265 -0.3% 101 99 1,161 1,166 0 0 0 0 Nevada 129 0

-- 0 0 129 0 0 0 0 0 New Mexico 2,226 2,104 5.8% 0 0 2,222 2,101 4 3 0 0 Utah 704 573 22.9% 0 0 704 573 0 0 0 0 Wyoming 4,369 4,612 -5.3% 1,951 2,120 2,418 2,491 0 0 0 0 Pacific Contiguous 22,697 18,790 20.8% 5,431 4,008 17,266 14,781 0 0 0 0 California 9,754 7,752 25.8% 797 507 8,957 7,245 0 0 0 0 Oregon 6,343 4,775 32.8% 1,299 721 5,044 4,054 0 0 0 0 Washington 6,600 6,262 5.4% 3,335 2,780 3,265 3,482 0 0 0 0 Pacific Noncontiguous 416 353 17.7% 19 12 396 341 0 0 0 0 Alaska 37 12 200.4% 19 12 18 0 0 0 0 0 Hawaii 378 341 11.0% 0 0 378 341 0 0 0 0 U.S. Total 140,822 120,177 17.2% 22,926 17,140 117,822 102,981 54 51 19 5

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.17. Net Generation from Wind by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 7,229 7,138 1.3% 570 515 4,428 4,544 125 94 2,105 1,985 Connecticut 667 660 1.0% 0 0 667 660 0 0 0 0 Maine 3,212 3,788 -15.2% 0 0 1,581 1,714 92 89 1,539 1,985 Massachusetts 1,724 1,140 51.2% 0 0 1,157 1,137 1 3 566 0 New Hampshire 1,173 1,025 14.4% 347 291 795 734 31 0 0 0 Rhode Island 101 127 -21.1% 0 0 101 127 0 0 0 0 Vermont 353 398 -11.2% 223 224 128 172 2 2 0 0 Middle Atlantic 5,411 5,219 3.7% 0 0 4,194 4,067 506 467 711 684 New Jersey 965 876 10.1% 0 0 808 639 157 237 0 0 New York 2,148 2,061 4.2% 0 0 1,687 1,725 220 110 242 226 Pennsylvania 2,298 2,281 0.7% 0 0 1,699 1,704 130 120 469 458 East North Central 5,987 5,779 3.6% 544 534 3,395 3,342 233 193 1,816 1,709 Illinois 615 638 -3.6% 0 0 615 638 0 0 0 1 Indiana 336 336 0.2% 286 295 0 0 21 20 29 20 Michigan 2,654 2,506 5.9% 0 2 1,652 1,663 196 158 806 683 Ohio 717 722 -0.7% 0 0 377 340 0 0 340 382 Wisconsin 1,666 1,577 5.6% 258 237 751 702 16 15 641 624 West North Central 2,169 2,037 6.5% 504 476 1,091 959 53 51 521 552 Iowa 151 161 -6.0% 27 27 86 88 25 30 12 15 Kansas 57 59 -2.4% 0 0 57 59 0 0 0 0 Minnesota 1,838 1,680 9.4% 403 362 926 789 10 7 499 522 Missouri 54 62 -13.5% 28 35 21 23 0 0 5 4 Nebraska 63 65 -3.5% 46 52 0 0 17 14 0 0 North Dakota 6 10 -43.8% 0 0 0 0 0 0 6 10 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 15,342 15,089 1.7% 888 924 4,968 4,584 233 300 9,253 9,281 Delaware 105 145 -27.6% 0 0 105 145 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 4,330 4,544 -4.7% 85 88 2,209 2,345 36 39 2,001 2,073 Georgia 3,276 3,190 2.7% 0 0 218 165 28 23 3,030 3,001 Maryland 554 548 1.0% 0 0 378 343 35 55 141 150 North Carolina 2,564 2,328 10.2% 1 8 1,227 971 3 0 1,334 1,350 South Carolina 2,143 2,129 0.7% 458 410 40 22 0 0 1,646 1,698 Virginia 2,358 2,196 7.4% 345 419 782 585 130 183 1,101 1,009 West Virginia 11 9 11.8% 0 0 11 9 0 0 0 0 East South Central 5,395 5,726 -5.8% 96 96 250 258 0 0 5,050 5,371 Alabama 2,777 2,817 -1.4% 1 1 190 231 0 0 2,586 2,585 Kentucky 333 436 -23.7% 95 95 0 0 0 0 238 342 Mississippi 1,509 1,506 0.2% 0 0 3 0 0 0 1,506 1,506 Tennessee 777 967 -19.6% 0 0 57 28 0 0 720 939 West South Central 6,138 6,031 1.8% 0 0 815 688 41 43 5,282 5,300 Arkansas 1,660 1,668 -0.4% 0 0 65 76 6 5 1,590 1,587 Louisiana 2,430 2,443 -0.5% 0 0 60 70 0 0 2,370 2,372 Oklahoma 363 314 15.7% 0 0 0 0 0 0 363 314 Texas 1,684 1,606 4.8% 0 0 691 542 35 38 958 1,027 Mountain 911 842 8.2% 36 24 475 392 3 5 397 420 Arizona 211 190 10.6% 26 24 181 161 3 5 0 0 Colorado 58 62 -6.0% 0 0 58 62 0 0 0 0 Idaho 549 522 5.2% 10 0 143 102 0 0 397 420 Montana 0 0

-- 0 0 0 0 0 0 0 0 Nevada 19 0

-- 0 0 19 0 0 0 0 0 New Mexico 14 9 51.3% 0 0 14 9 0 0 0 0 Utah 60 58 2.7% 0 0 60 58 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 8,757 8,495 3.1% 648 831 4,682 4,447 996 1,026 2,431 2,190 California 6,311 6,029 4.7% 231 246 4,328 4,105 974 1,003 779 675 Oregon 832 714 16.4% 67 68 271 260 22 24 472 363 Washington 1,614 1,751 -7.8% 351 518 83 82 0 0 1,179 1,151 Pacific Noncontiguous 284 316 -10.2% 22 39 0 0 153 161 109 116 Alaska 3 3 -21.9% 0 0 0 0 0 0 3 3 Hawaii 281 313 -10.1% 22 39 0 0 153 161 106 112 U.S. Total 57,622 56,671 1.7% 3,308 3,440 24,298 23,282 2,343 2,341 27,674 27,607

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.18. Net Generation from Biomass by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 0 0

-- 0 0 0 0 0 0 0 0 Connecticut 0 0

-- 0 0 0 0 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts 0 0

-- 0 0 0 0 0 0 0 0 New Hampshire 0 0

-- 0 0 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 0 0

-- 0 0 0 0 0 0 0 0 New Jersey 0 0

-- 0 0 0 0 0 0 0 0 New York 0 0

-- 0 0 0 0 0 0 0 0 Pennsylvania 0 0

-- 0 0 0 0 0 0 0 0 East North Central 0 0

-- 0 0 0 0 0 0 0 0 Illinois 0 0

-- 0 0 0 0 0 0 0 0 Indiana 0 0

-- 0 0 0 0 0 0 0 0 Michigan 0 0

-- 0 0 0 0 0 0 0 0 Ohio 0 0

-- 0 0 0 0 0 0 0 0 Wisconsin 0 0

-- 0 0 0 0 0 0 0 0 West North Central 0 0

-- 0 0 0 0 0 0 0 0 Iowa 0 0

-- 0 0 0 0 0 0 0 0 Kansas 0 0

-- 0 0 0 0 0 0 0 0 Minnesota 0 0

-- 0 0 0 0 0 0 0 0 Missouri 0 0

-- 0 0 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 0 0

-- 0 0 0 0 0 0 0 0 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 0 0

-- 0 0 0 0 0 0 0 0 Georgia 0 0

-- 0 0 0 0 0 0 0 0 Maryland 0 0

-- 0 0 0 0 0 0 0 0 North Carolina 0 0

-- 0 0 0 0 0 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 0 0

-- 0 0 0 0 0 0 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central 0 0

-- 0 0 0 0 0 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 0 0

-- 0 0 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 0 0

-- 0 0 0 0 0 0 0 0 West South Central 0 0

-- 0 0 0 0 0 0 0 0 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 0 0

-- 0 0 0 0 0 0 0 0 Oklahoma 0 0

-- 0 0 0 0 0 0 0 0 Texas 0 0

-- 0 0 0 0 0 0 0 0 Mountain 2,757 2,540 8.5% 269 278 2,488 2,262 0 0 0 0 Arizona 0 0

-- 0 0 0 0 0 0 0 0 Colorado 0 0

-- 0 0 0 0 0 0 0 0 Idaho 75 63 17.6% 0 0 75 63 0 0 0 0 Montana 0 0

-- 0 0 0 0 0 0 0 0 Nevada 2,347 2,146 9.4% 0 0 2,347 2,146 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 335 330 1.3% 269 278 66 52 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 12,545 12,552 -0.1% 875 858 11,670 11,694 0 0 0 0 California 12,519 12,552 -0.3% 875 858 11,644 11,694 0 0 0 0 Oregon 26 0

-- 0 0 26 0 0 0 0 0 Washington 0 0

-- 0 0 0 0 0 0 0 0 Pacific Noncontiguous 261 224 16.6% 0 0 261 224 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 261 224 16.6% 0 0 261 224 0 0 0 0 U.S. Total 15,562 15,316 1.6% 1,143 1,137 14,419 14,180 0 0 0 0

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.19. Net Generation from Geothermal by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 35 7 427.1% 9 4 25 2 1 1 0 0 Connecticut 0 0

-- 0 0 0 0 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts 30 5 521.6% 9 4 20 0 1 1 0 0 New Hampshire 0 0

-- 0 0 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 5 2 179.0% 0 0 5 2 0 0 0 0 Middle Atlantic 389 98 295.3% 41 19 303 65 37 8 8 5 New Jersey 304 69 341.8% 41 19 225 41 37 8 1 0 New York 53 6 718.1% 0 0 53 6 0 0 0 0 Pennsylvania 32 23 38.9% 0 0 26 18 0 0 6 5 East North Central 67 30 128.3% 6 1 61 28 0 0 0 0 Illinois 31 14 118.0% 0 0 31 14 0 0 0 0 Indiana NM 0

-- 0 0 NM 0 0 0 0 0 Michigan 0 0

-- 0 0 0 0 0 0 0 0 Ohio 37 15 136.4% 6 1 31 14 0 0 0 0 Wisconsin 0 0

-- 0 0 0 0 0 0 0 0 West North Central 0 0

-- 0 0 0 0 0 0 0 0 Iowa 0 0

-- 0 0 0 0 0 0 0 0 Kansas 0 0

-- 0 0 0 0 0 0 0 0 Minnesota 0 0

-- 0 0 0 0 0 0 0 0 Missouri 0 0

-- 0 0 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 381 154 147.3% 168 103 209 51 5 0 0 0 Delaware 23 8 172.5% 2 0 20 8 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 194 126 54.0% 159 100 34 26 1 0 0 0 Georgia 3 0

-- 0 0 NM 0 2 0 0 0 Maryland 22 3 730.5% 3 0 18 3 1 0 0 0 North Carolina 139 17 702.6% 4 2 135 15 1 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 0 0

-- 0 0 0 0 0 0 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central 12 0

-- 0 0 10 0 NM 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 0 0

-- 0 0 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 12 0

-- 0 0 10 0 NM 0 0 0 West South Central 118 29 313.0% 0 0 118 29 1 0 0 0 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 0 0

-- 0 0 0 0 0 0 0 0 Oklahoma 0 0

-- 0 0 0 0 0 0 0 0 Texas 118 29 313.0% 0 0 118 29 1 0 0 0 Mountain 1,930 607 217.9% 210 41 1,665 518 52 47 3 1 Arizona 955 83 NM 162 41 789 40 4 2 0 0 Colorado 165 105 58.1% 0 0 150 92 16 12 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 0 0

-- 0 0 0 0 0 0 0 0 Nevada 473 291 62.6% 0 0 438 258 32 32 3 1 New Mexico 334 128 161.2% 48 0 286 128 0 0 0 0 Utah 2 0

-- 0 0 2 0 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 1,390 890 56.2% 205 48 1,130 814 51 28 4 0 California 1,382 889 55.5% 202 47 1,126 814 51 28 4 0 Oregon 6 0 NM 3 0 4 0 0 0 0 0 Washington 1 1 -5.5% 1 1 0 0 0 0 0 0 Pacific Noncontiguous 5 4 28.2% 0 0 5 4 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 5 4 28.2% 0 0 5 4 0 0 0 0 U.S. Total 4,327 1,818 138.0% 639 216 3,525 1,511 148 84 14 7

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 3.20. Net Generation from Solar by State, by Sector, 2012 and 2011 (Thousand Megawatthours) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorPeriod Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Renewable Sources Other Total

2002 336,848 61,313 11,513 708,738 117,513 571,509 48,263 1,855,697 2003 333,361 68,329 16,934 610,122 110,263 632,366 54,960 1,826,335 2004 351,871 80,824 16,659 654,242 126,157 667,341 45,456 1,942,550 2005 341,806 79,362 13,021 624,008 138,469 664,691 41,400 1,902,757 2006 332,548 54,224 24,009 603,288 126,049 689,549 49,308 1,878,973 2007 326,803 50,882 25,373 554,394 116,313 651,230 46,822 1,771,816 2008 315,244 29,554 18,263 509,330 110,680 610,131 23,729 1,616,931 2009 281,557 32,591 20,308 513,002 99,556 546,974 33,287 1,527,276 2010 300,303 19,914 21,448 524,494 91,439 581,310 28,755 1,567,662 2011 286,210 15,230 21,552 535,150 103,615 586,299 31,067 1,579,124 2012 252,605 12,452 24,419 556,945 113,147 580,513 24,571 1,564,653

January 27,238 2,420 1,809 46,343 7,527 49,564 1,834 136,735 February 24,966 1,988 1,887 40,962 6,706 45,274 2,142 123,926 March 25,445 1,345 1,610 43,478 7,940 50,043 2,413 132,275

April 32,199 1,472 1,556 39,957 7,688 47,082 2,356 132,311 May 22,885 1,390 1,702 41,049 7,682 46,789 2,572 124,070 June 22,929 1,265 1,861 41,350 7,880 47,068 2,598 124,950 July 24,483 1,631 1,791 47,085 7,573 48,956 2,503 134,022 August 24,539 1,417 1,788 47,723 8,061 49,145 2,653 135,328 September 22,849 1,303 1,782 43,318 7,552 47,918 2,379 127,101 October 22,502 1,647 1,867 43,166 7,379 49,005 2,434 128,000 November 23,552 1,756 1,948 42,425 7,513 48,714 2,311 128,220 December 26,714 2,278 1,846 47,638 7,938 51,751 2,560 140,725

January 28,049 2,161 1,867 45,950 7,869 53,111 1,943 140,950 February 24,489 1,437 1,798 41,202 8,688 46,989 2,404 127,007 March 25,103 1,325 1,669 42,279 8,789 49,555 2,621 131,341

April 22,645 1,150 1,857 40,914 7,980 45,774 2,332 122,652 May 23,267 1,140 1,903 42,606 8,549 45,054 2,616 125,135 June 22,940 1,148 1,811 42,816 8,424 48,089 2,747 127,974 July 24,535 1,096 1,847 49,682 8,484 48,877 2,714 137,236 August 24,093 1,135 1,610 50,264 8,442 49,078 2,749 137,371 September 22,602 1,096 1,783 45,244 9,122 48,147 2,709 130,703 October 22,495 1,238 1,825 42,548 9,477 48,366 2,762 128,711 November 22,098 1,163 1,740 43,060 8,591 50,337 2,652 129,641 December 23,893 1,140 1,841 48,587 9,203 52,922 2,817 140,403

January 25,211 2,281 2,292 47,409 9,732 49,808 2,107 138,839 February 22,416 961 2,017 43,785 9,416 47,023 2,035 127,654 March 21,458 1,057 2,012 44,005 9,956 48,544 1,937 128,970

April 18,141 850 1,507 44,946 10,053 44,838 1,866 122,201 May 20,238 923 1,627 45,801 9,832 47,116 2,073 127,611 June 19,799 878 1,881 47,072 9,567 46,476 2,182 127,855 July 21,190 913 2,175 52,025 9,516 48,617 2,028 136,463 August 21,162 908 2,386 50,360 9,883 48,931 2,145 135,775 September 19,447 782 2,072 45,635 8,567 48,066 1,957 126,527 October 20,317 999 2,205 44,727 8,350 49,311 2,034 127,943 November 21,049 920 2,165 43,801 8,466 49,926 2,039 128,366 December 22,177 979 2,079 47,379 9,809 51,858 2,168 136,450

Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, and solar thermal. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. Beginning with the collection of Form EIA-923 in January 2008, the methodology for separating the fuel used for electricity generation and useful thermal output from combined heat and power plants changed. The new methodology was retroactively applied to 2004-2007. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.21. Useful Thermal Output by Energy Source: Total Combined Heat and Power (All Sectors), 2002 - 2012 (Billion Btus)

Annual Totals

2010

2011

2012Period Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Renewable Sources Other Total

2002 40,020 1,319 2,550 214,137 5,961 12,550 4,732 281,269 2003 38,249 5,551 1,828 200,077 9,282 19,785 3,296 278,068 2004 39,014 5,731 2,486 239,416 18,200 17,347 3,822 326,017 2005 39,652 5,571 2,238 239,324 36,694 18,240 3,884 345,605 2006 38,133 4,812 2,253 207,095 22,567 17,284 4,435 296,579 2007 38,260 5,294 1,862 212,705 20,473 19,166 4,459 302,219 2008 37,220 5,479 1,353 204,167 22,109 17,052 4,854 292,234 2009 38,015 5,341 1,445 190,875 19,830 17,625 5,055 278,187 2010 38,325 4,702 1,108 186,772 19,707 17,589 5,040 273,244 2011 35,209 4,484 1,231 190,712 20,435 16,029 6,044 274,143 2012 26,093 4,405 1,246 200,294 20,948 16,369 5,545 274,900

January 3,790 443 116 16,624 1,717 1,660 394 24,745 February 3,505 271 121 14,780 1,598 1,574 367 22,215 March 3,469 202 137 15,718 1,738 1,595 391 23,250

April 2,859 382 94 14,056 1,735 1,274 407 20,807 May 2,828 421 105 14,931 1,709 1,183 333 21,510 June 3,017 403 83 15,064 1,639 1,434 450 22,090 July 3,306 404 87 17,574 1,671 1,390 455 24,888 August 3,215 411 19 17,185 1,669 1,421 465 24,384 September 2,966 398 27 15,517 1,631 1,292 429 22,259 October 2,881 417 100 14,262 1,302 1,514 408 20,885 November 3,049 522 125 14,761 1,615 1,560 420 22,053 December 3,440 427 95 16,301 1,682 1,692 522 24,159

January 3,424 410 55 16,673 1,708 1,727 550 24,547 February 3,031 312 92 15,005 1,594 1,555 521 22,108 March 3,095 334 122 15,548 1,854 1,329 546 22,828

April 2,804 376 102 14,699 1,625 998 419 21,023 May 3,122 371 119 14,857 1,735 1,223 533 21,960 June 2,756 372 102 15,092 1,601 1,248 527 21,699 July 3,057 393 119 18,064 1,718 1,341 514 25,206 August 2,975 410 116 17,845 1,683 1,278 477 24,785 September 2,753 401 114 15,831 1,748 1,274 452 22,571 October 2,788 391 86 14,690 1,693 1,313 491 21,451 November 2,530 370 94 15,247 1,660 1,337 454 21,692 December 2,874 344 112 17,161 1,817 1,405 560 24,273

January 2,725 514 122 17,364 1,820 1,457 454 24,454 February 2,268 350 118 15,957 1,730 1,345 449 22,217 March 2,127 235 114 14,749 1,906 1,533 529 21,193

April 1,623 291 95 15,972 1,739 1,094 440 21,254 May 2,208 381 120 17,100 1,629 1,117 420 22,974 June 2,155 400 63 17,381 1,669 1,342 468 23,476 July 2,304 360 103 18,668 1,770 1,254 429 24,888 August 2,415 370 105 18,647 1,785 1,355 486 25,163 September 2,203 355 104 16,124 1,736 1,237 447 22,206 October 2,180 387 98 15,749 1,750 1,505 456 22,125 November 1,954 377 98 15,033 1,575 1,536 468 21,041 December 1,932 384 107 17,550 1,840 1,596 500 23,909

Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, and solar thermal. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. Beginning with the collection of Form EIA-923 in January 2008, the methodology for separating the fuel used for electricity generation and useful thermal output from combined heat and power plants changed. The new methodology was retroactively applied to 2004-2007. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.22. Useful Thermal Output by Energy Source: Electric Power Sector Combined Heat and Power, 2002 - 2012 (Billion Btus)

Annual Totals

2010

2011

2012Period Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Renewable Sources Other Total

2002 18,477 2,600 143 36,265 0 6,902 4,801 69,188 2003 22,780 2,520 196 16,955 0 8,296 6,142 56,889 2004 22,450 4,118 165 21,851 0 8,936 6,350 63,871 2005 22,601 3,518 166 20,227 0 8,647 5,921 61,081 2006 22,186 2,092 172 19,370 0 9,359 6,242 59,422 2007 22,595 1,640 221 20,040 0 6,651 3,983 55,131 2008 22,991 1,822 177 20,183 0 8,863 6,054 60,091 2009 20,057 1,095 155 25,902 0 8,450 5,761 61,420 2010 19,216 845 216 29,791 13 7,917 5,333 63,330 2011 17,234 687 111 24,848 14 7,433 5,988 56,314 2012 13,992 523 229 27,922 0 7,970 6,426 57,063

January 2,144 116 24 2,600 1 657 398 5,940 February 1,894 100 21 2,372 1 641 340 5,369 March 1,658 25 27 2,320 1 752 403 5,186

April 1,278 36 16 2,114 1 760 456 4,661 May 1,318 50 0 1,949 1 947 644 4,909 June 1,531 51 0 2,060 1 715 501 4,859 July 1,628 152 0 2,866 1 682 505 5,833 August 1,727 110 21 3,226 1 711 532 6,327 September 1,476 37 20 2,623 1 601 431 5,189 October 1,320 17 23 2,583 1 489 455 4,887 November 1,418 30 30 2,436 1 446 342 4,704 December 1,825 123 34 2,642 1 516 327 5,467

January 1,966 310 26 2,275 1 542 348 5,469 February 1,770 91 21 1,857 1 511 376 4,627 March 1,665 33 25 1,771 1 554 529 4,579

April 1,263 9 0 1,657 1 562 428 3,921 May 1,306 29 0 1,817 1 612 535 4,301 June 1,378 15 0 1,778 1 664 568 4,404 July 1,534 37 0 2,435 1 623 521 5,152 August 1,372 33 0 2,442 1 726 580 5,154 September 1,272 40 0 2,130 1 622 584 4,649 October 1,086 16 0 1,979 1 613 493 4,189 November 1,176 62 12 2,163 1 720 491 4,624 December 1,445 11 28 2,544 1 683 533 5,245

January 1,539 235 29 2,378 0 681 593 5,455 February 1,340 13 25 2,289 0 624 506 4,798 March 1,216 35 23 2,179 0 613 467 4,533

April 941 6 2 2,027 0 632 456 4,063 May 1,072 8 0 2,100 0 650 580 4,410 June 1,072 15 0 2,209 0 633 609 4,539 July 1,163 113 22 2,822 0 699 537 5,356 August 1,159 30 26 2,708 0 723 579 5,224 September 1,019 8 25 2,493 0 654 558 4,757 October 950 6 27 2,324 0 723 508 4,537 November 1,152 30 24 2,204 0 626 488 4,525 December 1,369 25 26 2,190 0 712 544 4,866

Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, and solar thermal. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. Beginning with the collection of Form EIA-923 in January 2008, the methodology for separating the fuel used for electricity generation and useful thermal output from combined heat and power plants changed. The new methodology was retroactively applied to 2004-2007. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.23. Useful Thermal Output by Energy Source: Commerical Sector Combined Heat and Power, 2002 - 2012 (Billion Btus)

Annual Totals

2010

2011

2012Period Coal Petroleum Liquids Petroleum Coke Natural Gas Other Gas Renewable Sources Other Total

2002 278,351 57,394 8,820 458,336 111,552 552,056 38,731 1,505,240 2003 272,332 60,258 14,910 393,090 100,981 604,285 45,522 1,491,378 2004 290,407 70,976 14,008 392,974 107,956 641,058 35,284 1,552,663 2005 279,552 70,273 10,616 364,457 101,775 637,803 31,594 1,496,071 2006 272,229 47,320 21,584 376,822 103,481 662,906 38,630 1,522,971 2007 265,948 43,948 23,290 321,648 95,840 625,413 38,380 1,414,466 2008 255,032 22,253 16,733 284,980 88,571 584,216 12,821 1,264,606 2009 223,485 26,155 18,708 296,225 79,726 520,898 22,471 1,187,669 2010 242,762 14,366 20,124 307,931 71,719 555,804 18,382 1,231,088 2011 233,767 10,059 20,209 319,590 83,167 562,838 19,035 1,248,666 2012 212,520 7,524 22,944 328,729 92,199 556,174 12,599 1,232,689

January 21,304 1,860 1,668 27,119 5,810 47,247 1,042 106,050 February 19,567 1,618 1,746 23,811 5,107 43,059 1,435 96,343 March 20,319 1,118 1,447 25,439 6,201 47,696 1,619 103,839

April 28,063 1,054 1,446 23,787 5,951 45,048 1,493 106,843 May 18,739 919 1,597 24,169 5,972 44,659 1,595 97,652 June 18,381 811 1,778 24,226 6,239 44,919 1,648 98,002 July 19,550 1,076 1,704 26,645 5,901 46,884 1,543 103,302 August 19,597 897 1,749 27,312 6,391 47,013 1,656 104,616 September 18,407 868 1,735 25,178 5,920 46,025 1,519 99,653 October 18,301 1,213 1,744 26,321 6,076 47,002 1,571 102,228 November 19,085 1,204 1,793 25,228 5,896 46,708 1,549 101,464 December 21,449 1,728 1,717 28,696 6,254 49,543 1,711 111,098

January 22,659 1,441 1,787 27,002 6,159 50,841 1,044 110,933 February 19,689 1,034 1,685 24,341 7,093 44,923 1,507 100,271 March 20,342 958 1,522 24,960 6,934 47,672 1,546 103,933

April 18,577 765 1,756 24,557 6,354 44,215 1,485 97,709 May 18,839 739 1,783 25,932 6,813 43,219 1,547 98,873 June 18,806 761 1,709 25,946 6,821 46,177 1,652 101,872 July 19,944 666 1,728 29,183 6,765 46,913 1,678 106,879 August 19,746 692 1,494 29,976 6,758 47,073 1,692 107,432 September 18,576 656 1,670 27,284 7,373 46,251 1,674 103,483 October 18,621 831 1,740 25,879 7,783 46,439 1,778 103,072 November 18,392 731 1,634 25,650 6,930 48,280 1,708 103,324 December 19,575 786 1,701 28,882 7,384 50,834 1,724 110,885

January 20,947 1,532 2,141 27,667 7,912 47,670 1,060 108,930 February 18,809 598 1,874 25,539 7,686 45,053 1,080 100,639 March 18,116 787 1,875 27,078 8,050 46,398 941 103,244

April 15,577 552 1,410 26,947 8,314 43,112 970 96,884 May 16,959 534 1,507 26,601 8,203 45,350 1,073 100,227 June 16,572 463 1,818 27,482 7,899 44,501 1,105 99,839 July 17,723 440 2,051 30,535 7,745 46,664 1,061 106,219 August 17,588 508 2,255 29,005 8,098 46,854 1,080 105,388 September 16,225 419 1,943 27,018 6,831 46,176 952 99,564 October 17,187 607 2,080 26,654 6,601 47,083 1,070 101,281 November 17,942 513 2,044 26,564 6,892 47,763 1,082 102,800 December 18,875 570 1,946 27,640 7,969 49,551 1,124 107,675

Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. Other Gas includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, Other Gas included propane and synthesis gases. See the Technical Notes for fuel conversion factors. Renewable Sources include wood, black liquor, other wood waste, biogenic municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, and solar thermal. Other includes non-biogenic municipal solid waste, batteries, hydrogen, purchased steam, sulfur, tire-derived fuel, and other miscellaneous energy sources. Notes: Beginning with 2001 data, non-biogenic municipal solid waste and tire-derived fuels are reclassified as non-renewable energy sources and included in Other. Biogenic municipal solid waste is included in Other Renewable Sources. Beginning with the collection of Form EIA-923 in January 2008, the methodology for separating the fuel used for electricity generation and useful thermal output from combined heat and power plants changed. The new methodology was retroactively applied to 2004-2007. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. NM=Not meaningful due to large standard error. W=Withheld to avoid disclosure of individual company data. Sources: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report; U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report; and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 3.24. Useful Thermal Output by Energy Source: Industrial Sector Combined Heat and Power, 2002 - 2012 (Billion Btus)

Annual Totals

2010

2011

2012

# Chapter 4
Generation CapacityYear Coal Petroleum Natural Gas Other Gases Nuclear Hydroelectric ConventionalOther RenewablesHydroelectric Pumped StorageOther Energy Sources

2002 633 1,147 1,649 40 66 1,426 682 38 28 2003 629 1,166 1,693 40 66 1,425 741 38 27 2004 625 1,143 1,670 46 66 1,425 749 39 28 2005 619 1,133 1,664 44 66 1,422 781 39 29 2006 616 1,148 1,659 46 66 1,421 843 39 29 2007 606 1,163 1,659 46 66 1,424 929 39 25 2008 598 1,170 1,655 43 66 1,423 1,076 39 29 2009 593 1,168 1,652 43 66 1,427 1,219 39 28 2010 580 1,169 1,657 48 66 1,432 1,355 39 32 2011 589 1,146 1,646 41 66 1,434 1,582 40 54 2012 557 1,129 1,714 44 66 1,426 1,956 41 64

2002 363 811 699 1 37 913 57 33

-- 2003 359 827 715 1 37 912 64 33 1 2004 357 816 722 2 37 908 65 34 1 2005 353 813 743 1 37 906 71 34 1 2006 353 832 758 1 37 905 84 34 1 2007 351 851 767 1 37 904 93 34 1 2008 348 866 774

-- 37 902 107 34 1 2009 340 855 768

-- 34 887 129 34 1 2010 333 855 775 3 34 888 155 34

-- 2011 332 829 777

-- 34 884 189 35 1 2012 315 815 797

-- 34 875 238 36 5

2002 106 180 326 1 29 455 430 5 4 2003 99 182 350

-- 29 456 468 5 2 2004 100 173 355 1 29 457 478 5 2 2005 101 170 357 2 29 456 502 5 2 2006 101 166 356 2 29 458 552 5 2 2007 101 166 364 1 29 462 625 5 1 2008 99 166 365

-- 29 464 751 5 2 2009 100 173 377 1 32 485 868 5 2 2010 102 175 380 1 32 488 966 5 6 2011 98 166 373

-- 32 490 1,106 5 12 2012 88 150 368

-- 32 494 1,388 5 16

2002 44 15 169 2

-- -- 28

-- -- 2003 49 17 187 3

-- -- 34

-- -- 2004 48 15 180 3

-- -- 30

-- -- 2005 48 14 177 3

-- -- 33

-- -- 2006 50 15 173 4

-- -- 32

-- -- 2007 48 12 170 4

-- -- 32

-- -- 2008 47 12 169 3

-- -- 36

-- -- 2009 51 10 166 3

-- -- 41

-- -- 2010 48 10 161 2

-- -- 41

-- -- 2011 45 11 156 1

-- -- 38

-- 1 2012 42 12 157 2

-- -- 47

-- --

2002 22 63 122

-- -- 9 41

-- -- 2003 22 65 121

-- -- 9 44

-- -- 2004 21 65 121 1

-- 9 46

-- -- 2005 20 64 113 1

-- 9 48

-- -- 2006 22 62 109 1

-- 9 47

-- -- 2007 20 64 106 1

-- 9 47

-- 1 2008 20 62 106 1

-- 9 49

-- 1 2009 18 68 107 1

-- 9 47

-- 1 2010 17 69 110 1

-- 9 57

-- 1 2011 22 80 118

-- -- 10 105

-- 2 2012 22 89 153

-- -- 9 129

-- 2

2002 98 71 317 36

-- 49 125

-- 24 2003 100 71 310 36

-- 48 130

-- 24 2004 99 74 292 39

-- 51 130

-- 25 2005 97 72 274 37

-- 51 127

-- 26 2006 90 73 263 38

-- 49 128

-- 26 2007 86 70 252 39

-- 49 132

-- 22 2008 84 64 241 39

-- 48 133

-- 25 2009 84 62 234 38

-- 46 134

-- 24 2010 80 60 231 41

-- 47 136

-- 25 2011 92 60 222 40

-- 50 144

-- 38 2012 90 63 239 42

-- 48 154

-- 41 Industrial Sector

Notes: The number of power plants for each energy source is the number of sites for which the respective energy source was reported as the most predominant energy source for at least one of its generators. If all generators for a site have the same energy source reported as the most predominant, that site will be counted once under that energy source. However, if the most predominant energy source is not the same for all generators within a site, the site is counted more than once, based on the number of most predominant energy sources for generators at a site. In general, this table translates the number of generators by energy source into the number of sites represented by the generators for an energy source. Therefore, the count for Total (All Sectors) above is the sum of the counts for each sector by energy source and does not necessarily represent unique sites. In addition, changes to predominant energy sources and status codes from year to year may result in changes to previously-posted data. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.' 

### Table 4.1. Count of Electric Power Industry Power Plants, by Sector, by Predominant Energy Sources within Plant, 2002 through 2012

Total (All Sectors)

Electric Utilities

Independent Power Producers, Non-Combined Heat and Power Plants

Independent Power Producers, Combined Heat and Power Plants

Commercial SectorYear Coal Petroleum Natural Gas Other Gases Nuclear Hydroelectric ConventionalOther Renewable Sources Hydroelectric Pumped StorageOther Energy Sources Total

2002 315,350 59,651 312,512 2,008 98,657 79,356 16,710 20,371 686 905,301 2003 313,019 60,730 355,442 1,994 99,209 78,694 18,153 20,522 684 948,446 2004 313,020 59,119 371,011 2,296 99,628 77,641 18,717 20,764 746 962,942 2005 313,380 58,548 383,061 2,063 99,988 77,541 21,205 21,347 887 978,020 2006 312,956 58,097 388,294 2,256 100,334 77,821 24,113 21,461 882 986,215 2007 312,738 56,068 392,876 2,313 100,266 77,885 30,069 21,886 788 994,888 2008 313,322 57,445 397,460 1,995 100,755 77,930 38,466 21,858 942 1,010,171 2009 314,294 56,781 401,272 1,932 101,004 78,518 48,552 22,160 888 1,025,400 2010 316,800 55,647 407,028 2,700 101,167 78,825 53,811 22,199 884 1,039,062 2011 317,640 51,482 415,191 1,934 101,419 78,652 61,221 22,293 1,420 1,051,251 2012 309,680 47,167 422,364 1,946 101,885 78,738 77,155 22,368 1,729 1,063,033

2002 244,056 33,876 127,692 61 63,202 73,391 989 17,807

-- 561,074 2003 236,473 32,570 125,612 61 60,964 72,827 925 17,803 13 547,249 2004 235,976 31,415 131,734 58 60,651 71,696 960 18,048 13 550,550 2005 229,705 30,867 147,752

-- 56,564 71,568 1,545 18,195 39 556,235 2006 230,644 30,419 157,742 104 56,143 71,840 2,291 18,301 39 567,523 2007 231,289 29,115 162,756 104 54,211 72,186 2,806 18,693 39 571,200 2008 231,857 30,657 173,106

-- 54,376 72,142 4,066 18,664 39 584,908 2009 234,397 30,174 180,571

-- 54,355 72,690 5,614 18,930 39 596,769 2010 235,707 28,972 184,231 539 54,369 72,974 6,316 18,969

-- 602,076 2011 236,392 27,670 193,631

-- 54,352 72,182 7,811 19,062 5 611,105 2012 232,079 26,732 206,774

-- 54,717 72,505 9,824 19,094 61 621,785

2002 61,770 23,664 140,404 9 35,455 4,911 10,390 2,564 80 279,246 2003 66,538 26,028 178,624 6 38,244 5,058 11,786 2,719 46 329,049 2004 67,242 25,918 190,855 8 38,978 5,274 12,070 2,717 46 343,106 2005 73,734 26,041 188,043 12 43,424 5,284 13,864 3,152 46 353,601 2006 72,730 25,384 184,196 20 44,190 5,263 15,865 3,160 46 350,854 2007 71,943 24,818 184,888 8 46,055 5,346 21,002 3,193 26 357,278 2008 71,864 24,823 179,169

-- 46,379 5,433 28,139 3,193 46 359,044 2009 70,123 24,657 176,035 8 46,649 5,470 36,556 3,230 46 362,773 2010 71,214 24,867 178,190 8 46,798 5,489 41,014 3,230 77 370,887 2011 72,120 22,399 176,517

-- 47,067 5,539 46,698 3,230 169 373,739 2012 69,068 18,644 170,654

-- 47,168 5,569 60,117 3,274 470 374,964

2002 5,222 1,084 28,455 182

-- -- 555

-- -- 35,499 2003 5,534 1,051 34,895 185

-- 1 665

-- -- 42,332 2004 5,609 677 32,600 289

-- 1 555

-- -- 39,731 2005 5,560 530 31,740 289

-- 1 614

-- -- 38,735 2006 5,837 970 30,031 325

-- 1 628

-- -- 37,793 2007 5,885 907 29,468 339

-- -- 656

-- -- 37,254 2008 5,927 900 29,575 206

-- -- 701

-- -- 37,309 2009 5,940 897 28,875 206

-- -- 740

-- -- 36,658 2010 5,451 766 29,006 182

-- -- 846

-- -- 36,250 2011 5,146 317 29,373 30

-- -- 793

-- 53 35,712 2012 4,756 317 29,129 83

-- -- 981

-- -- 35,266

2002 292 301 1,216

-- -- 22 357

-- -- 2,188 2003 347 343 994

-- -- 22 371

-- -- 2,077 2004 368 321 1,069 5

-- 22 404

-- -- 2,188 2005 397 333 1,024 5

-- 25 435

-- -- 2,219 2006 428 341 1,040 5

-- 25 433

-- -- 2,272 2007 428 348 1,064 5

-- 22 443

-- 3 2,312 2008 428 352 1,059 5

-- 22 444

-- 3 2,312 2009 424 348 1,105 5

-- 22 480

-- 3 2,386 2010 418 368 1,155 5

-- 22 520

-- 3 2,490 2011 436 406 1,283

-- -- 234 694

-- 4 3,056 2012 436 443 1,545

-- -- 18 777

-- 4 3,223

2002 4,010 726 14,745 1,756

-- 1,033 4,419

-- 607 27,295 2003 4,127 738 15,316 1,742

-- 786 4,406

-- 625 27,740 2004 3,825 789 14,753 1,937

-- 648 4,728

-- 687 27,367 2005 3,984 777 14,501 1,757

-- 662 4,747

-- 802 27,230 2006 3,317 983 15,285 1,802

-- 693 4,896

-- 797 27,773 2007 3,194 880 14,699 1,858

-- 331 5,163

-- 720 26,844 2008 3,246 713 14,551 1,784

-- 334 5,116

-- 854 26,599 2009 3,412 704 14,686 1,714

-- 337 5,162

-- 800 26,815 2010 4,010 674 14,447 1,967

-- 341 5,116

-- 804 27,359 2011 3,547 690 14,389 1,904

-- 697 5,225

-- 1,188 27,639 2012 3,342 1,032 14,263 1,863

-- 646 5,457

-- 1,194 27,795 Industrial Sector

Notes: Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011, coal-derived synthesis gas was included in Other Gases. Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. Other Gases also includes blast furnace gas. Prior to 2011, waste heat was included in Natural Gas. Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Other Renewable Sources include wood, black liquor, other wood waste, municipal solid waste, landfill gas, sludge waste, agriculture byproducts, other biomass, geothermal, solar thermal, photovoltaic energy, and wind. Other Energy Sources include batteries, hydrogen, purchased steam, sulfur, tire-derived fuels and other miscellaneous energy sources. In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.' 

### Table 4.2.A. Existing Net Summer Capacity by Energy Source and Producer Type, 2002 through 2012 (Megawatts)

Total (All Sectors)

Electric Utilities

Independent Power Producers, Non-Combined Heat and Power Plants

Independent Power Producers, Combined Heat and Power Plants

Commercial SectorYear Wind Solar Thermal and PhotovoltaicWood and WoodDerived Fuels Geothermal Other Biomass Total (Other Renewable

Sources)

2002 4,417 397 5,844 2,252 3,800 16,710 2003 5,995 397 5,871 2,133 3,758 18,153 2004 6,456 398 6,182 2,152 3,529 18,717 2005 8,706 411 6,193 2,285 3,609 21,205 2006 11,329 411 6,372 2,274 3,727 24,113 2007 16,515 502 6,704 2,214 4,134 30,069 2008 24,651 536 6,864 2,229 4,186 38,466 2009 34,296 619 6,939 2,382 4,317 48,552 2010 39,135 866 7,037 2,405 4,369 53,811 2011 45,676 1,524 7,077 2,409 4,536 61,221 2012 59,075 3,170 7,508 2,592 4,811 77,155

2002 111 9 248 271 350 989 2003 140 9 268 162 346 925 2004 326 10 313 152 160 960 2005 765 11 391 242 136 1,545 2006 1,441 11 428 240 172 2,291 2007 1,928 12 418 158 290 2,806 2008 3,190 14 427 159 276 4,066 2009 4,655 42 431 159 327 5,614 2010 5,338 79 414 159 325 6,316 2011 6,735 202 359 159 356 7,811 2012 8,489 332 364 162 477 9,824

2002 4,305 388 1,162 1,981 2,553 10,390 2003 5,855 388 1,121 1,972 2,450 11,786 2004 6,130 388 1,138 2,000 2,414 12,070 2005 7,941 400 1,033 2,044 2,447 13,864 2006 9,888 400 1,037 2,034 2,505 15,865 2007 14,587 489 1,066 2,056 2,803 21,002 2008 21,461 521 1,196 2,070 2,891 28,139 2009 29,640 575 1,220 2,223 2,898 36,556 2010 33,784 780 1,275 2,246 2,930 41,014 2011 38,912 1,263 1,313 2,250 2,961 46,698 2012 50,548 2,731 1,399 2,384 3,056 60,117 Independent Power Producers, Non-Combined Heat and Power Plants 

### Table 4.2.B. Existing Net Summer Capacity of Other Renewable Sources by Producer Type, 2002 through 2012 (Megawatts) (Page 1)

Total (All Sectors)

Electric Utilities

Notes: Wood and wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Biomass includes municipal solid waste, landfill gas, sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). * = Value is less than half of the smallest unit of measure. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.'Year Wind Solar Thermal and PhotovoltaicWood and WoodDerived Fuels Geothermal Other Biomass Total (Other Renewable

Sources)

2002

-- -- 144

-- 411 555 2003

-- -- 204

-- 461 665 2004

-- -- 179

-- 375 555 2005

-- -- 218

-- 395 614 2006

-- -- 212

-- 416 628 2007

-- -- 210

-- 446 656 2008

-- -- 223

-- 478 701 2009

-- -- 237

-- 503 740 2010

-- -- 393

-- 453 846 2011

-- -- 356

-- 437 793 2012

-- -- 490 46 446 981

2002

-- -- 6

-- 351 357 2003

-- -- 7

-- 364 371 2004

-- -- 7

-- 397 404 2005

-- -- 7

-- 428 435 2006

-- -- 7

-- 426 433 2007

-- -- 8

-- 435 443 2008

-- -- 8

-- 436 444 2009 1 * 8

-- 471 480 2010 11 6 8

-- 496 520 2011 25 54 8

-- 608 694 2012 30 100 8

-- 640 777

2002

-- -- 4,285

-- 134 4,419 2003

-- -- 4,271

-- 136 4,406 2004

-- -- 4,545

-- 183 4,728 2005

-- -- 4,545

-- 202 4,747 2006

-- -- 4,688

-- 208 4,896 2007

-- 1 5,002

-- 160 5,163 2008

-- 1 5,010

-- 105 5,116 2009

-- 1 5,043

-- 118 5,162 2010 2 1 4,948

-- 165 5,116 2011 4 4 5,041

-- 175 5,225 2012 9 7 5,247

-- 193 5,457 Commercial Sector

Industrial Sector

Notes: Wood and wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Biomass includes municipal solid waste, landfill gas, sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). * = Value is less than half of the smallest unit of measure. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.' 

### Table 4.2.B. Existing Net Summer Capacity of Other Renewable Sources by Producer Type, 2002 through 2012 (Megawatts) (Page 2)

Independent Power Producers, Combined Heat and Power PlantsEnergy Source Number of Generators Generator Nameplate

Capacity Net Summer Capacity Net Winter Capacity Coal 1,309 336,341 309,680 312,293 Petroleum 3,702 53,789 47,167 51,239 Natural Gas 5,726 485,957 422,364 455,214 Other Gases 94 2,253 1,946 1,933 Nuclear 104 107,938 101,885 104,182 Hydroelectric Conventional 4,023 78,241 78,738 78,215 Wind 947 59,629 59,075 59,082 Solar Thermal and Photovoltaic 553 3,215 3,170 3,053 Wood and Wood-Derived Fuels 351 8,520 7,508 7,570 Geothermal 197 3,724 2,592 2,782 Other Biomass 1,766 5,527 4,811 4,885 Hydroelectric Pumped Storage 156 20,858 22,368 22,271 Other Energy Sources 95 2,005 1,729 1,739 Total 19,023 1,167,995 1,063,033 1,104,459 

### Table 4.3. Existing Capacity by Energy Source, 2012 (Megawatts)

Notes: Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011, coal-derived synthesis gas was included in Other Gases. Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. Other Gases includes blast furnace gas. Prior to 2011, waste heat was included in Natural Gas. Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Wood and wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Biomass include municipal solid waste, landfill gas, sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Other Energy Sources include batteries, hydrogen, purchased steam, sulfur, tire-derived fuels and other miscellaneous energy
sources. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.'Producer Type Number of Generators Generator Nameplate

Capacity Net Summer Capacity Net Winter Capacity

Electric Utilities 9,624 680,592 621,785 644,358 Independent Power Producers, Non-Combined Heat and Power Plants 6,148 412,045 374,964 389,349 Independent Power Producers, Combined Heat and Power Plants 609 39,916 35,266 38,023 Total 16,381 1,132,554 1,032,015 1,071,729

Commercial Sector 962 3,610 3,223 3,349 Industrial Sector 1,680 31,832 27,795 29,381 Total 2,642 35,442 31,018 32,730

Total 19,023 1,167,995 1,063,033 1,104,459 

### Table 4.4. Existing Capacity by Producer Type, 2012 (Megawatts)

Electric Power Sector

Commercial and Industrial Sectors

All Sectors

Notes: In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. See Glossary reference for definitions. Totals may not equal sum of components because of independent rounding. In the case of some wind, solar and wave energy sites, the capacity for multiple generators is reported in a single generator record and is presented as a single generator in the generator count. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.'Energy Source Number of Generators Net Summer Capacity Number of Generators Net Summer Capacity Number of Generators Net Summer Capacity

U.S. Total 513 15,144 179 12,604 334 2,540 Coal 4 1,482 28 4,465 -24 -2,983 Petroleum 21 45 41 1,401 -20 -1,356 Natural Gas 87 6,818 55 2,950 32 3,868 Other Gases

-- -- 1 4 -1 -4 Nuclear

-- -- 4 3,576 -4 -3,576 Hydroelectric Conventional 17 385 36 185 -19 201 Wind 25 2,225

-- -- 25 2,225 Solar Thermal and Photovoltaic 277 3,460 1 1 276 3,459 Wood and Wood-Derived Fuels 10 489

-- -- 10 489 Geothermal 5 50 1 11 4 39 Other Biomass 65 132 12 12 53 119 Hydroelectric Pumped Storage

-- -- -- -- -- -- Other Energy Sources 2 60

-- -- 2 60

U.S. Total 179 13,321 77 7,515 102 5,806 Coal 4 655 45 5,593 -41 -4,938 Petroleum

-- -- 9 725 -9 -725 Natural Gas 54 6,871 13 444 41 6,427 Other Gases

-- -- 4 40 -4 -40 Nuclear

-- -- 1 604 -1 -604 Hydroelectric Conventional 10 318 5 109 5 209 Wind 28 2,509

-- -- 28 2,509 Solar Thermal and Photovoltaic 44 2,678

-- -- 44 2,678 Wood and Wood-Derived Fuels 3 85

-- -- 3 85 Geothermal 2 48

-- -- 2 48 Other Biomass 30 131

-- -- 30 131 Hydroelectric Pumped Storage

-- -- -- -- -- -- Other Energy Sources 4 27

-- -- 4 27

U.S. Total 97 13,319 153 15,328 -56 -2,009 Coal

-- -- 79 11,993 -79 -11,993 Petroleum

-- -- 21 808 -21 -808 Natural Gas 59 9,044 49 2,377 10 6,667 Other Gases

-- -- -- -- -- -- Nuclear 1 1,122

-- -- 1 1,122 Hydroelectric Conventional 8 252 4 150 4 103 Wind 10 1,041

-- -- 10 1,041 Solar Thermal and Photovoltaic 11 1,677

-- -- 11 1,677 Wood and Wood-Derived Fuels

-- -- -- -- -- -- Geothermal 2 62

-- -- 2 62 Other Biomass 6 121

-- -- 6 121 Hydroelectric Pumped Storage

-- -- -- -- -- -- Other Energy Sources

-- -- -- -- -- -- 

### Table 4.5. Planned Generating Capacity Changes, by Energy Source, 2013-2017 (Page 1)

Generator Additions Generator Retirements Net Capacity Additions

2013

2014

2015

Notes: These data reflect plans as of December 31, 2012 Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011, coal-derived synthesis gas was included in Other Gases. Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. Other Gases also includes blast furnace gas. Prior to 2011, waste heat was included in Natural Gas. Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Wood and wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Biomass include municipal solid waste, landfill gas, sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Other Energy Sources include batteries, hydrogen, purchased steam, sulfur, tire-derived fuels and other miscellaneous energy sources. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. In the case of wind, solar and wave energy sites, the capacity for multiple generators is reported in a single generator record and is presented as a single generator in the generator count. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.'Energy Source Number of Generators Net Summer Capacity Number of Generators Net Summer Capacity Number of Generators Net Summer Capacity

U.S. Total 49 11,658 61 4,054 -12 7,604 Coal 3 757 24 3,178 -21 -2,421 Petroleum 2 3 19 217 -17 -214 Natural Gas 26 7,568 17 556 9 7,012 Other Gases 1 3

-- -- 1 3 Nuclear 1 1,100

-- -- 1 1,100 Hydroelectric Conventional 4 190 1 104 3 86 Wind 1 99

-- -- 1 99 Solar Thermal and Photovoltaic 10 1,937

-- -- 10 1,937 Wood and Wood-Derived Fuels

-- -- -- -- -- -- Geothermal

-- -- -- -- -- -- Other Biomass 1 2

-- -- 1 2 Hydroelectric Pumped Storage

-- -- -- -- -- -- Other Energy Sources

-- -- -- -- -- --

U.S. Total 23 6,452 37 3,579 -14 2,873 Coal

-- -- 15 2,066 -15 -2,066 Petroleum

-- -- -- -- -- -- Natural Gas 16 3,718 19 1,304 -3 2,414 Other Gases

-- -- -- -- -- -- Nuclear 2 2,200

-- -- 2 2,200 Hydroelectric Conventional 2 244 2 208

-- 36 Wind

-- -- -- -- -- -- Solar Thermal and Photovoltaic 1 200

-- -- 1 200 Wood and Wood-Derived Fuels

-- -- -- -- -- -- Geothermal 2 90

-- -- 2 90 Other Biomass

-- -- 1 1 -1 -1 Hydroelectric Pumped Storage

-- -- -- -- -- -- Other Energy Sources

-- -- -- -- -- --

U.S. Total 861 59,894 507 43,080 354 16,815 Coal 11 2,894 191 27,294 -180 -24,401 Petroleum 23 48 90 3,151 -67 -3,103 Natural Gas 242 34,019 153 7,631 89 26,389 Other Gases 1 3 5 44 -4 -41 Nuclear 4 4,422 5 4,180 -1 242 Hydroelectric Conventional 41 1,389 48 755 -7 634 Wind 64 5,874

-- -- 64 5,874 Solar Thermal and Photovoltaic 343 9,953 1 1 342 9,952 Wood and Wood-Derived Fuels 13 574

-- -- 13 574 Geothermal 11 249 1 11 10 238 Other Biomass 102 385 13 13 89 371 Hydroelectric Pumped Storage

-- -- -- -- -- -- Other Energy Sources 6 87

-- -- 6 87 

### Table 4.5. Planned Generating Capacity Changes, by Energy Source, 2013-2017 (Page 2)

Notes: These data reflect plans as of December 31, 2012 Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011, coal-derived synthesis gas was included in Other Gases. Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. Other Gases also includes blast furnace gas. Prior to 2011, waste heat was included in Natural Gas. Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Wood and wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Biomass include municipal solid waste, landfill gas, sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Other Energy Sources include batteries, hydrogen, purchased steam, sulfur, tire-derived fuels and other miscellaneous energy sources. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. In the case of wind, solar and wave energy sites, the capacity for multiple generators is reported in a single generator record and is presented as a single generator in the generator count. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.' Generator Additions Generator Retirements Net Capacity Additions

2016

2017

2013-2017Energy Source Number of Generators Generator Nameplate

CapacityNet Summer CapacityNet Winter CapacityNumber of Generators Generator Nameplate

CapacityNet Summer CapacityNet Winter Capacity Coal 5 3,953 3,663 3,677 86 11,273 10,308 10,420 Petroleum 40 580 508 365 96 2,417 2,121 2,168 Natural Gas 111 10,128 9,210 9,721 80 3,001 2,267 2,431 Other Gases 1 * * * 4 120 152 152 Nuclear

-- -- -- -- -- -- -- -- Hydroelectric Conventional 15 345 344 342 28 317 315 314 Wind 149 12,953 12,885 12,885 1 13 12 12 Solar Thermal and Photovoltaic 210 1,616 1,595 1,585

-- -- -- -- Wood and Wood-Derived Fuels 5 186 162 155 3 36 32 33 Geothermal 12 192 146 172 1 1 1 1 Other Biomass 103 202 188 189 25 49 43 43 Hydroelectric Pumped Storage 2 42 42 42

-- -- -- -- Other Energy Sources 6 62 59 59

-- -- -- -- Total 659 30,257 28,801 29,192 324 17,226 15,251 15,575

Energy Source Generator Nameplate

CapacityNet Summer CapacityNet Winter Capacity Coal -96 -1,315 -1,149 Petroleum -2,215 -2,701 -2,427 Natural Gas 1,443 230 -532 Other Gases 170 163 167 Nuclear 936 466 675 Hydroelectric Conventional 19 57 81 Wind 707 526 521 Solar Thermal and Photovoltaic 35 52 58 Wood and Wood-Derived Fuels 356 302 298 Geothermal 34 38 15 Other Biomass 181 130 138 Hydroelectric Pumped Storage

-- 34 -39 Other Energy Sources 246 251 257 Total 1,816 -1,768 -1,938

Notes: Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011, coal-derived synthesis gas was included in Other Gases. Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. Other Gases also includes blast furnace gas and other manufactured and waste gases derived from fossil fuels. Prior to 2011, waste heat was included in Natural Gas. Hydroelectric Conventional capacity includes conventional hydroelectric power excluding pumped storage facilities. Wood and wood-derived fuels include wood/wood waste solids (including paper pellets, railroad ties, utility poles, wood chips, bark, and wood waste solids), wood waste liquids (red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids), and black liquor. Other Biomass include municipal solid waste, landfill gas, sludge waste, agricultural byproducts, other biomass solids, other biomass liquids, and other biomass gases (including digester gases, methane, and other biomass gases). Other Energy Sources include batteries, hydrogen, purchased steam, sulfur, tire-derived fuels and other miscellaneous energy sources. Capacity by energy source is based on the capacity associated with the energy source reported as the most predominant (primary) one, where more than one energy source is associated with a generator. In the case of some wind, solar and wave energy sites, the capacity for multiple generators is reported in a single generator record and is presented as a single generator in the generator count. Other Changes to Existing Capacity reflect uprates, derates, repowerings, and changes to previously reported generator capacity.
Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.' 

### Table 4.6. Capacity Additions, Retirements and Changes by Energy Source, 2012 (Count, Megawatts)

Generator Additions Generator Retirements

Other Changes to Existing CapacityCensus Division and State

Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 4,157.7 3,805.224,619.1 24,153.6 1,753.4 1,709.4 3.0 3.0 4,630.3 4,653.7 48.0 26.035,211.534,350.9 Connecticut 294.7 299.9 6,607.7 6,674.5 29.4 29.4 0.0 0.0 2,102.5 2,102.5 26.0 26.0 9,060.3 9,132.3 Maine 1,704.5 1,640.8 2,764.9 2,737.4 0.0 0.0 0.0 0.0 0.0 0.0 22.0 0.0 4,491.4 4,378.2 Massachusetts 761.5 710.911,155.210,637.8 1,724.0 1,680.0 3.0 3.0 677.3 684.7 0.0 0.014,321.013,716.4 New Hampshire 838.4 675.2 2,238.7 2,252.3 0.0 0.0 0.0 0.0 1,246.2 1,246.2 0.0 0.0 4,323.3 4,173.7 Rhode Island 27.9 27.9 1,752.8 1,751.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1,780.7 1,778.9 Vermont 530.7 450.5 99.8 100.6 0.0 0.0 0.0 0.0 604.3 620.3 0.0 0.0 1,234.8 1,171.4 Middle Atlantic 9,621.4 8,679.971,813.372,805.6 3,321.0 3,321.0 28.0 28.019,055.418,973.7 11.2 11.2103,850.3103,819.4 New Jersey 464.5 375.213,933.913,474.8 400.0 400.0 0.0 0.0 4,114.5 4,112.7 11.2 11.218,924.1 18,373.9 New York 6,436.4 6,198.926,392.226,782.9 1,400.0 1,400.0 28.0 28.0 5,263.3 5,219.0 0.0 0.039,519.939,628.8 Pennsylvania 2,720.5 2,105.831,487.232,547.9 1,521.0 1,521.0 0.0 0.0 9,677.6 9,642.0 0.0 0.045,406.345,816.7 East North Central 8,761.8 7,139.5123,094.3124,168.6 1,871.0 1,872.0 0.0 0.019,359.2 19,327.4 114.1 209.1153,200.4152,716.6 Illinois 3,715.1 2,904.829,884.729,439.0 0.0 0.0 0.0 0.011,541.011,486.0 5.0 0.045,145.843,829.8 Indiana 1,661.7 1,452.725,087.625,863.3 0.0 0.0 0.0 0.0 0.0 0.0 88.0 88.026,837.327,404.0 Michigan 1,571.1 1,058.922,953.523,013.6 1,871.0 1,872.0 0.0 0.0 3,936.2 3,957.4 0.0 0.030,331.829,901.9 Ohio 738.0 404.329,982.330,641.8 0.0 0.0 0.0 0.0 2,134.0 2,134.0 0.0 100.032,854.333,280.1 Wisconsin 1,075.9 1,318.815,186.215,210.9 0.0 0.0 0.0 0.0 1,748.0 1,750.0 21.1 21.1 18,031.2 18,300.8 West North Central 17,735.714,763.1 62,162.062,126.7 657.0 667.0 0.0 0.0 5,805.0 5,804.9 23.7 23.786,383.483,385.4 Iowa 5,167.4 4,362.010,249.810,324.2 0.0 0.0 0.0 0.0 601.4 601.4 0.0 0.016,018.615,287.6 Kansas 2,733.2 1,281.510,185.1 10,301.3 0.0 0.0 0.0 0.0 1,175.0 1,175.0 0.0 0.014,093.312,757.8 Minnesota 3,389.9 3,146.810,444.810,402.6 0.0 0.0 0.0 0.0 1,594.0 1,594.0 18.4 18.415,447.1 15,161.8 Missouri 1,038.1 1,036.519,118.619,167.7 657.0 667.0 0.0 0.0 1,190.0 1,190.0 0.0 0.022,003.722,061.2 Nebraska 741.6 621.6 6,286.9 6,307.7 0.0 0.0 0.0 0.0 1,244.6 1,244.5 0.0 0.0 8,273.1 8,173.8 North Dakota 2,277.0 1,940.7 4,208.1 4,237.7 0.0 0.0 0.0 0.0 0.0 0.0 5.3 5.3 6,490.4 6,183.7 South Dakota 2,388.5 2,374.0 1,668.7 1,385.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4,057.2 3,759.5 South Atlantic 11,516.011,206.5162,937.3163,819.7 7,905.2 7,904.5 32.0 32.025,020.024,685.0 406.0 402.0207,816.5208,049.7 Delaware 34.3 22.5 3,322.2 3,336.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3,356.5 3,359.3 District of Columbia 0.0 0.0 10.0 800.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 10.0 800.0 Florida 1,156.4 1,143.553,455.854,207.2 0.0 0.0 0.0 0.0 4,175.0 3,924.0 352.0 352.059,139.259,626.7 Georgia 2,699.9 2,689.929,865.028,501.8 1,862.2 1,861.5 0.0 0.0 4,061.0 4,061.0 0.0 0.038,488.1 37,114.2 Maryland 880.9 853.9 9,618.410,023.7 0.0 0.0 0.0 0.0 1,716.0 1,705.0 0.0 0.012,215.312,582.6 North Carolina 2,614.2 2,531.822,638.520,820.8 86.0 86.0 0.0 0.0 4,998.0 4,970.0 54.0 50.030,390.728,458.6 South Carolina 1,725.1 1,625.512,133.713,253.5 2,716.0 2,716.0 0.0 0.0 6,508.0 6,486.0 0.0 0.023,082.824,081.0 Virginia 1,533.0 1,524.216,512.616,380.7 3,241.0 3,241.0 0.0 0.0 3,562.0 3,539.0 0.0 0.024,848.624,684.9 West Virginia 872.2 815.215,381.1 16,495.2 0.0 0.0 32.0 32.0 0.0 0.0 0.0 0.016,285.317,342.4 East South Central 7,936.7 7,824.671,173.371,286.1 1,616.3 1,616.3 0.0 0.0 9,634.1 9,634.1 1.4 1.490,361.890,362.5 Alabama 3,948.9 3,861.823,555.1 23,671.6 0.0 0.0 0.0 0.0 5,043.4 5,043.4 0.0 0.032,547.432,576.8 Kentucky 896.7 890.720,192.1 20,223.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.021,088.821,113.9 Mississippi 236.7 235.1 13,975.514,116.9 0.0 0.0 0.0 0.0 1,190.0 1,190.0 1.4 1.415,403.615,543.4 Tennessee 2,854.4 2,837.013,450.613,274.4 1,616.3 1,616.3 0.0 0.0 3,400.7 3,400.7 0.0 0.021,322.021,128.4 West South Central 19,687.016,361.5145,586.8147,155.1 288.0 288.0 37.0 1.0 8,922.0 8,916.0 435.9 435.3174,956.7173,156.9 Arkansas 1,666.5 1,666.512,832.812,439.1 28.0 28.0 0.0 0.0 1,828.0 1,823.0 0.0 0.016,355.315,956.6 Louisiana 571.5 516.522,634.823,341.2 0.0 0.0 0.0 0.0 2,134.0 2,133.0 207.6 207.625,547.926,198.3 Oklahoma 4,064.5 2,742.419,160.618,821.1 260.0 260.0 0.0 0.0 0.0 0.0 0.0 0.023,485.1 21,823.5 Texas 13,384.511,436.1 90,958.692,553.7 0.0 0.0 37.0 1.0 4,960.0 4,960.0 228.3 227.7109,568.4109,178.5 Mountain 19,102.216,916.1 64,689.665,700.9 778.8 778.8 1.8 0.0 3,937.0 3,937.0 111.4 111.488,620.887,444.2 Arizona 3,628.9 3,023.919,804.319,865.3 216.3 216.3 0.0 0.0 3,937.0 3,937.0 0.0 0.027,586.527,042.5 Colorado 3,055.1 2,553.311,319.911,057.0 562.5 562.5 0.0 0.0 0.0 0.0 9.3 9.314,946.814,182.1 Idaho 3,762.9 3,405.7 1,133.1 834.4 0.0 0.0 0.0 0.0 0.0 0.0 14.8 14.8 4,910.8 4,254.9 Montana 3,359.4 3,102.8 2,913.7 2,873.2 0.0 0.0 0.0 0.0 0.0 0.0 44.0 44.0 6,317.1 6,020.0 Nevada 1,916.0 1,506.6 8,559.710,139.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.010,475.711,646.3 New Mexico 1,027.4 969.0 7,344.0 7,285.1 0.0 0.0 1.8 0.0 0.0 0.0 0.0 0.0 8,373.2 8,254.1 Utah 638.1 635.3 6,960.7 6,945.9 0.0 0.0 0.0 0.0 0.0 0.0 31.8 31.8 7,630.6 7,613.0 Wyoming 1,714.4 1,719.5 6,654.2 6,700.3 0.0 0.0 0.0 0.0 0.0 0.0 11.5 11.5 8,380.1 8,431.3 Pacific Contiguous 56,418.452,383.551,279.1 51,222.4 4,177.6 4,135.6 0.0 0.0 5,522.0 5,487.0 385.8 108.5117,782.9113,337.0 California 20,165.1 17,572.242,534.242,412.5 3,863.6 3,821.6 0.0 0.0 4,390.0 4,390.0 375.8 99.1 71,328.768,295.4 Oregon 11,949.010,907.4 3,595.2 3,627.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.015,544.2 14,534.6 Washington 24,304.323,903.9 5,149.7 5,182.7 314.0 314.0 0.0 0.0 1,132.0 1,097.0 10.0 9.430,910.030,507.0 Pacific Noncontiguous 956.3 792.7 3,802.8 3,808.7 0.0 0.0 63.0 27.0 0.0 0.0 26.6 0.0 4,848.7 4,628.4 Alaska 453.9 422.6 1,637.6 1,616.9 0.0 0.0 27.0 27.0 0.0 0.0 0.0 0.0 2,118.5 2,066.5 Hawaii 502.4 370.1 2,165.2 2,191.8 0.0 0.0 36.0 0.0 0.0 0.0 26.6 0.0 2,730.2 2,561.9 U.S. Total 155,893.2139,872.6781,157.6786,247.422,368.322,292.6 164.8 91.0101,885.0101,418.8 1,564.1 1,328.61,063,033.01,051,251.0

Values are final.

NOTES: Capacity from facilities with a total generator nameplate capacity less than 1 MW are excluded from this report. This exclusion may represent a signifciant portion of capacity for some technologies such as solar photovoltaic generation. Concentrated Solar Power Energy Storage is included in 'Renewable sources'; it is not included in 'Other Energy Storage'
Sources: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report' and Form EIA-860M, 'Monthly Update to the Annual Electric Generator Report.' 

### Table 4.7.A. Net Summer Capacity of Utility Scale Units by Technology and by State, 2012 and 2011 (Megawatts) Renewable

Sources Fossil Fuels Hydroelectric Pumped Storage Other Energy Storage Nuclear All Other Sources All SourcesCensus Division and State

Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 784.1 422.8 49.2 13.9 0.0 0.0 1,956.9 1,946.9 1,367.5 1,421.6 0.0 0.0 4,157.7 3,805.2 Connecticut 0.0 0.0 0.0 0.0 0.0 0.0 122.2 121.7 172.5 178.2 0.0 0.0 294.7 299.9 Maine 427.6 322.5 0.0 0.0 0.0 0.0 742.3 742.3 534.6 576.0 0.0 0.0 1,704.5 1,640.8 Massachusetts 63.8 29.6 41.2 11.7 0.0 0.0 261.1 262.7 395.4 406.9 0.0 0.0 761.5 710.9 New Hampshire 171.0 24.0 0.0 0.0 0.0 0.0 505.0 493.3 162.4 157.9 0.0 0.0 838.4 675.2 Rhode Island 1.5 1.5 0.0 0.0 0.0 0.0 2.7 2.7 23.7 23.7 0.0 0.0 27.9 27.9 Vermont 120.2 45.2 8.0 2.2 0.0 0.0 323.6 324.2 78.9 78.9 0.0 0.0 530.7 450.5 Middle Atlantic 2,987.8 2,195.7 304.6 203.0 0.0 0.0 5,076.7 5,084.5 1,252.3 1,196.7 0.0 0.0 9,621.4 8,679.9 New Jersey 7.5 7.5 236.1 152.7 0.0 0.0 3.3 5.4 217.6 209.6 0.0 0.0 464.5 375.2 New York 1,636.4 1,398.9 31.5 31.5 0.0 0.0 4,311.9 4,319.1 456.6 449.4 0.0 0.0 6,436.4 6,198.9 Pennsylvania 1,343.9 789.3 37.0 18.8 0.0 0.0 761.5 760.0 578.1 537.7 0.0 0.0 2,720.5 2,105.8 East North Central 6,765.9 5,222.8 60.8 31.4 0.0 0.0 817.0 820.6 1,118.1 1,064.7 0.0 0.0 8,761.8 7,139.5 Illinois 3,520.1 2,737.3 29.0 9.0 0.0 0.0 34.1 34.1 131.9 124.4 0.0 0.0 3,715.1 2,904.8 Indiana 1,539.7 1,339.7 3.5 0.0 0.0 0.0 59.5 59.5 59.0 53.5 0.0 0.0 1,661.7 1,452.7 Michigan 874.8 374.6 0.0 0.0 0.0 0.0 237.0 237.8 459.3 446.5 0.0 0.0 1,571.1 1,058.9 Ohio 461.7 159.7 28.3 22.4 0.0 0.0 101.6 101.5 146.4 120.7 0.0 0.0 738.0 404.3 Wisconsin 369.6 611.5 0.0 0.0 0.0 0.0 384.8 387.7 321.5 319.6 0.0 0.0 1,075.9 1,318.8 West North Central 14,030.011,045.2 0.0 0.0 0.0 0.0 3,282.1 3,294.1 423.6 423.8 0.0 0.017,735.714,763.1 Iowa 5,005.0 4,203.2 0.0 0.0 0.0 0.0 147.8 144.2 14.6 14.6 0.0 0.0 5,167.4 4,362.0 Kansas 2,719.1 1,271.8 0.0 0.0 0.0 0.0 7.0 2.6 7.1 7.1 0.0 0.0 2,733.2 1,281.5 Minnesota 2,842.3 2,576.3 0.0 0.0 0.0 0.0 175.7 196.8 371.9 373.7 0.0 0.0 3,389.9 3,146.8 Missouri 458.5 458.5 0.0 0.0 0.0 0.0 570.3 570.3 9.3 7.7 0.0 0.0 1,038.1 1,036.5 Nebraska 455.4 332.5 0.0 0.0 0.0 0.0 275.3 278.2 10.9 10.9 0.0 0.0 741.6 621.6 North Dakota 1,759.2 1,422.9 0.0 0.0 0.0 0.0 508.0 508.0 9.8 9.8 0.0 0.0 2,277.0 1,940.7 South Dakota 790.5 780.0 0.0 0.0 0.0 0.0 1,598.0 1,594.0 0.0 0.0 0.0 0.0 2,388.5 2,374.0 South Atlantic 705.3 650.1 234.9 126.2 0.0 0.0 7,145.5 7,145.8 3,430.3 3,284.4 0.0 0.011,516.011,206.5 Delaware 2.0 2.0 24.3 12.5 0.0 0.0 0.0 0.0 8.0 8.0 0.0 0.0 34.3 22.5 District of Columbia 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Florida 0.0 0.0 65.2 64.6 0.0 0.0 54.5 54.5 1,036.7 1,024.4 0.0 0.0 1,156.4 1,143.5 Georgia 0.0 0.0 3.2 0.0 0.0 0.0 2,047.9 2,048.7 648.8 641.2 0.0 0.0 2,699.9 2,689.9 Maryland 120.0 120.0 27.6 4.4 0.0 0.0 590.0 590.0 143.3 139.5 0.0 0.0 880.9 853.9 North Carolina 0.0 0.0 114.6 44.7 0.0 0.0 1,964.2 1,964.3 535.4 522.8 0.0 0.0 2,614.2 2,531.8 South Carolina 0.0 0.0 0.0 0.0 0.0 0.0 1,336.0 1,337.2 389.1 288.3 0.0 0.0 1,725.1 1,625.5 Virginia 0.0 0.0 0.0 0.0 0.0 0.0 866.2 866.2 666.8 658.0 0.0 0.0 1,533.0 1,524.2 West Virginia 583.3 528.1 0.0 0.0 0.0 0.0 286.7 284.9 2.2 2.2 0.0 0.0 872.2 815.2 East South Central 29.1 29.1 12.8 0.0 0.0 0.0 6,715.9 6,709.9 1,178.9 1,085.6 0.0 0.0 7,936.7 7,824.6 Alabama 0.0 0.0 0.0 0.0 0.0 0.0 3,272.2 3,272.2 676.7 589.6 0.0 0.0 3,948.9 3,861.8 Kentucky 0.0 0.0 0.0 0.0 0.0 0.0 827.6 821.6 69.1 69.1 0.0 0.0 896.7 890.7 Mississippi 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 236.7 235.1 0.0 0.0 236.7 235.1 Tennessee 29.1 29.1 12.8 0.0 0.0 0.0 2,616.1 2,616.1 196.4 191.8 0.0 0.0 2,854.4 2,837.0 West South Central 15,311.812,172.1 75.2 43.5 0.0 0.0 3,080.2 3,080.2 1,219.8 1,065.7 0.0 0.019,687.016,361.5 Arkansas 0.0 0.0 0.0 0.0 0.0 0.0 1,340.7 1,340.7 325.8 325.8 0.0 0.0 1,666.5 1,666.5 Louisiana 0.0 0.0 0.0 0.0 0.0 0.0 192.0 192.0 379.5 324.5 0.0 0.0 571.5 516.5 Oklahoma 3,132.9 1,810.8 0.0 0.0 0.0 0.0 858.2 858.2 73.4 73.4 0.0 0.0 4,064.5 2,742.4 Texas 12,178.910,361.3 75.2 43.5 0.0 0.0 689.3 689.3 441.1 342.0 0.0 0.013,384.511,436.1 Mountain 6,758.1 5,407.5 1,167.8 417.2 69.5 65.010,507.810,507.5 159.9 144.2 439.1 374.719,102.2 16,916.1 Arizona 237.3 138.1 631.7 129.1 1.0 1.0 2,720.4 2,720.4 38.5 35.3 0.0 0.0 3,628.9 3,023.9 Colorado 2,271.1 1,792.9 115.4 85.6 0.0 0.0 655.6 661.8 13.0 13.0 0.0 0.0 3,055.1 2,553.3 Idaho 962.7 611.3 0.0 0.0 0.0 0.0 2,703.4 2,703.9 86.8 80.5 10.0 10.0 3,762.9 3,405.7 Montana 627.8 378.2 0.0 0.0 0.0 0.0 2,731.6 2,724.6 0.0 0.0 0.0 0.0 3,359.4 3,102.8 Nevada 150.0 0.0 258.8 73.0 68.5 64.0 1,051.4 1,051.4 3.2 0.0 384.1 318.2 1,916.0 1,506.6 New Mexico 777.5 750.2 160.6 129.5 0.0 0.0 82.9 82.9 6.4 6.4 0.0 0.0 1,027.4 969.0 Utah 324.4 324.4 1.3 0.0 0.0 0.0 255.4 255.4 12.0 9.0 45.0 46.5 638.1 635.3 Wyoming 1,407.3 1,412.4 0.0 0.0 0.0 0.0 307.1 307.1 0.0 0.0 0.0 0.0 1,714.4 1,719.5 Pacific Contiguous 11,464.4 8,431.6 781.6 214.6 406.5 406.539,715.339,623.2 1,940.6 1,704.1 2,110.0 2,003.556,418.452,383.5 California 5,506.3 3,770.1 770.4 211.5 406.5 406.510,145.710,136.1 1,243.9 1,044.5 2,092.3 2,003.520,165.1 17,572.2 Oregon 3,151.9 2,208.0 10.7 2.6 0.0 0.0 8,454.7 8,419.8 314.0 277.0 17.7 0.011,949.010,907.4 Washington 2,806.2 2,453.5 0.5 0.5 0.0 0.021,114.921,067.3 382.7 382.6 0.0 0.024,304.323,903.9 Pacific Noncontiguous 238.3 99.0 7.2 2.2 0.0 0.0 440.6 438.9 227.2 221.6 43.0 31.0 956.3 792.7 Alaska 32.7 7.4 0.0 0.0 0.0 0.0 415.6 415.2 5.6 0.0 0.0 0.0 453.9 422.6 Hawaii 205.6 91.6 7.2 2.2 0.0 0.0 25.0 23.7 221.6 221.6 43.0 31.0 502.4 370.1 U.S. Total 59,074.845,675.9 2,694.1 1,052.0 476.0 471.578,738.078,651.612,318.2 11,612.4 2,592.1 2,409.2155,893.2139,872.6

Values are final.

NOTES: Capacity from facilities with a total generator nameplate capacity less than 1 MW are excluded from this report. This exclusion may represent a signifciant portion of existing or planned capacity for some technologies such as solar photovoltaic generation.
Sources: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report' and Form EIA-860M, 'Monthly Update to the Annual Electric Generator Report.' 

### Table 4.7.B. Net Summer Capacity of Utility Scale Units Using Primarily Renewable Energy Sources and by State, 2012 and 2011 (Megawatts)

Wind Solar Photovoltaic Solar Thermal Conventional Hydroelectric Biomass Sources Geothermal Total Renewable SourcesCensus Division and State

Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 12,190.511,593.8 1,090.0 1,058.9 876.4 830.1 2,546.1 2,755.5 0.0 0.0 7,916.1 7,915.3 0.0 0.024,619.1 24,153.6 Connecticut 2,513.4 2,447.7 458.1 432.7 61.0 44.7 389.1 564.4 0.0 0.0 3,186.1 3,185.0 0.0 0.0 6,607.7 6,674.5 Maine 1,250.0 1,250.0 306.0 302.2 119.0 93.0 85.0 85.0 0.0 0.0 1,004.9 1,007.2 0.0 0.0 2,764.9 2,737.4 Massachusetts 5,498.9 4,967.9 322.1 320.2 686.0 683.0 1,538.1 1,559.8 0.0 0.0 3,110.1 3,106.9 0.0 0.011,155.210,637.8 New Hampshire 1,203.0 1,203.0 3.8 3.8 0.0 0.0 533.9 546.3 0.0 0.0 498.0 499.2 0.0 0.0 2,238.7 2,252.3 Rhode Island 1,725.2 1,725.2 0.0 0.0 10.4 9.4 0.0 0.0 0.0 0.0 17.2 16.4 0.0 0.0 1,752.8 1,751.0 Vermont 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 99.8 100.6 0.0 0.0 99.8 100.6 Middle Atlantic 22,470.622,596.3 8,708.5 8,288.0 9,616.3 8,072.221,966.222,881.6 11.6 0.0 8,939.710,867.1 100.4 100.471,813.372,805.6 New Jersey 5,871.3 5,869.4 4,099.2 3,593.2 642.9 630.4 2,006.6 2,000.9 11.6 0.0 1,302.3 1,380.9 0.0 0.013,933.913,474.8 New York 8,338.6 8,352.1 3,011.4 3,093.4 7,194.6 7,363.0 2,703.7 2,813.1 0.0 0.0 5,143.9 5,161.3 0.0 0.026,392.226,782.9 Pennsylvania 8,260.7 8,374.8 1,597.9 1,601.4 1,778.8 78.817,255.918,067.6 0.0 0.0 2,493.5 4,324.9 100.4 100.431,487.232,547.9 East North Central 16,834.915,615.625,669.025,680.3 3,419.7 3,282.772,502.674,808.6 570.1 570.1 3,191.9 3,432.5 906.1 778.8123,094.3124,168.6 Illinois 2,976.6 2,976.010,314.610,354.6 238.7 246.915,574.014,857.2 0.0 0.0 663.1 886.6 117.7 117.729,884.729,439.0 Indiana 2,451.9 2,451.9 3,189.6 3,189.6 4.0 4.018,140.418,949.4 274.0 274.0 456.4 450.4 571.3 544.025,087.625,863.3 Michigan 4,777.0 4,762.3 3,319.3 3,313.9 2,979.3 2,951.411,261.811,346.6 47.2 47.2 568.9 592.2 0.0 0.022,953.523,013.6 Ohio 3,960.3 2,763.0 5,443.1 5,434.9 57.4 46.219,267.521,250.7 142.0 142.0 894.9 887.9 217.1 117.1 29,982.330,641.8 Wisconsin 2,669.1 2,662.4 3,402.4 3,387.3 140.3 34.2 8,258.9 8,404.7 106.9 106.9 608.6 615.4 0.0 0.015,186.215,210.9 West North Central 5,714.1 5,429.211,201.811,206.3 3,257.3 3,135.037,843.838,061.2 32.0 32.0 4,104.6 4,254.6 8.4 8.462,162.062,126.7 Iowa 1,161.5 1,152.6 1,113.9 1,102.6 261.4 87.6 6,683.4 6,934.7 32.0 32.0 997.6 1,014.7 0.0 0.010,249.810,324.2 Kansas 0.0 0.0 2,377.8 2,435.4 2,043.0 2,132.8 5,223.0 5,188.2 0.0 0.0 541.3 544.9 0.0 0.010,185.1 10,301.3 Minnesota 2,107.2 2,073.2 2,558.4 2,569.1 278.7 237.4 4,696.5 4,709.5 0.0 0.0 804.0 813.4 0.0 0.010,444.810,402.6 Missouri 1,834.8 1,842.1 3,397.5 3,415.8 267.4 267.412,457.512,424.7 0.0 0.0 1,161.4 1,217.7 0.0 0.019,118.619,167.7 Nebraska 320.6 361.3 1,111.6 1,025.8 394.2 397.2 4,145.7 4,160.2 0.0 0.0 314.8 363.2 0.0 0.0 6,286.9 6,307.7 North Dakota 0.0 0.0 0.0 9.6 0.0 0.0 4,141.1 4,147.3 0.0 0.0 58.6 72.4 8.4 8.4 4,208.1 4,237.7 South Dakota 290.0 0.0 642.6 648.0 12.6 12.6 496.6 496.6 0.0 0.0 226.9 228.3 0.0 0.0 1,668.7 1,385.5 South Atlantic 43,584.240,397.431,464.531,075.0 3,497.9 3,030.567,099.369,679.1 633.8 633.816,522.618,716.6 135.0 287.3162,937.3163,819.7 Delaware 1,130.0 1,130.0 355.0 301.0 854.8 864.0 742.0 794.0 0.0 0.0 105.4 112.8 135.0 135.0 3,322.2 3,336.8 District of Columbia 0.0 0.0 10.0 10.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 790.0 0.0 0.0 10.0 800.0 Florida 23,942.623,982.2 7,958.9 7,957.2 1,755.5 1,392.1 10,266.010,204.0 550.0 550.0 8,982.810,121.7 0.0 0.053,455.854,207.2 Georgia 7,956.0 6,280.0 7,836.9 7,867.7 115.0 115.012,737.1 12,988.1 83.8 83.8 1,136.2 1,167.2 0.0 0.029,865.028,501.8 Maryland 230.0 230.0 1,488.3 1,482.9 335.5 329.8 4,757.0 4,896.0 0.0 0.0 2,807.6 2,932.7 0.0 152.3 9,618.410,023.7 North Carolina 4,074.6 2,516.6 6,011.7 5,509.7 0.0 0.012,104.812,250.8 0.0 0.0 447.4 543.7 0.0 0.022,638.520,820.8 South Carolina 2,281.7 2,295.7 2,852.2 3,029.5 110.8 3.3 6,225.5 7,257.5 0.0 0.0 663.5 667.5 0.0 0.012,133.713,253.5 Virginia 3,969.3 3,962.9 3,877.6 3,879.0 320.7 320.7 5,976.3 5,848.1 0.0 0.0 2,368.7 2,370.0 0.0 0.016,512.616,380.7 West Virginia 0.0 0.0 1,073.9 1,038.0 5.6 5.614,290.615,440.6 0.0 0.0 11.0 11.0 0.0 0.015,381.1 16,495.2 East South Central 17,725.916,616.1 12,865.813,292.3 2,865.5 3,234.1 37,415.237,852.7 0.0 0.0 197.1 187.1 103.8 103.871,173.371,286.1 Alabama 9,325.7 9,325.7 2,550.6 2,577.8 169.1 169.1 11,367.311,456.6 0.0 0.0 42.6 42.6 99.8 99.823,555.1 23,671.6 Kentucky 0.0 0.0 4,828.9 4,863.8 0.0 0.015,293.315,289.5 0.0 0.0 69.9 69.9 0.0 0.020,192.1 20,223.2 Mississippi 6,997.2 6,750.4 1,716.9 1,736.5 2,696.4 3,065.0 2,526.0 2,526.0 0.0 0.0 35.0 35.0 4.0 4.013,975.514,116.9 Tennessee 1,403.0 540.0 3,769.4 4,114.2 0.0 0.0 8,228.6 8,580.6 0.0 0.0 49.6 39.6 0.0 0.013,450.613,274.4 West South Central 56,430.956,965.211,725.511,430.038,460.040,681.336,984.836,445.9 1,409.8 1,092.6 195.9 200.2 379.9 339.9145,586.8147,155.1 Arkansas 4,660.5 4,875.5 753.1 749.6 2,258.0 2,257.0 5,144.0 4,535.0 0.0 0.0 17.2 22.0 0.0 0.012,832.812,439.1 Louisiana 7,324.2 7,864.6 2,406.2 1,966.1 8,434.2 9,058.3 3,414.0 3,424.0 975.0 947.0 46.9 46.9 34.3 34.322,634.823,341.2 Oklahoma 7,512.5 7,027.4 1,191.9 1,245.0 5,092.5 5,172.9 5,294.4 5,306.5 0.0 0.0 69.3 69.3 0.0 0.019,160.618,821.1 Texas 36,933.737,197.7 7,374.3 7,469.322,675.324,193.1 23,132.423,180.4 434.8 145.6 62.5 62.0 345.6 305.690,958.692,553.7 Mountain 21,136.720,650.4 8,778.6 8,515.4 3,545.8 3,533.630,756.432,528.8 52.0 52.0 325.2 327.4 94.9 93.364,689.665,700.9 Arizona 9,882.4 9,873.2 2,353.6 2,353.6 1,320.8 1,320.8 6,157.0 6,225.0 0.0 0.0 90.5 92.7 0.0 0.019,804.319,865.3 Colorado 2,733.2 2,533.2 2,545.5 2,364.2 381.0 386.0 5,482.3 5,595.7 0.0 0.0 177.9 177.9 0.0 0.011,319.911,057.0 Idaho 567.5 268.8 543.0 543.0 0.0 0.0 17.2 17.2 0.0 0.0 5.4 5.4 0.0 0.0 1,133.1 834.4 Montana 0.0 0.0 362.1 321.6 54.0 54.0 2,442.1 2,442.1 52.0 52.0 2.0 2.0 1.5 1.5 2,913.7 2,873.2 Nevada 5,287.2 5,287.2 1,380.6 1,380.6 587.1 587.1 1,293.4 2,873.4 0.0 0.0 11.4 11.4 0.0 0.0 8,559.710,139.7 New Mexico 1,465.4 1,461.0 947.2 949.2 896.0 880.5 4,031.0 3,990.0 0.0 0.0 4.4 4.4 0.0 0.0 7,344.0 7,285.1 Utah 1,201.0 1,227.0 530.0 486.6 300.9 301.5 4,901.0 4,903.0 0.0 0.0 27.8 27.8 0.0 0.0 6,960.7 6,945.9 Wyoming 0.0 0.0 116.6 116.6 6.0 3.7 6,432.4 6,482.4 0.0 0.0 5.8 5.8 93.4 91.8 6,654.2 6,700.3 Pacific Contiguous 24,264.923,859.9 9,042.1 8,774.215,073.415,510.0 2,275.5 2,336.4 0.0 123.6 412.1 408.2 211.1 210.1 51,279.1 51,222.4 California 18,322.817,852.8 8,207.1 7,939.215,045.815,482.4 350.5 411.4 0.0 123.6 396.9 393.0 211.1 210.1 42,534.242,412.5 Oregon 2,876.4 2,908.4 133.8 133.8 0.0 0.0 585.0 585.0 0.0 0.0 0.0 0.0 0.0 0.0 3,595.2 3,627.2 Washington 3,065.7 3,098.7 701.2 701.2 27.6 27.6 1,340.0 1,340.0 0.0 0.0 15.2 15.2 0.0 0.0 5,149.7 5,182.7 Pacific Noncontiguous 329.4 329.4 510.0 502.6 14.2 5.5 290.5 290.5 0.0 0.0 2,652.7 2,668.5 6.0 12.2 3,802.8 3,808.7 Alaska 329.4 329.4 510.0 502.6 14.2 5.5 110.5 110.5 0.0 0.0 673.5 668.9 0.0 0.0 1,637.6 1,616.9 Hawaii 0.0 0.0 0.0 0.0 0.0 0.0 180.0 180.0 0.0 0.0 1,979.2 1,999.6 6.0 12.2 2,165.2 2,191.8 U.S. Total 220,682.1214,053.3121,055.8119,823.080,626.581,315.0309,680.4317,640.3 2,709.3 2,504.1 44,457.948,977.5 1,945.6 1,934.2781,157.6786,247.4

Values are final.

NOTES: Capacity from facilities with a total generator nameplate capacity less than 1 MW are excluded from this report. This exclusion may represent a signifciant portion of existing or planned capacity for some technologies such as solar photovoltaic generation.
Sources: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report' and Form EIA-860M, 'Monthly Update to the Annual Electric Generator Report.' 

### Table 4.7.C. Net Summer Capacity of Utility Scale Units Using Primarily Fossil Fuels and by State, 2012 and 2011 (Megawatts) Natural Gas Fired Combined Cycle Natural Gas Fired Combustion Turbine Other Natural Gas Coal Petroleum Coke Petroleum Liquids Other Gases Total Fossil FuelsYear Internal Combustion Combustion Turbine Steam TurbineHydro Wind PhotovoltaicStorageOtherWind and Other Total Number of Generators

2005 4,025.0 1,917.01,830.0 999.0

-- -- -- -- 995.09,766.0 17,371 2006 3,646.0 1,298.02,582.0 806.0

-- -- -- --1,081.09,411.0 5,044 2007 4,624.0 1,990.03,596.01,051.0

-- -- -- --1,441.012,702.0 7,103 2008 5,112.0 1,949.03,060.01,154.0

-- -- -- --1,588.012,863.0 9,591 2009 4,339.0 4,147.04,621.01,166.0

-- -- -- --1,729.016,002.0 13,006 2010 886.8 186.0 109.9 97.4 98.9 236.3

-- 372.7

--1,988.0 15,630 2011 791.1 115.5 64.9 97.9 36.7 314.8 0.2 264.3

--1,685.4 20,941 2012 756.1 105.8 60.2 119.9 252.9 543.7 15.2 324.4

--1,990.6 28,252

2005 4,290.0 335.0 126.0 2.0

-- -- -- -- 13.04,766.0 11,373 2006 6,524.0 346.0 157.0 3.0

-- -- -- -- 8.07,037.0 9,536 2007 7,866.0 268.0 102.0 31.0

-- -- -- -- 30.08,297.0 11,057 2008 9,335.0 86.0 248.0 34.0

-- -- -- -- 70.09,773.0 12,262 2009 9,751.0 329.0 204.0 81.0

-- -- -- -- 108.010,475.0 13,928 2010 2,771.2 64.4 13.8 8.4 6.3 95.2 7.0 17.9

--2,984.2 16,874 2011 2,916.9 40.3 14.6 6.0 3.2 2.7 8.0 7.9

--2,999.6 14,123 2012 3,180.9 49.8

-- 2.2 3.1 8.5 7.7 13.5

--3,265.5 14,557

2005 8,315.0 2,252.01,956.01,001.0

-- -- -- --1,008.014,532.0 28,744 2006 10,170.0 1,644.02,739.0 809.0

-- -- -- --1,089.016,448.0 14,580 2007 12,490.0 2,258.03,698.01,082.0

-- -- -- --1,471.020,999.0 18,160 2008 14,447.0 2,035.03,308.01,188.0

-- -- -- --1,658.022,636.0 21,853 2009 14,090.0 4,476.04,825.01,247.0

-- -- -- --1,837.026,477.0 26,934 2010 3,658.0 250.4 123.7 105.8 105.2 331.5 7.0 390.6

--4,972.2 32,504 2011 3,708.0 155.8 79.5 103.9 39.9 317.5 8.2 272.2

--4,685.0 35,064 2012 3,937.0 155.6 60.2 122.1 256.0 552.2 22.9 337.9

--5,256.1 42,809
Distributed and Dispersed generator data in 2005 include a significant number of generators reported by one respondent, which may be for residential applications. Prior to 2010, data contains generators over and under 1 MW, from 2010 forward, data contains only generators under 1 MW. Distributed generators are commercial and industrial generators which are connected to the grid. Dispersed generators are commercial and industrial generators which are not connected to the grid. Both types may be installed at or near a customer`s site, or at other locations. They may be owned by either the customers of the distribution utility or by the utility. Other includes generators for which technology is not specified. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." 

### Table 4.9. Total Capacity of Distributed and Dispersed Generators by Technology Type, 2005 through 2012 Capacity (MW)

Distributed Generators

Dispersed Generators

Distributed and Dispersed GeneratorsYear Residential Commercial Industrial Transportation Total Residential Commercial Industrial Transportation Total

2003 N/A N/A N/A N/A N/A 5,870 775 168

-- 6,813 2004 N/A N/A N/A N/A N/A 14,114 1,494 215 3 15,826 2005 N/A N/A N/A N/A N/A 19,244 1,565 337

-- 21,146 2006 N/A N/A N/A N/A N/A 30,689 2,553 376

-- 33,618 2007 N/A N/A N/A N/A N/A 44,450 3,513 391

-- 48,354 2008 N/A N/A N/A N/A N/A 64,400 5,305 304

-- 70,009 2009 N/A N/A N/A N/A N/A 88,205 7,365 919

-- 96,489

2010 698 518 243

-- 1,459 137,618 11,897 1,225

-- 150,740 2011 1,024 1,089 382

-- 2,495 198,255 18,345 2,418

-- 219,018 2012 1,542 1,742 395

-- 3,680 294,437 27,611 1,317

-- 323,365

2010 84 26 6

-- 116 3,467 583 37

-- 4,087 2011 28 44 10

-- 82 4,456 905 50

-- 5,411 2012 33 75 17

-- 126 4,796 1,143 48

-- 5,987

2010 11 35 25

-- 71 767 271 56

-- 1,094 2011 5 49 57

-- 111 807 242 100

-- 1,149 2012 8 66 83

-- 157 862 314 122

-- 1,298

2010 793 579 274

-- 1,646 141,852 12,751 1,318

-- 155,921 2011 1,057 1,183 448

-- 2,688 203,518 19,492 2,568

-- 225,578 2012 1,583 1,882 496

-- 3,962 300,095 29,068 1,487

-- 330,650 Wind

Other

All Technologies

N/A = Not Available. Capacity and customer count was not collected by technology type before 2010. Total customer count for the years 2007, 2009, and 2010 were revised based on requests from respondents. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." 

### Table 4.10. Net Metering Customers and Capacity by Technology Type, by End Use Sector, 2003 through 2012 Capacity (MW) Customers

Historical Data

PhotovoltaicProducer Type Total Net Summer Capacity of All Generators Reporting Natural Gas as the Primary Fuel Net Summer Capacity of Natural Gas-Fired Generators Reporting the Ability to Switch to Petroleum Liquids Fuel Switchable Capacity as Percent of Total Maximum Achievable Net Summer Capacity Using Petroleum Liquids Fuel Switchable Net Summer Capacity Reported to Have No Factors that Limit the Ability to

Switch to Petroleum Liquids Electric Utilities 206,774 78,346 37.9 74,835 23,624 Independent Power Producers, Non-Combined Heat and Power Plants 170,654 42,509 24.9 40,788 12,216 Independent Power Producers, Combined Heat and Power Plants 29,129 6,716 23.1 6,455 1,238 Electric Power Sector Subtotal 406,557 127,570 31.4 122,078 37,078 Commercial Sector 1,545 762 49.3 732 154 Industrial Sector 14,263 1,272 8.9 1,233 278 All Sectors 422,364 129,604 30.7 124,043 37,510 

### Table 4.11. Fuel-Switching Capacity of Operable Generators Reporting Natural Gas as the Primary Fuel, by Producer Type, 2012 (Megawatts, Percent) Fuel-Switchable Part of Total

Notes: Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.'Producer Type Total Net Summer Capacity of All Generators Reporting

Petroleum as the Primary Fuel Net Summer Capacity of Petroleum-Fired Generators Reporting the Ability to Switch to Natural GasFuel Switchable Capacity as Percent of Total Maximum Achievable Net Summer Capacity Using Natural Gas Electric Utilities 26,732 7,640 28.6 7,224 Independent Power Producers, Non-Combined Heat and Power Plants 18,644 7,867 42.2 6,628 Independent Power Producers, Combined Heat and Power Plants 317

-- -- -- Electric Power Sector Subtotal 45,693 15,507 33.9 13,852 Commercial Sector 443 21 4.8 21 Industrial Sector 1,032 44 4.2 35 All Sectors 47,167 15,572 33.0 13,908 

### Table 4.12. Fuel-Switching Capacity of Operable Generators Reporting Petroleum Liquids as the Primary Fuel, by Producer Type, 2012 (Megawatts, Percent) Fuel-Switchable Part of Total

Notes: Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.'Prime Mover Type Number of Generators Net Summer CapacityFuel Switchable Net Summer Capacity Reported to Have No Factors that Limit the Ability to Switch to Petroleum Liquids Steam Generator 183 26,382 17,932 Combined Cycle 433 45,267 6,370 Internal Combustion 324 1,056 328 Gas Turbine 940 56,900 12,880 All Fuel Switchable Prime Movers 1,880 129,604 37,510 

### Table 4.13. Fuel-Switching Capacity of Operable Generators: From Natural Gas to Petroleum Liquids, by Type of Prime Mover, 2012 (Megawatts, Percent)

Notes: Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.'Year of Initial Commercial Operation Number of Generators Net Summer CapacityFuel Switchable Net Summer Capacity Reported to Have No Factors that Limit the Ability to Switch to Petroleum Liquids Pre-1970 318 11,735 7,535 1970-1974 376 18,210 11,033 1975-1979 105 11,031 7,283 1980-1984 46 945 211 1985-1989 107 3,155 413 1990-1994 208 11,738 1,453 1995-1999 134 9,680 2,099 2000-2004 392 39,841 5,098 2005-2009 116 14,791 2,066 2010-2012 78 8,479 320 Total 1,880 129,604 37,510 

### Table 4.14. Fuel-Switching Capacity of Operable Generators: From Natural Gas to Petroleum Liquids, by Year of Initial Commercial Operation, 2012 (Megawatts, Percent)

Notes: Petroleum includes distillate fuel oil (all diesel and No. 1, No. 2, and No. 4 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil), jet fuel, kerosene, petroleum coke (converted to liquid petroleum, see Technical Notes for conversion methodology), waste oil, and beginning in 2011, synthetic gas and propane. Prior to 2011, synthetic gas and propane were included in Other Gases. In 2011, EIA corrected the NAICS codes of several plants which resulted in a net capacity shift from the electric utility sector to the commercial sector. Source: U.S. Energy Information Administration, Form EIA-860, "Annual Electric Generator Report."

# Chapter 5
Consumption of Fossil FuelsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 987,583 767,803 207,448 477 11,855 2003 1,014,058 757,384 245,652 582 10,440 2004 1,020,523 772,224 240,235 377 7,687 2005 1,041,448 761,349 272,218 377 7,504 2006 1,030,556 753,390 269,412 347 7,408 2007 1,046,795 764,765 276,581 361 5,089 2008 1,042,335 760,326 276,565 369 5,075 2009 934,683 695,615 234,077 317 4,674 2010 979,684 721,431 249,814 314 8,125 2011 934,938 689,316 239,541 347 5,735 2012 825,734 615,467 205,295 307 4,665

January 90,767 67,211 22,869 32 654 February 80,209 59,279 20,258 28 643 March 76,544 56,252 19,520 26 746

April 67,037 49,997 16,562 23 456 May 76,061 56,847 18,464 23 727 June 87,395 64,891 21,833 27 643

July 94,993 69,933 24,261 30 769 August 94,786 69,860 24,061 29 835 September 79,573 58,199 20,682 26 666 October 70,918 51,353 18,851 23 690 November 72,756 52,962 19,244 21 529 December 88,645 64,645 23,208 26 765

January 90,208 66,083 23,598 40 487 February 73,614 54,434 18,733 39 409 March 72,645 54,115 18,034 37 460

April 67,128 49,443 17,200 25 460 May 73,522 54,959 18,051 25 487 June 84,156 62,690 20,931 27 507

July 94,304 69,942 23,782 32 548 August 92,297 68,137 23,570 29 562 September 76,790 55,844 20,442 26 479 October 69,605 50,644 18,520 21 419 November 67,059 48,879 17,762 21 397 December 73,610 54,146 18,917 26 521

January 70,744 52,338 17,967 29 410 February 62,974 46,908 15,665 27 374 March 57,468 43,413 13,640 26 388

April 51,806 39,920 11,507 23 356 May 62,801 46,900 15,517 22 361 June 71,656 53,708 17,543 26 379

July 86,516 64,433 21,603 28 452 August 82,676 61,480 20,730 28 439 September 69,478 51,516 17,558 24 381 October 66,486 49,060 17,044 21 361 November 69,913 51,276 18,245 25 366 December 73,217 54,516 18,275 27 398 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.1.A. Coal: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 17,561 0 2,255 929 14,377 2003 17,720 0 2,080 1,234 14,406 2004 24,275 0 3,809 1,540 18,926 2005 23,833 0 3,918 1,544 18,371 2006 23,227 0 3,834 1,539 17,854 2007 22,810 0 3,795 1,566 17,449 2008 22,168 0 3,689 1,652 16,827 2009 20,507 0 3,935 1,481 15,091 2010 21,727 0 3,808 1,406 16,513 2011 21,532 0 3,628 1,321 16,584 2012 19,333 0 2,790 1,143 15,400

January 1,972 0 371 160 1,440 February 1,820 0 347 139 1,334 March 1,839 0 338 123 1,378

April 2,142 0 284 95 1,764 May 1,664 0 285 95 1,283 June 1,668 0 306 108 1,255

July 1,790 0 325 112 1,354 August 1,807 0 326 123 1,359 September 1,677 0 296 107 1,275 October 1,653 0 287 98 1,267 November 1,740 0 308 107 1,325 December 1,955 0 336 139 1,481

January 2,084 0 340 149 1,595 February 1,833 0 307 135 1,391 March 1,869 0 310 127 1,431

April 1,713 0 287 98 1,327 May 1,776 0 328 99 1,349 June 1,726 0 287 103 1,336

July 1,824 0 313 113 1,397 August 1,807 0 305 101 1,400 September 1,689 0 283 96 1,309 October 1,712 0 294 89 1,329 November 1,689 0 277 96 1,315 December 1,812 0 296 113 1,403

January 2,021 0 289 127 1,605 February 1,797 0 232 108 1,458 March 1,609 0 212 101 1,295

April 1,370 0 166 79 1,125 May 1,518 0 230 86 1,202 June 1,486 0 229 83 1,174

July 1,598 0 247 91 1,260 August 1,631 0 275 93 1,264 September 1,473 0 235 83 1,154 October 1,545 0 239 80 1,226 November 1,600 0 218 99 1,283 December 1,685 0 218 113 1,354 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.1.B. Coal: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 1,005,144 767,803 209,703 1,405 26,232 2003 1,031,778 757,384 247,732 1,816 24,846 2004 1,044,798 772,224 244,044 1,917 26,613 2005 1,065,281 761,349 276,135 1,922 25,875 2006 1,053,783 753,390 273,246 1,886 25,262 2007 1,069,606 764,765 280,377 1,927 22,537 2008 1,064,503 760,326 280,254 2,021 21,902 2009 955,190 695,615 238,012 1,798 19,766 2010 1,001,411 721,431 253,621 1,720 24,638 2011 956,470 689,316 243,168 1,668 22,319 2012 845,066 615,467 208,085 1,450 20,065

January 92,738 67,211 23,240 193 2,094 February 82,029 59,279 20,605 167 1,978 March 78,383 56,252 19,858 149 2,124

April 69,179 49,997 16,845 117 2,220 May 77,725 56,847 18,750 118 2,010 June 89,063 64,891 22,139 135 1,898

July 96,783 69,933 24,586 142 2,122 August 96,593 69,860 24,387 152 2,194 September 81,250 58,199 20,977 133 1,941 October 72,571 51,353 19,139 121 1,958 November 74,496 52,962 19,552 128 1,854 December 90,600 64,645 23,544 165 2,246

January 92,292 66,083 23,939 189 2,082 February 75,447 54,434 19,040 173 1,800 March 74,514 54,115 18,343 164 1,891

April 68,841 49,443 17,487 124 1,787 May 75,298 54,959 18,379 124 1,836 June 85,881 62,690 21,218 130 1,843

July 96,128 69,942 24,095 145 1,946 August 94,103 68,137 23,875 129 1,962 September 78,479 55,844 20,724 122 1,788 October 71,317 50,644 18,814 110 1,748 November 68,748 48,879 18,039 117 1,712 December 75,422 54,146 19,213 139 1,923

January 72,764 52,338 18,256 155 2,015 February 64,771 46,908 15,897 135 1,832 March 59,077 43,413 13,852 128 1,684

April 53,176 39,920 11,673 102 1,481 May 64,319 46,900 15,748 108 1,563 June 73,142 53,708 17,772 109 1,553

July 88,115 64,433 21,850 120 1,712 August 84,307 61,480 21,004 120 1,703 September 70,951 51,516 17,793 107 1,535 October 68,030 49,060 17,283 101 1,587 November 71,512 51,276 18,464 124 1,649 December 74,901 54,516 18,493 141 1,751 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.1.C. Coal: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 19,996,890 15,517,857 4,215,043 9,168 254,821 2003 20,366,879 15,391,188 4,745,545 13,080 217,066 2004 20,375,751 15,610,335 4,606,584 8,251 150,581 2005 20,801,716 15,397,688 5,250,824 8,314 144,889 2006 20,527,410 15,211,077 5,166,001 7,526 142,807 2007 20,841,871 15,436,110 5,287,202 7,833 110,727 2008 20,548,610 15,189,050 5,242,194 8,070 109,296 2009 18,240,611 13,744,178 4,390,596 7,007 98,829 2010 19,196,315 14,333,496 4,709,686 6,815 146,318 2011 18,074,298 13,551,416 4,399,144 7,263 116,475 2012 15,867,141 11,995,971 3,767,011 6,383 97,775

January 1,792,455 1,341,522 438,461 703 11,769 February 1,584,519 1,181,007 391,557 621 11,334 March 1,493,927 1,114,613 365,639 559 13,115

April 1,316,582 995,633 311,079 481 9,389 May 1,489,806 1,129,893 346,590 514 12,809 June 1,722,718 1,294,123 416,294 601 11,699

July 1,876,586 1,401,288 460,903 676 13,719 August 1,865,192 1,393,687 456,226 644 14,636 September 1,550,912 1,153,963 384,143 556 12,251 October 1,371,705 1,012,350 346,400 487 12,467 November 1,401,177 1,036,324 354,510 432 9,911 December 1,730,737 1,279,092 437,884 541 13,218

January 1,763,170 1,307,741 444,639 836 9,955 February 1,432,157 1,072,748 350,173 798 8,438 March 1,400,484 1,061,807 328,646 756 9,274

April 1,295,986 972,440 313,907 529 9,110 May 1,432,180 1,086,571 335,344 537 9,727 June 1,646,308 1,246,730 388,860 596 10,123

July 1,847,192 1,390,380 445,064 682 11,066 August 1,797,976 1,351,103 434,923 617 11,333 September 1,471,083 1,094,574 366,248 548 9,712 October 1,321,304 978,991 333,369 436 8,509 November 1,271,795 944,086 319,257 415 8,036 December 1,394,662 1,044,244 338,714 513 11,191

January 1,348,608 1,012,122 327,295 595 8,595 February 1,194,392 905,071 280,975 570 7,777 March 1,105,492 846,083 250,739 543 8,127

April 1,007,851 785,334 214,575 473 7,469 May 1,216,206 920,501 287,764 454 7,487 June 1,383,256 1,050,959 323,743 548 8,005

July 1,688,679 1,271,150 407,424 612 9,493 August 1,601,665 1,207,322 384,462 588 9,293 September 1,322,241 998,493 315,266 495 7,986 October 1,262,892 947,165 307,710 439 7,578 November 1,338,310 997,932 332,222 507 7,648 December 1,397,549 1,053,838 334,837 558 8,316 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.1.D. Coal: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 421,084 0 50,041 23,099 347,944 2003 416,700 0 47,817 28,479 340,405 2004 564,497 0 87,981 34,538 441,978 2005 548,666 0 88,364 34,616 425,685 2006 532,561 0 84,335 34,086 414,140 2007 521,717 0 83,838 34,690 403,189 2008 503,096 0 81,416 36,163 385,517 2009 462,674 0 90,867 32,651 339,156 2010 490,931 0 90,184 30,725 370,022 2011 479,822 0 84,855 28,056 366,911 2012 420,923 0 58,275 23,673 338,975

January 44,514 0 8,627 3,445 32,442 February 40,887 0 8,041 3,024 29,823 March 41,529 0 7,926 2,646 30,957

April 49,876 0 6,822 2,048 41,006 May 37,678 0 6,843 2,099 28,736 June 37,546 0 7,185 2,461 27,900

July 40,421 0 7,799 2,604 30,018 August 40,523 0 7,634 2,767 30,121 September 37,922 0 7,172 2,350 28,401 October 37,289 0 6,993 2,099 28,197 November 38,881 0 7,182 2,263 29,436 December 43,865 0 7,959 2,919 32,987

January 46,693 0 7,965 3,205 35,523 February 40,900 0 7,129 2,879 30,892 March 42,037 0 7,448 2,680 31,909

April 38,014 0 6,703 2,064 29,247 May 39,478 0 7,680 2,137 29,662 June 38,498 0 6,693 2,258 29,547

July 40,876 0 7,353 2,508 31,015 August 40,319 0 7,136 2,239 30,945 September 37,717 0 6,626 2,077 29,014 October 38,024 0 6,905 1,781 29,339 November 37,180 0 6,248 1,914 29,019 December 40,087 0 6,971 2,317 30,799

January 43,026 0 6,114 2,569 34,343 February 38,171 0 4,911 2,228 31,032 March 35,483 0 4,736 2,034 28,712

April 30,144 0 3,638 1,591 24,915 May 33,661 0 5,066 1,809 26,787 June 32,897 0 4,881 1,829 26,186

July 35,103 0 5,153 2,015 27,936 August 35,456 0 5,494 1,993 27,968 September 32,151 0 4,857 1,728 25,566 October 33,618 0 4,902 1,615 27,101 November 34,627 0 4,274 1,960 28,393 December 36,586 0 4,246 2,303 30,036 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.1.E. Coal: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 20,417,974 15,517,857 4,265,084 32,267 602,765 2003 20,783,579 15,391,188 4,793,362 41,559 557,471 2004 20,940,247 15,610,335 4,694,565 42,789 592,559 2005 21,350,382 15,397,688 5,339,188 42,931 570,574 2006 21,059,972 15,211,077 5,250,336 41,612 556,948 2007 21,363,588 15,436,110 5,371,039 42,523 513,916 2008 21,051,706 15,189,050 5,323,610 44,233 494,813 2009 18,703,284 13,744,178 4,481,463 39,658 437,985 2010 19,687,246 14,333,496 4,799,870 37,540 516,341 2011 18,554,120 13,551,416 4,483,999 35,319 483,385 2012 16,288,063 11,995,971 3,825,286 30,056 436,750

January 1,836,969 1,341,522 447,089 4,148 44,210 February 1,625,407 1,181,007 399,597 3,645 41,158 March 1,535,456 1,114,613 373,565 3,205 44,072

April 1,366,458 995,633 317,902 2,528 50,395 May 1,527,484 1,129,893 353,433 2,613 41,544 June 1,760,264 1,294,123 423,479 3,063 39,599

July 1,917,007 1,401,288 468,702 3,280 43,738 August 1,905,714 1,393,687 463,860 3,411 44,757 September 1,588,834 1,153,963 391,314 2,906 40,652 October 1,408,993 1,012,350 353,393 2,585 40,664 November 1,440,058 1,036,324 361,692 2,695 39,346 December 1,774,601 1,279,092 445,843 3,460 46,205

January 1,809,863 1,307,741 452,604 4,040 45,479 February 1,473,056 1,072,748 357,302 3,677 39,330 March 1,442,520 1,061,807 336,094 3,436 41,183

April 1,334,000 972,440 320,611 2,593 38,357 May 1,471,658 1,086,571 343,024 2,674 39,389 June 1,684,806 1,246,730 395,552 2,854 39,670

July 1,888,069 1,390,380 452,416 3,191 42,082 August 1,838,295 1,351,103 442,059 2,856 42,277 September 1,508,800 1,094,574 372,875 2,625 38,726 October 1,359,328 978,991 340,273 2,216 37,848 November 1,308,974 944,086 325,505 2,329 37,055 December 1,434,749 1,044,244 345,685 2,829 41,990

January 1,391,633 1,012,122 333,409 3,164 42,938 February 1,232,563 905,071 285,886 2,797 38,809 March 1,140,974 846,083 255,475 2,577 36,839

April 1,037,996 785,334 218,213 2,064 32,384 May 1,249,868 920,501 292,830 2,263 34,274 June 1,416,152 1,050,959 328,624 2,377 34,192

July 1,723,783 1,271,150 412,576 2,627 37,429 August 1,637,121 1,207,322 389,956 2,581 37,261 September 1,354,391 998,493 320,123 2,223 33,552 October 1,296,510 947,165 312,612 2,054 34,679 November 1,372,937 997,932 336,496 2,468 36,041 December 1,434,135 1,053,838 339,084 2,862 38,352 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.1.F. Coal: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 134,415 88,595 39,035 826 5,959 2003 175,136 105,319 61,420 882 7,514 2004 165,107 103,793 56,342 760 4,212 2005 165,137 98,223 62,154 580 4,180 2006 73,821 53,529 17,179 327 2,786 2007 82,433 56,910 22,793 250 2,480 2008 53,846 38,995 13,152 160 1,538 2009 43,562 31,847 9,880 184 1,652 2010 40,103 30,806 8,278 164 855 2011 27,326 20,844 5,633 133 716 2012 22,604 17,521 4,110 272 702

January 5,587 4,381 1,083 17 106 February 2,156 1,599 454 15 88 March 2,178 1,775 325 11 66

April 2,013 1,633 306 10 63 May 3,168 2,593 496 14 65 June 4,485 3,667 750 13 55

July 5,228 3,545 1,589 26 68 August 4,245 3,232 944 15 54 September 2,844 2,154 622 13 56 October 2,029 1,581 369 10 69 November 2,001 1,487 436 5 73 December 4,170 3,161 903 14 91

January 3,325 2,207 1,005 26 87 February 2,077 1,590 400 16 72 March 2,160 1,737 351 10 63

April 2,450 2,091 296 5 57 May 2,291 1,886 347 5 52 June 2,355 1,745 553 5 53

July 2,926 1,906 958 14 49 August 2,290 1,749 480 12 49 September 1,834 1,427 342 13 52 October 1,835 1,481 280 10 64 November 1,832 1,488 278 10 55 December 1,952 1,539 343 8 62

January 1,933 1,495 317 28 93 February 1,544 1,245 218 18 64 March 1,629 1,360 188 16 65

April 1,612 1,339 204 17 52 May 1,864 1,441 341 25 57 June 2,320 1,733 519 24 44

July 2,683 2,032 568 32 51 August 2,014 1,597 338 27 52 September 1,591 1,279 242 18 51 October 1,722 1,372 265 21 64 November 1,648 1,282 294 23 48 December 2,045 1,345 617 23 60 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.2.A. Petroleum Liquids: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Thousand Barrels) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 12,228 0 286 384 11,558 2003 14,124 0 1,197 512 12,414 2004 20,654 0 1,501 1,203 17,951 2005 20,494 0 1,392 1,004 18,097 2006 14,077 0 1,153 559 12,365 2007 13,462 0 1,303 441 11,718 2008 7,533 0 1,311 461 5,762 2009 8,128 0 1,301 293 6,534 2010 4,866 0 1,086 212 3,567 2011 3,826 0 1,004 168 2,654 2012 3,097 0 992 122 1,984

January 606 0 105 31 470 February 504 0 78 26 401 March 335 0 46 7 281

April 355 0 86 9 260 May 340 0 93 14 232 June 304 0 89 13 202

July 392 0 90 34 268 August 337 0 91 26 220 September 313 0 88 9 215 October 398 0 95 5 298 November 431 0 128 8 296 December 552 0 97 31 424

January 538 0 94 69 375 February 370 0 72 26 272 March 333 0 75 9 249

April 287 0 83 3 201 May 287 0 82 7 198 June 286 0 82 4 200

July 272 0 87 8 176 August 284 0 92 8 184 September 280 0 89 11 180 October 311 0 87 5 219 November 293 0 83 14 195 December 286 0 76 3 207

January 554 0 117 51 386 February 242 0 81 4 158 March 267 0 53 8 207

April 211 0 66 2 144 May 229 0 86 2 141 June 215 0 90 4 121

July 222 0 82 23 117 August 221 0 82 7 132 September 194 0 79 2 112 October 271 0 87 2 182 November 228 0 84 8 135 December 242 0 85 8 149 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.2.B. Petroleum Liquids: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Barrels) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 146,643 88,595 39,320 1,210 17,517 2003 189,260 105,319 62,617 1,394 19,929 2004 185,761 103,793 57,843 1,963 22,162 2005 185,631 98,223 63,546 1,584 22,278 2006 87,898 53,529 18,332 886 15,150 2007 95,895 56,910 24,097 691 14,198 2008 61,379 38,995 14,463 621 7,300 2009 51,690 31,847 11,181 477 8,185 2010 44,968 30,806 9,364 376 4,422 2011 31,152 20,844 6,637 301 3,370 2012 25,702 17,521 5,102 394 2,685

January 6,193 4,381 1,188 48 576 February 2,660 1,599 532 41 489 March 2,512 1,775 371 18 348

April 2,367 1,633 392 19 323 May 3,507 2,593 589 28 297 June 4,789 3,667 839 26 257

July 5,620 3,545 1,679 59 336 August 4,582 3,232 1,035 40 274 September 3,157 2,154 711 22 271 October 2,427 1,581 463 15 367 November 2,433 1,487 564 13 369 December 4,722 3,161 1,000 46 515

January 3,863 2,207 1,099 95 462 February 2,447 1,590 472 42 343 March 2,493 1,737 425 19 312

April 2,736 2,091 380 8 258 May 2,578 1,886 430 12 250 June 2,642 1,745 636 9 253

July 3,198 1,906 1,045 23 225 August 2,573 1,749 572 20 233 September 2,114 1,427 431 23 232 October 2,145 1,481 367 14 283 November 2,124 1,488 361 24 251 December 2,238 1,539 419 11 269

January 2,487 1,495 433 79 479 February 1,787 1,245 299 22 222 March 1,897 1,360 241 24 272

April 1,824 1,339 270 18 196 May 2,093 1,441 427 27 198 June 2,534 1,733 608 28 165

July 2,905 2,032 650 55 167 August 2,236 1,597 421 34 184 September 1,784 1,279 322 20 163 October 1,993 1,372 351 23 246 November 1,875 1,282 378 32 184 December 2,287 1,345 702 31 209 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.2.C. Petroleum Liquids: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Barrels) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 835,481 553,390 241,892 3,953 36,243 2003 1,089,307 658,868 380,378 5,358 44,702 2004 1,031,954 651,712 350,093 4,544 25,606 2005 1,035,045 618,811 387,355 3,469 25,410 2006 459,392 335,130 105,312 1,963 16,987 2007 512,423 355,999 139,977 1,505 14,942 2008 332,367 242,379 79,816 957 9,215 2009 266,508 196,346 59,277 1,101 9,784 2010 244,114 188,987 49,042 970 5,115 2011 163,954 125,755 33,166 801 4,233 2012 134,956 105,179 24,081 1,618 4,078

January 33,737 26,715 6,282 100 639 February 12,882 9,681 2,578 89 534 March 13,180 10,815 1,900 68 397

April 12,156 9,948 1,773 61 375 May 19,351 15,956 2,926 84 386 June 27,665 22,803 4,455 77 329

July 32,279 22,030 9,689 153 406 August 26,126 20,015 5,703 88 319 September 17,357 13,250 3,699 75 333 October 12,267 9,642 2,154 58 412 November 12,024 8,970 2,587 32 435 December 25,091 19,162 5,295 84 549

January 20,010 13,314 6,015 160 521 February 12,446 9,595 2,331 95 425 March 12,977 10,490 2,054 57 376

April 14,715 12,631 1,713 32 340 May 13,840 11,454 2,050 29 307 June 14,196 10,558 3,296 28 313

July 17,692 11,583 5,739 86 284 August 13,843 10,674 2,810 72 286 September 10,910 8,569 1,960 76 305 October 10,891 8,840 1,613 57 381 November 10,872 8,879 1,605 61 326 December 11,562 9,169 1,978 47 368

January 11,656 9,046 1,892 167 551 February 9,260 7,500 1,282 106 372 March 9,708 8,119 1,111 97 380

April 9,570 7,972 1,196 98 304 May 11,111 8,649 1,979 148 335 June 13,900 10,391 3,117 141 251

July 16,184 12,289 3,412 190 293 August 12,079 9,621 2,001 159 298 September 9,471 7,653 1,416 106 297 October 10,239 8,185 1,552 127 376 November 9,855 7,694 1,743 139 279 December 11,923 8,060 3,380 139 343 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.2.D. Petroleum Liquids: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 76,737 0 1,669 3,276 71,788 2003 85,488 0 6,963 3,176 75,349 2004 124,809 0 8,592 7,219 108,997 2005 125,689 0 8,134 6,145 111,410 2006 87,137 0 6,740 3,481 76,916 2007 82,768 0 7,602 2,754 72,412 2008 45,481 0 7,644 2,786 35,051 2009 48,912 0 7,557 1,802 39,552 2010 29,243 0 6,402 1,297 21,545 2011 22,799 0 5,927 1,039 15,833 2012 18,233 0 5,871 746 11,616

January 3,648 0 614 190 2,843 February 3,027 0 422 157 2,447 March 2,015 0 272 43 1,699

April 2,113 0 506 55 1,552 May 2,043 0 554 85 1,404 June 1,826 0 531 78 1,217

July 2,357 0 534 209 1,613 August 2,022 0 541 159 1,322 September 1,886 0 526 55 1,304 October 2,401 0 565 30 1,806 November 2,589 0 765 46 1,778 December 3,316 0 572 187 2,557

January 3,261 0 554 434 2,273 February 2,197 0 415 169 1,613 March 1,988 0 443 56 1,490

April 1,702 0 495 16 1,191 May 1,704 0 489 42 1,173 June 1,706 0 489 23 1,193

July 1,614 0 517 53 1,045 August 1,680 0 543 47 1,090 September 1,656 0 527 65 1,063 October 1,849 0 515 29 1,304 November 1,736 0 490 86 1,160 December 1,708 0 452 20 1,236

January 3,326 0 697 315 2,313 February 1,422 0 479 24 919 March 1,564 0 315 49 1,200

April 1,234 0 388 11 835 May 1,345 0 510 14 821 June 1,256 0 530 24 702

July 1,304 0 482 146 676 August 1,302 0 489 42 771 September 1,135 0 468 14 653 October 1,600 0 511 11 1,077 November 1,338 0 498 48 792 December 1,408 0 505 46 857 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.2.E. Petroleum Liquids: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 912,218 553,390 243,561 7,229 108,031 2003 1,174,795 658,868 387,341 8,534 120,051 2004 1,156,763 651,712 358,685 11,763 134,603 2005 1,160,733 618,811 395,489 9,614 136,820 2006 546,529 335,130 112,052 5,444 93,903 2007 595,191 355,999 147,579 4,259 87,354 2008 377,848 242,379 87,460 3,743 44,266 2009 315,420 196,346 66,834 2,903 49,336 2010 273,357 188,987 55,444 2,267 26,660 2011 186,753 125,755 39,093 1,840 20,066 2012 153,189 105,179 29,952 2,364 15,695

January 37,385 26,715 6,896 291 3,483 February 15,909 9,681 3,000 247 2,981 March 15,196 10,815 2,172 111 2,097

April 14,269 9,948 2,279 116 1,927 May 21,394 15,956 3,480 169 1,790 June 29,491 22,803 4,986 155 1,546

July 34,635 22,030 10,223 363 2,019 August 28,148 20,015 6,244 247 1,641 September 19,243 13,250 4,225 130 1,637 October 14,668 9,642 2,719 88 2,219 November 14,613 8,970 3,352 78 2,213 December 28,407 19,162 5,867 271 3,107

January 23,271 13,314 6,569 594 2,794 February 14,643 9,595 2,746 264 2,038 March 14,965 10,490 2,497 113 1,866

April 16,417 12,631 2,208 47 1,531 May 15,544 11,454 2,539 71 1,480 June 15,901 10,558 3,785 52 1,507

July 19,306 11,583 6,256 138 1,329 August 15,522 10,674 3,353 119 1,376 September 12,566 8,569 2,487 142 1,369 October 12,740 8,840 2,128 86 1,685 November 12,608 8,879 2,095 148 1,487 December 13,269 9,169 2,429 67 1,605

January 14,982 9,046 2,589 483 2,864 February 10,682 7,500 1,761 131 1,291 March 11,271 8,119 1,425 146 1,580

April 10,803 7,972 1,584 109 1,139 May 12,456 8,649 2,489 162 1,156 June 15,156 10,391 3,647 165 952

July 17,488 12,289 3,893 337 969 August 13,381 9,621 2,490 201 1,069 September 10,606 7,653 1,883 120 950 October 11,839 8,185 2,064 138 1,453 November 11,194 7,694 2,241 187 1,071 December 13,330 8,060 3,885 185 1,200 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.2.F. Petroleum Liquids: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 6,836 2,125 3,580 2 1,130 2003 6,303 2,554 3,166 2 582 2004 7,677 4,150 2,985 1 541 2005 8,330 4,130 3,746 1 452 2006 7,363 3,619 3,286 1 456 2007 6,036 2,808 2,715 2 512 2008 5,417 2,296 2,704 1 416 2009 4,821 2,761 1,724 1 335 2010 4,994 3,325 1,354 2 313 2011 5,012 3,449 1,277 1 286 2012 3,675 2,105 756 1 812

January 433 283 121 0 29 February 404 258 120 0 25 March 438 308 108 0 23

April 382 253 107 0 22 May 415 261 129 0 25 June 493 319 144 0 30

July 524 340 155 0 29 August 423 286 106 0 31 September 394 296 75 0 23 October 362 245 92 0 25 November 317 201 89 0 27 December 408 274 108 0 25

January 552 400 124 0 28 February 431 295 114 0 22 March 517 344 151 0 22

April 336 218 94 0 24 May 357 232 101 0 24 June 432 302 107 0 22

July 510 359 131 0 19 August 464 330 110 0 24 September 454 333 95 0 26 October 338 229 83 0 25 November 257 155 77 0 25 December 365 252 88 0 25

January 476 297 92 0 87 February 363 230 77 0 56 March 226 107 61 0 58

April 212 120 37 0 55 May 255 150 51 0 55 June 280 169 53 0 58

July 307 182 62 0 63 August 338 170 87 0 80 September 314 180 61 0 73 October 280 156 64 0 60 November 314 175 55 0 84 December 308 170 56 0 82 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.3.A. Petroleum Coke: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 517 0 111 6 399 2003 763 0 80 9 675 2004 1,043 0 237 8 798 2005 783 0 206 8 568 2006 1,259 0 195 9 1,055 2007 1,262 0 162 11 1,090 2008 897 0 119 9 769 2009 1,007 0 126 8 873 2010 1,059 0 98 11 950 2011 1,080 0 112 6 962 2012 1,346 0 113 11 1,222

January 92 0 10 1 81 February 93 0 10 1 82 March 84 0 12 1 71

April 76 0 9 1 66 May 84 0 10 0 75 June 93 0 8 0 86

July 89 0 8 0 80 August 87 0 2 1 84 September 82 0 2 1 79 October 91 0 9 1 81 November 97 0 11 1 84 December 91 0 9 2 81

January 93 0 5 1 86 February 90 0 9 1 81 March 85 0 11 1 73

April 92 0 9 0 83 May 95 0 11 0 84 June 89 0 9 0 80

July 89 0 11 0 79 August 81 0 11 0 70 September 90 0 10 0 80 October 91 0 7 0 84 November 88 0 9 1 79 December 95 0 10 1 84

January 128 0 11 1 116 February 108 0 11 1 96 March 108 0 10 1 97

April 87 0 9 0 78 May 91 0 11 0 80 June 100 0 6 0 94

July 118 0 9 1 108 August 133 0 10 1 122 September 116 0 9 1 105 October 117 0 9 1 107 November 122 0 9 1 112 December 118 0 10 1 107 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.3.B. Petroleum Coke: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 7,353 2,125 3,691 8 1,529 2003 7,067 2,554 3,245 11 1,257 2004 8,721 4,150 3,223 9 1,339 2005 9,113 4,130 3,953 9 1,020 2006 8,622 3,619 3,482 10 1,511 2007 7,299 2,808 2,877 12 1,602 2008 6,314 2,296 2,823 10 1,184 2009 5,828 2,761 1,850 9 1,209 2010 6,053 3,325 1,452 12 1,264 2011 6,092 3,449 1,388 6 1,248 2012 5,021 2,105 869 13 2,034

January 525 283 130 1 110 February 497 258 131 1 106 March 522 308 119 1 94

April 458 253 116 1 88 May 500 261 139 0 100 June 586 319 151 0 116

July 613 340 163 0 109 August 510 286 108 1 115 September 475 296 76 1 102 October 453 245 101 1 106 November 414 201 100 2 111 December 499 274 117 2 106

January 645 400 129 1 114 February 521 295 122 1 102 March 603 344 162 1 95

April 428 218 103 0 107 May 452 232 112 0 108 June 521 302 117 0 102

July 599 359 142 0 98 August 545 330 121 0 94 September 545 333 105 0 106 October 429 229 90 0 109 November 345 155 86 1 103 December 460 252 98 2 109

January 605 297 103 2 203 February 470 230 88 1 152 March 335 107 72 1 155

April 299 120 46 0 133 May 346 150 61 0 135 June 380 169 59 0 152

July 426 182 72 1 171 August 471 170 97 1 203 September 430 180 70 1 178 October 397 156 73 1 167 November 435 175 63 1 196 December 426 170 66 1 188 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.3.C. Petroleum Coke: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 178,725 57,296 102,224 48 19,158 2003 176,657 69,695 90,102 65 16,796 2004 216,047 116,086 83,979 33 15,949 2005 234,217 115,727 105,163 33 13,295 2006 208,518 102,117 92,643 33 13,726 2007 170,166 77,941 77,135 45 15,045 2008 152,933 64,843 76,416 37 11,638 2009 136,474 77,919 48,776 32 9,747 2010 141,774 94,331 38,235 44 9,165 2011 144,406 99,257 36,923 20 8,206 2012 105,488 60,862 21,643 39 22,944

January 12,265 7,995 3,431 5 835 February 11,386 7,244 3,415 4 723 March 12,395 8,660 3,054 6 676

April 10,813 7,146 3,029 4 635 May 11,779 7,415 3,630 0 733 June 13,964 9,060 4,043 0 861

July 14,869 9,661 4,362 0 845 August 12,020 8,153 2,979 4 884 September 11,265 8,455 2,112 4 693 October 10,338 6,953 2,628 5 753 November 9,051 5,728 2,519 6 798 December 11,628 7,861 3,031 7 729

January 15,806 11,407 3,591 5 802 February 12,355 8,480 3,247 4 624 March 14,855 9,896 4,321 5 633

April 9,679 6,299 2,693 0 686 May 10,278 6,675 2,894 0 709 June 12,476 8,724 3,103 0 649

July 14,730 10,320 3,844 0 565 August 13,397 9,457 3,259 0 681 September 13,161 9,629 2,800 0 732 October 9,750 6,619 2,414 0 717 November 7,377 4,473 2,205 2 697 December 10,543 7,278 2,551 4 710

January 13,587 8,575 2,622 5 2,385 February 10,411 6,655 2,212 4 1,540 March 6,477 3,067 1,748 4 1,659

April 6,099 3,455 1,068 0 1,576 May 7,347 4,327 1,464 0 1,556 June 8,142 4,967 1,528 0 1,647

July 8,862 5,293 1,759 4 1,806 August 9,726 4,939 2,498 4 2,285 September 9,046 5,209 1,746 4 2,087 October 8,023 4,491 1,824 5 1,703 November 8,977 5,008 1,569 4 2,396 December 8,791 4,876 1,605 4 2,306 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.3.D. Petroleum Coke: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 14,395 0 3,192 179 11,024 2003 21,170 0 2,282 244 18,644 2004 29,342 0 6,768 226 22,347 2005 22,224 0 5,935 228 16,061 2006 38,169 0 5,672 236 32,262 2007 38,033 0 4,710 303 33,019 2008 27,100 0 3,441 243 23,416 2009 29,974 0 3,652 213 26,109 2010 31,303 0 2,855 296 28,152 2011 31,943 0 3,244 153 28,546 2012 38,777 0 3,281 315 35,181

January 2,683 0 285 33 2,365 February 2,770 0 302 29 2,439 March 2,424 0 338 36 2,050

April 2,257 0 255 22 1,980 May 2,498 0 280 0 2,217 June 2,716 0 222 0 2,493

July 2,620 0 242 0 2,377 August 2,525 0 52 29 2,445 September 2,534 0 54 28 2,452 October 2,721 0 252 32 2,437 November 2,868 0 324 41 2,503 December 2,688 0 250 46 2,393

January 2,698 0 152 35 2,511 February 2,661 0 250 29 2,383 March 2,502 0 317 34 2,151

April 2,723 0 269 0 2,455 May 2,806 0 308 0 2,499 June 2,660 0 273 0 2,386

July 2,682 0 311 0 2,371 August 2,420 0 307 0 2,113 September 2,690 0 301 0 2,389 October 2,698 0 212 0 2,485 November 2,601 0 254 16 2,331 December 2,802 0 292 38 2,472

January 3,667 0 315 40 3,312 February 3,132 0 307 34 2,791 March 3,138 0 304 32 2,802

April 2,481 0 264 2 2,215 May 2,628 0 315 0 2,313 June 2,922 0 160 0 2,763

July 3,418 0 269 30 3,120 August 3,816 0 279 36 3,502 September 3,349 0 274 35 3,040 October 3,402 0 257 37 3,108 November 3,480 0 256 33 3,191 December 3,343 0 283 36 3,024 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.3.E. Petroleum Coke: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 193,120 57,296 105,416 227 30,182 2003 197,827 69,695 92,384 309 35,440 2004 245,389 116,086 90,747 259 38,297 2005 256,441 115,727 111,098 260 29,356 2006 246,687 102,117 98,314 269 45,987 2007 208,198 77,941 81,845 348 48,064 2008 180,034 64,843 79,856 280 35,055 2009 166,449 77,919 52,428 245 35,856 2010 173,078 94,331 41,090 340 37,317 2011 176,349 99,257 40,167 173 36,752 2012 144,266 60,862 24,925 353 58,126

January 14,949 7,995 3,716 38 3,199 February 14,156 7,244 3,717 33 3,162 March 14,819 8,660 3,392 42 2,726

April 13,070 7,146 3,284 26 2,615 May 14,277 7,415 3,911 0 2,951 June 16,680 9,060 4,266 0 3,354

July 17,489 9,661 4,604 0 3,223 August 14,546 8,153 3,031 33 3,329 September 13,799 8,455 2,166 32 3,145 October 13,059 6,953 2,880 37 3,190 November 11,919 5,728 2,843 47 3,301 December 14,316 7,861 3,281 53 3,122

January 18,504 11,407 3,743 40 3,313 February 15,016 8,480 3,496 33 3,007 March 17,356 9,896 4,638 39 2,784

April 12,402 6,299 2,962 0 3,141 May 13,085 6,675 3,202 0 3,208 June 15,135 8,724 3,376 0 3,035

July 17,412 10,320 4,156 0 2,936 August 15,816 9,457 3,565 0 2,794 September 15,851 9,629 3,101 0 3,122 October 12,448 6,619 2,626 0 3,203 November 9,978 4,473 2,459 18 3,028 December 13,345 7,278 2,843 42 3,182

January 17,254 8,575 2,937 45 5,697 February 13,542 6,655 2,519 38 4,331 March 9,615 3,067 2,051 36 4,461

April 8,581 3,455 1,332 2 3,791 May 9,975 4,327 1,779 0 3,869 June 11,064 4,967 1,688 0 4,409

July 12,280 5,293 2,028 34 4,925 August 13,543 4,939 2,777 40 5,787 September 12,395 5,209 2,020 39 5,127 October 11,425 4,491 2,081 41 4,811 November 12,457 5,008 1,825 37 5,587 December 12,134 4,876 1,888 40 5,330 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.3.F. Petroleum Coke: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 6,126,062 2,259,684 3,148,595 32,545 685,239 2003 5,616,135 1,763,764 3,145,485 38,480 668,407 2004 5,674,580 1,809,443 3,265,896 32,839 566,401 2005 6,036,370 2,134,859 3,349,921 33,785 517,805 2006 6,461,615 2,478,396 3,412,826 34,623 535,770 2007 7,089,342 2,736,418 3,765,194 34,087 553,643 2008 6,895,843 2,730,134 3,612,197 33,403 520,109 2009 7,121,069 2,911,279 3,655,712 34,279 519,799 2010 7,680,185 3,290,993 3,794,423 39,462 555,307 2011 7,883,865 3,446,087 3,819,107 47,170 571,501 2012 9,484,710 4,101,927 4,686,260 63,116 633,407

January 570,204 244,970 274,050 3,162 48,023 February 501,790 211,934 244,016 2,894 42,945 March 478,851 207,974 223,630 2,972 44,275

April 493,588 210,270 238,616 2,709 41,994 May 582,287 261,882 273,632 2,661 44,111 June 731,357 314,471 366,984 2,931 46,970

July 922,648 387,996 480,611 3,659 50,382 August 971,855 411,663 503,418 3,847 52,927 September 723,230 306,156 365,331 3,447 48,295 October 594,338 260,110 287,180 3,471 43,576 November 519,375 219,357 253,331 3,345 43,341 December 590,663 254,209 283,622 4,364 48,467

January 563,712 238,731 273,552 3,518 47,910 February 505,126 208,813 250,551 3,069 42,692 March 503,090 217,538 239,429 3,169 42,953

April 545,924 243,866 253,900 3,062 45,096 May 598,689 268,818 279,002 4,043 46,826 June 727,189 330,305 344,944 3,957 47,982

July 967,125 430,187 478,936 5,316 52,686 August 951,425 421,042 471,544 5,001 53,838 September 711,980 306,699 352,213 4,290 48,779 October 599,544 266,740 284,312 3,727 44,764 November 568,007 242,306 275,414 3,709 46,579 December 642,055 271,041 315,311 4,309 51,394

January 677,117 285,194 335,785 5,065 51,072 February 672,278 274,977 343,616 4,955 48,730 March 703,533 295,548 354,510 5,129 48,345

April 741,560 321,202 367,445 5,044 47,869 May 843,383 376,968 407,974 5,263 53,180 June 912,469 403,071 448,815 5,838 54,745

July 1,118,369 492,043 559,652 7,312 59,363 August 1,038,691 447,137 526,648 5,924 58,982 September 835,109 358,829 417,952 5,014 53,314 October 700,348 304,811 339,272 4,621 51,645 November 611,680 265,122 290,769 4,472 51,317 December 630,173 277,026 293,821 4,479 54,847 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.4.A. Natural Gas: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Million Cubic Feet) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 860,024 0 263,619 41,435 554,970 2003 721,267 0 225,967 19,973 475,327 2004 1,052,100 0 388,424 39,233 624,443 2005 984,340 0 384,365 34,172 565,803 2006 942,817 0 330,878 33,112 578,828 2007 872,579 0 339,796 35,987 496,796 2008 793,537 0 326,048 32,813 434,676 2009 816,787 0 305,542 41,275 469,970 2010 821,775 0 301,769 46,324 473,683 2011 839,681 0 308,669 39,856 491,155 2012 886,103 0 322,607 47,883 515,613

January 72,867 0 26,791 4,086 41,990 February 64,030 0 23,665 3,731 36,634 March 68,097 0 25,259 3,612 39,225

April 62,604 0 22,596 3,279 36,729 May 64,675 0 24,150 3,079 37,446 June 64,855 0 24,210 3,254 37,391

July 74,050 0 28,575 4,452 41,023 August 74,748 0 27,921 4,955 41,872 September 67,954 0 25,235 4,034 38,685 October 67,393 0 23,073 3,960 40,361 November 66,220 0 23,851 3,786 38,583 December 74,282 0 26,442 4,096 43,744

January 72,765 0 27,509 3,590 41,667 February 65,092 0 24,322 2,962 37,808 March 66,500 0 24,958 2,875 38,666

April 64,265 0 23,687 2,685 37,894 May 67,344 0 24,178 3,047 40,119 June 66,791 0 24,165 2,912 39,714

July 77,883 0 29,452 3,910 44,520 August 78,356 0 28,864 3,877 45,616 September 70,438 0 25,286 3,339 41,812 October 66,780 0 23,880 3,155 39,744 November 67,698 0 24,826 3,422 39,450 December 75,769 0 27,542 4,083 44,145

January 75,174 0 27,843 4,072 43,259 February 69,960 0 25,937 3,869 40,154 March 70,324 0 24,040 3,743 42,542

April 71,587 0 25,691 3,484 42,412 May 72,877 0 27,525 3,543 41,808 June 74,822 0 27,995 3,799 43,028

July 82,618 0 29,994 4,798 47,827 August 80,621 0 30,153 4,661 45,807 September 72,357 0 25,807 4,292 42,258 October 70,985 0 25,112 4,005 41,867 November 69,240 0 23,855 3,809 41,577 December 75,537 0 28,655 3,809 43,073 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.4.B. Natural Gas: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Million Cubic Feet) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 6,986,087 2,259,684 3,412,213 73,980 1,240,209 2003 6,337,402 1,763,764 3,371,452 58,453 1,143,734 2004 6,726,679 1,809,443 3,654,320 72,072 1,190,844 2005 7,020,709 2,134,859 3,734,286 67,957 1,083,607 2006 7,404,432 2,478,396 3,743,704 67,735 1,114,597 2007 7,961,922 2,736,418 4,104,991 70,074 1,050,439 2008 7,689,380 2,730,134 3,938,245 66,216 954,785 2009 7,937,856 2,911,279 3,961,254 75,555 989,769 2010 8,501,960 3,290,993 4,096,192 85,786 1,028,990 2011 8,723,546 3,446,087 4,127,777 87,026 1,062,657 2012 10,370,812 4,101,927 5,008,867 110,999 1,149,020

January 643,072 244,970 300,842 7,248 90,013 February 565,820 211,934 267,681 6,626 79,580 March 546,948 207,974 248,889 6,584 83,501

April 556,192 210,270 261,212 5,988 78,722 May 646,962 261,882 297,782 5,740 81,557 June 796,212 314,471 391,194 6,185 84,362

July 996,697 387,996 509,185 8,111 91,405 August 1,046,602 411,663 531,340 8,801 94,799 September 791,184 306,156 390,566 7,481 86,980 October 661,732 260,110 310,253 7,431 83,937 November 585,595 219,357 277,182 7,131 81,924 December 664,945 254,209 310,065 8,461 92,210

January 636,477 238,731 301,061 7,108 89,577 February 570,218 208,813 274,873 6,032 80,500 March 569,590 217,538 264,388 6,044 81,620

April 610,190 243,866 277,587 5,747 82,990 May 666,033 268,818 303,180 7,090 86,945 June 793,979 330,305 369,109 6,869 87,696

July 1,045,008 430,187 508,388 9,226 97,207 August 1,029,781 421,042 500,407 8,878 99,454 September 782,418 306,699 377,499 7,629 90,591 October 666,323 266,740 308,192 6,882 84,509 November 635,705 242,306 300,240 7,130 86,029 December 717,824 271,041 342,852 8,392 95,539

January 752,291 285,194 363,628 9,137 94,331 February 742,237 274,977 369,553 8,824 88,883 March 773,857 295,548 378,550 8,872 90,887

April 813,147 321,202 393,136 8,528 90,281 May 916,260 376,968 435,499 8,806 94,988 June 987,291 403,071 476,810 9,637 97,774

July 1,200,988 492,043 589,645 12,110 107,190 August 1,119,312 447,137 556,802 10,585 104,789 September 907,466 358,829 443,759 9,306 95,572 October 771,333 304,811 364,384 8,626 93,512 November 680,920 265,122 314,624 8,281 92,894 December 705,710 277,026 322,476 8,288 97,920 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.4.C. Natural Gas: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Million Cubic Feet) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 6,249,585 2,307,358 3,214,286 30,626 697,315 2003 5,735,770 1,809,003 3,200,057 39,424 687,286 2004 5,827,470 1,857,247 3,351,469 33,623 585,132 2005 6,212,116 2,198,098 3,444,875 34,645 534,498 2006 6,643,926 2,546,169 3,508,597 35,473 553,687 2007 7,287,714 2,808,500 3,872,646 34,872 571,697 2008 7,087,191 2,803,283 3,712,872 34,138 536,899 2009 7,301,522 2,981,285 3,750,080 35,046 535,111 2010 7,852,665 3,359,035 3,882,995 40,356 570,279 2011 8,052,309 3,511,732 3,906,484 48,509 585,584 2012 9,696,575 4,179,725 4,802,741 64,987 649,122

January 582,992 249,924 280,499 3,235 49,335 February 513,087 216,353 249,652 2,960 44,121 March 489,636 212,288 228,811 3,036 45,501

April 504,598 214,384 244,312 2,767 43,135 May 595,320 267,066 280,193 2,712 45,348 June 747,778 320,923 375,608 2,994 48,253

July 943,538 396,426 491,656 3,742 51,714 August 993,608 420,430 514,923 3,937 54,318 September 740,053 312,993 373,945 3,526 49,589 October 608,011 265,734 294,030 3,549 44,699 November 530,776 223,630 259,174 3,423 44,549 December 603,269 258,885 290,192 4,476 49,717

January 575,521 243,212 279,664 3,624 49,021 February 516,427 212,934 256,497 3,160 43,836 March 513,724 221,498 244,797 3,258 44,171

April 557,693 248,459 259,863 3,145 46,225 May 611,133 273,835 285,175 4,157 47,965 June 742,708 336,934 352,589 4,066 49,119

July 987,734 438,636 489,752 5,457 53,889 August 972,096 429,646 482,196 5,139 55,114 September 727,690 312,770 360,489 4,416 50,015 October 612,031 271,503 290,845 3,834 45,849 November 579,856 246,548 281,804 3,817 47,686 December 655,696 275,756 322,811 4,435 52,694

January 691,050 289,886 343,654 5,205 52,306 February 686,769 279,714 352,021 5,096 49,939 March 718,581 300,651 363,088 5,277 49,565

April 757,509 327,112 376,092 5,194 49,111 May 861,735 383,976 417,780 5,406 54,573 June 933,301 411,234 459,926 6,014 56,127

July 1,143,646 502,138 573,074 7,541 60,893 August 1,062,885 456,248 540,239 6,106 60,293 September 854,055 365,700 428,593 5,167 54,595 October 716,356 310,484 348,176 4,757 52,940 November 625,552 270,068 298,319 4,610 52,555 December 645,135 282,515 301,780 4,616 56,225 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.4.D. Natural Gas: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 885,987 0 267,675 45,359 572,953 2003 762,779 0 250,120 21,238 491,421 2004 1,085,191 0 398,476 40,122 646,593 2005 1,008,404 0 392,842 35,037 580,525 2006 968,574 0 339,047 33,928 595,599 2007 894,272 0 347,181 36,689 510,402 2008 813,794 0 333,197 33,434 447,163 2009 836,863 0 312,553 42,032 482,279 2010 841,521 0 308,246 47,001 486,274 2011 861,006 0 315,411 40,976 504,619 2012 909,087 0 330,354 48,944 529,788

January 74,586 0 27,368 4,148 43,070 February 65,539 0 24,180 3,786 37,573 March 69,750 0 25,816 3,663 40,270

April 64,065 0 23,082 3,330 37,653 May 66,246 0 24,669 3,123 38,454 June 66,468 0 24,772 3,299 38,397

July 75,860 0 29,233 4,514 42,113 August 76,582 0 28,502 5,026 43,054 September 69,610 0 25,767 4,098 39,745 October 68,953 0 23,523 4,017 41,413 November 67,772 0 24,329 3,839 39,604 December 76,091 0 27,005 4,158 44,928

January 74,528 0 28,057 3,686 42,785 February 66,742 0 24,863 3,042 38,837 March 68,226 0 25,457 2,958 39,812

April 65,865 0 24,174 2,759 38,932 May 69,019 0 24,680 3,131 41,208 June 68,611 0 24,792 2,993 40,826

July 79,769 0 30,061 4,015 45,693 August 80,249 0 29,349 3,988 46,912 September 72,408 0 25,930 3,442 43,036 October 68,525 0 24,469 3,248 40,808 November 69,359 0 25,380 3,518 40,461 December 77,705 0 28,198 4,198 45,309

January 77,111 0 28,515 4,162 44,434 February 71,774 0 26,572 3,955 41,247 March 72,137 0 24,594 3,827 43,717

April 73,470 0 26,290 3,562 43,618 May 74,851 0 28,159 3,622 43,070 June 76,791 0 28,666 3,882 44,244

July 84,854 0 30,691 4,900 49,264 August 82,540 0 30,883 4,761 46,896 September 74,228 0 26,494 4,385 43,349 October 72,830 0 25,759 4,098 42,973 November 71,018 0 24,394 3,894 42,730 December 77,481 0 29,336 3,897 44,247 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.4.E. Natural Gas: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 7,135,572 2,307,358 3,481,961 75,985 1,270,268 2003 6,498,549 1,809,003 3,450,177 60,662 1,178,707 2004 6,912,661 1,857,247 3,749,945 73,744 1,231,725 2005 7,220,520 2,198,098 3,837,717 69,682 1,115,023 2006 7,612,500 2,546,169 3,847,644 69,401 1,149,286 2007 8,181,986 2,808,500 4,219,827 71,560 1,082,099 2008 7,900,986 2,803,283 4,046,069 67,571 984,062 2009 8,138,385 2,981,285 4,062,633 77,077 1,017,390 2010 8,694,186 3,359,035 4,191,241 87,357 1,056,553 2011 8,913,315 3,511,732 4,221,895 89,485 1,090,203 2012 10,605,661 4,179,725 5,133,095 113,932 1,178,910

January 657,578 249,924 307,867 7,383 92,404 February 578,625 216,353 273,832 6,746 81,695 March 559,386 212,288 254,627 6,700 85,771

April 568,662 214,384 267,394 6,096 80,788 May 661,566 267,066 304,862 5,835 83,803 June 814,246 320,923 400,380 6,293 86,650

July 1,019,398 396,426 520,890 8,255 93,827 August 1,070,189 420,430 543,425 8,963 97,372 September 809,663 312,993 399,713 7,624 89,334 October 676,965 265,734 317,553 7,566 86,112 November 598,548 223,630 283,503 7,262 84,153 December 679,360 258,885 317,197 8,634 94,645

January 650,049 243,212 307,721 7,310 91,806 February 583,169 212,934 281,360 6,203 82,672 March 581,951 221,498 270,254 6,216 83,983

April 623,558 248,459 284,037 5,904 85,157 May 680,152 273,835 309,856 7,288 89,173 June 811,319 336,934 377,381 7,059 89,945

July 1,067,503 438,636 519,813 9,472 99,582 August 1,052,345 429,646 511,546 9,127 102,026 September 800,097 312,770 386,419 7,857 93,051 October 680,557 271,503 315,315 7,081 86,658 November 649,215 246,548 307,185 7,336 88,147 December 733,401 275,756 351,009 8,632 98,003

January 768,162 289,886 372,169 9,367 96,740 February 758,544 279,714 378,593 9,050 91,186 March 790,718 300,651 387,681 9,103 93,282

April 830,979 327,112 402,382 8,756 92,729 May 936,586 383,976 445,939 9,028 97,643 June 1,010,092 411,234 488,592 9,896 100,371

July 1,228,500 502,138 603,765 12,440 110,157 August 1,145,425 456,248 571,122 10,867 107,189 September 928,283 365,700 455,087 9,552 97,943 October 789,186 310,484 373,935 8,854 95,913 November 696,571 270,068 322,713 8,505 95,285 December 722,616 282,515 331,117 8,512 100,472 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.4.F. Natural Gas: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 605,054 10,659 129,947 469 463,980 2003 519,294 16,545 139,852 437 362,460 2004 344,134 19,973 130,248 168 193,745 2005 355,250 27,373 138,407 207 189,263 2006 350,074 27,455 135,546 269 186,803 2007 353,025 31,568 132,953 284 188,220 2008 338,786 29,150 130,122 287 179,227 2009 320,444 29,565 130,894 274 159,712 2010 349,530 40,167 137,072 274 172,016 2011 347,623 35,474 130,108 482 181,559 2012 390,342 32,723 138,217 478 218,924

January 29,578 3,731 11,954 23 13,870 February 27,768 3,305 11,335 21 13,107 March 28,852 2,991 11,797 22 14,041

April 27,499 3,043 10,463 22 13,971 May 26,790 2,867 10,173 22 13,728 June 29,061 3,304 11,354 23 14,380

July 30,802 3,533 12,297 24 14,948 August 31,578 3,630 12,793 24 15,131 September 29,522 3,322 11,298 23 14,879 October 27,669 2,857 10,511 22 14,279 November 29,313 3,793 11,044 23 14,452 December 31,099 3,790 12,052 25 15,231

January 30,922 3,447 11,785 45 15,646 February 27,914 3,268 10,751 58 13,837 March 28,821 3,307 10,692 39 14,783

April 25,010 2,086 8,705 38 14,182 May 25,819 2,213 9,641 32 13,933 June 29,975 3,118 11,126 41 15,690

July 31,289 3,345 12,173 48 15,724 August 31,729 3,661 12,097 43 15,928 September 29,534 3,116 10,967 34 15,417 October 27,245 2,722 9,960 23 14,540 November 27,979 2,117 10,322 34 15,506 December 31,385 3,075 11,889 47 16,375

January 34,582 3,060 12,146 42 19,335 February 32,667 2,920 11,556 40 18,152 March 31,023 2,446 11,529 36 17,012

April 28,062 1,735 9,538 35 16,753 May 30,164 2,751 9,882 33 17,498 June 32,221 2,410 12,170 39 17,601

July 34,692 2,874 13,217 47 18,554 August 35,328 3,246 12,839 49 19,194 September 33,051 2,732 12,158 32 18,129 October 31,734 2,305 11,054 25 18,350 November 32,205 3,013 10,566 48 18,578 December 34,612 3,232 11,560 52 19,769 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.5.D. Wood / Wood Waste Biomass: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 682,060 0 9,585 727 671,747 2003 746,375 0 10,893 762 734,720 2004 1,016,124 0 14,968 1,493 999,663 2005 997,331 0 19,193 1,028 977,111 2006 1,049,161 0 18,814 1,045 1,029,303 2007 982,486 0 21,435 1,756 959,296 2008 923,889 0 18,075 1,123 904,690 2009 816,285 0 19,587 1,135 795,563 2010 876,041 0 18,357 1,064 856,620 2011 893,314 0 16,577 1,022 875,716 2012 883,158 0 19,251 949 862,958

January 73,418 0 1,677 91 71,651 February 67,994 0 1,689 81 66,224 March 74,187 0 1,656 86 72,446

April 70,163 0 1,371 85 68,707 May 70,816 0 1,230 87 69,499 June 71,919 0 1,547 88 70,284

July 74,173 0 1,444 95 72,634 August 74,762 0 1,573 93 73,096 September 73,935 0 1,447 86 72,402 October 73,817 0 1,617 85 72,115 November 73,041 0 1,460 91 71,490 December 77,815 0 1,647 96 76,072

January 80,138 0 1,676 91 78,371 February 70,603 0 1,528 79 68,996 March 75,045 0 1,293 74 73,678

April 70,916 0 1,159 107 69,650 May 69,518 0 1,327 83 68,108 June 74,262 0 1,390 96 72,776

July 75,431 0 1,443 106 73,882 August 75,179 0 1,411 84 73,684 September 74,155 0 1,409 70 72,676 October 72,932 0 1,358 52 71,522 November 75,474 0 1,228 82 74,164 December 79,660 0 1,354 99 78,207

January 75,884 0 1,631 78 74,175 February 71,356 0 1,551 77 69,729 March 72,102 0 1,631 68 70,403

April 68,208 0 1,434 81 66,693 May 72,744 0 1,385 67 71,293 June 72,221 0 1,797 89 70,335

July 74,756 0 1,645 92 73,019 August 75,527 0 1,845 88 73,594 September 74,208 0 1,600 77 72,531 October 74,164 0 1,747 76 72,342 November 74,571 0 1,440 81 73,050 December 77,417 0 1,547 77 75,794 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.5.E. Wood / Wood Waste Biomass: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2002 1,287,114 10,659 139,532 1,196 1,135,727 2003 1,265,669 16,545 150,745 1,199 1,097,180 2004 1,360,258 19,973 145,216 1,661 1,193,408 2005 1,352,582 27,373 157,600 1,235 1,166,373 2006 1,399,235 27,455 154,360 1,314 1,216,106 2007 1,335,511 31,568 154,388 2,040 1,147,516 2008 1,262,675 29,150 148,198 1,410 1,083,917 2009 1,136,729 29,565 150,481 1,408 955,276 2010 1,225,571 40,167 155,429 1,338 1,028,637 2011 1,240,937 35,474 146,684 1,504 1,057,275 2012 1,273,500 32,723 157,468 1,427 1,081,882

January 102,997 3,731 13,630 114 85,521 February 95,763 3,305 13,024 101 79,332 March 103,039 2,991 13,453 108 86,487

April 97,662 3,043 11,834 107 82,678 May 97,606 2,867 11,403 110 83,227 June 100,980 3,304 12,901 111 84,664

July 104,975 3,533 13,741 119 87,582 August 106,340 3,630 14,366 117 88,226 September 103,457 3,322 12,745 109 87,280 October 101,485 2,857 12,128 106 86,394 November 102,353 3,793 12,504 114 85,942 December 108,914 3,790 13,700 120 91,303

January 111,060 3,447 13,461 135 94,017 February 98,517 3,268 12,279 137 82,833 March 103,866 3,307 11,985 113 88,461

April 95,927 2,086 9,863 145 83,832 May 95,337 2,213 10,968 115 82,041 June 104,237 3,118 12,516 136 88,466

July 106,720 3,345 13,615 155 89,606 August 106,908 3,661 13,508 128 89,611 September 103,689 3,116 12,376 104 88,093 October 100,177 2,722 11,318 75 86,062 November 103,453 2,117 11,550 116 89,670 December 111,046 3,075 13,244 145 94,582

January 110,466 3,060 13,777 120 93,509 February 104,023 2,920 13,106 117 87,880 March 103,126 2,446 13,161 103 87,415

April 96,270 1,735 10,972 116 83,446 May 102,908 2,751 11,267 100 88,791 June 104,442 2,410 13,967 128 87,936

July 109,448 2,874 14,862 139 91,573 August 110,856 3,246 14,685 138 92,788 September 107,259 2,732 13,758 109 90,660 October 105,898 2,305 12,801 101 90,691 November 106,776 3,013 12,006 129 91,628 December 112,030 3,232 13,106 129 95,563 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report. 

### Table 5.5.F. Wood / Wood Waste Biomass: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 136,421 9,168 121,984 3,280 1,989 2004 143,844 11,250 125,848 4,081 2,665 2005 141,899 11,490 123,064 4,797 2,548 2006 160,033 16,617 136,108 6,644 664 2007 166,774 17,442 144,104 4,598 630 2008 195,777 20,465 169,547 5,235 530 2009 206,792 19,583 180,689 5,931 589 2010 218,331 19,975 192,428 5,535 393 2011 232,795 22,086 180,856 29,469 384 2012 256,376 25,193 201,965 26,672 2,545

January 17,531 1,715 15,323 461 32 February 16,189 1,653 14,120 384 33 March 18,642 1,988 16,174 439 40

April 17,885 1,673 15,706 467 40 May 17,830 1,675 15,684 432 39 June 18,745 1,676 16,564 471 35

July 18,666 1,633 16,516 486 31 August 18,811 1,626 16,659 493 33 September 18,537 1,602 16,446 455 35 October 17,561 1,582 15,479 475 25 November 18,710 1,558 16,632 496 23 December 19,224 1,596 17,125 477 26

January 18,885 1,725 14,677 2,454 30 February 17,636 1,598 13,612 2,400 26 March 19,016 1,703 14,660 2,626 28

April 17,861 1,677 13,752 2,402 30 May 18,908 1,728 14,628 2,518 33 June 19,707 1,755 15,382 2,535 35

July 20,419 1,841 15,878 2,667 33 August 20,779 1,965 16,090 2,687 37 September 19,319 1,730 15,116 2,440 33 October 19,291 2,137 14,995 2,126 32 November 20,227 2,107 15,817 2,267 36 December 20,747 2,120 16,249 2,347 32

January 21,454 1,889 16,999 2,352 214 February 19,337 1,833 15,100 2,200 205 March 20,905 1,976 16,543 2,177 208

April 20,015 2,064 15,557 2,184 210 May 21,031 2,214 16,427 2,177 213 June 20,722 2,082 16,315 2,120 206

July 22,294 2,282 17,649 2,141 221 August 22,490 2,316 17,672 2,293 210 September 21,151 2,055 16,702 2,208 185 October 22,392 2,264 17,625 2,292 211 November 21,528 2,102 16,887 2,317 223 December 23,056 2,115 18,488 2,213 240 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.6.A. Landfill Gas: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Million Cubic Feet) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 993 0 116 0 876 2004 2,174 0 735 10 1,429 2005 1,923 0 965 435 522 2006 2,051 0 525 1,094 433 2007 1,988 0 386 1,102 501 2008 1,025 0 454 433 138 2009 793 0 545 176 72 2010 1,623 0 1,195 370 58 2011 3,195 0 2,753 351 91 2012 3,189 0 2,788 340 61

January 118 0 83 30 5 February 110 0 79 27 5 March 132 0 94 32 6

April 131 0 93 33 6 May 132 0 92 34 6 June 139 0 104 30 5

July 140 0 102 33 5 August 132 0 95 32 5 September 148 0 113 30 5 October 143 0 111 29 4 November 136 0 101 32 3 December 162 0 130 28 4

January 312 0 276 29 7 February 280 0 246 28 6 March 274 0 237 31 6

April 239 0 203 29 7 May 238 0 200 30 8 June 246 0 209 29 8

July 252 0 217 28 8 August 282 0 245 28 9 September 281 0 244 30 8 October 307 0 266 33 8 November 171 0 132 30 8 December 313 0 279 26 7

January 307 0 272 31 4 February 292 0 258 29 4 March 243 0 209 30 5

April 254 0 221 28 5 May 265 0 230 29 5 June 212 0 179 28 5

July 295 0 260 29 6 August 260 0 229 25 6 September 285 0 256 24 5 October 299 0 265 28 6 November 186 0 149 32 5 December 291 0 260 27 5 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.6.B. Landfill Gas: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Million Cubic Feet) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 137,414 9,168 122,100 3,280 2,865 2004 146,018 11,250 126,584 4,091 4,093 2005 143,822 11,490 124,030 5,232 3,070 2006 162,084 16,617 136,632 7,738 1,096 2007 168,762 17,442 144,490 5,699 1,131 2008 196,802 20,465 170,001 5,668 668 2009 207,585 19,583 181,234 6,106 661 2010 219,954 19,975 193,623 5,905 451 2011 235,990 22,086 183,609 29,820 474 2012 259,564 25,193 204,753 27,012 2,606

January 17,649 1,715 15,406 491 37 February 16,300 1,653 14,198 410 38 March 18,774 1,988 16,268 471 46

April 18,017 1,673 15,798 499 46 May 17,961 1,675 15,776 466 44 June 18,884 1,676 16,667 501 40

July 18,805 1,633 16,618 519 36 August 18,943 1,626 16,754 525 38 September 18,686 1,602 16,559 485 40 October 17,705 1,582 15,590 504 29 November 18,846 1,558 16,733 528 27 December 19,386 1,596 17,255 505 30

January 19,197 1,725 14,952 2,483 37 February 17,916 1,598 13,858 2,428 32 March 19,290 1,703 14,897 2,656 34

April 18,100 1,677 13,954 2,431 37 May 19,146 1,728 14,829 2,548 41 June 19,954 1,755 15,592 2,564 43

July 20,672 1,841 16,095 2,695 40 August 21,061 1,965 16,335 2,715 46 September 19,600 1,730 15,360 2,470 41 October 19,597 2,137 15,261 2,159 40 November 20,398 2,107 15,949 2,298 45 December 21,060 2,120 16,527 2,374 39

January 21,761 1,889 17,271 2,382 218 February 19,629 1,833 15,358 2,229 209 March 21,149 1,976 16,752 2,207 213

April 20,269 2,064 15,777 2,212 216 May 21,295 2,214 16,658 2,206 218 June 20,934 2,082 16,494 2,147 211

July 22,588 2,282 17,909 2,170 227 August 22,750 2,316 17,901 2,317 216 September 21,436 2,055 16,958 2,232 190 October 22,691 2,264 17,890 2,320 217 November 21,714 2,102 17,036 2,349 227 December 23,347 2,115 18,747 2,240 245 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.6.C. Landfill Gas: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Million Cubic Feet) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 65,770 3,930 59,089 1,753 998 2004 69,331 5,373 60,514 2,093 1,351 2005 67,902 5,650 58,624 2,360 1,269 2006 75,970 8,287 63,950 3,388 345 2007 79,712 8,620 68,432 2,344 316 2008 94,215 10,242 81,029 2,668 276 2009 99,821 9,748 86,773 2,999 301 2010 105,835 10,029 92,763 2,837 205 2011 112,538 11,146 89,857 11,332 203 2012 124,297 12,721 99,938 10,356 1,282

January 8,441 853 7,335 236 17 February 7,824 830 6,781 197 17 March 9,056 1,013 7,796 226 21

April 8,689 848 7,581 239 21 May 8,694 850 7,603 220 20 June 9,137 849 8,028 241 18

July 9,028 814 7,949 249 16 August 9,117 809 8,039 252 17 September 8,989 800 7,938 233 18 October 8,494 793 7,444 244 13 November 9,054 780 8,007 255 12 December 9,312 790 8,263 245 14

January 9,090 862 7,268 943 16 February 8,461 801 6,752 893 14 March 9,138 858 7,279 987 15

April 8,588 836 6,851 886 16 May 9,079 861 7,261 940 18 June 9,517 873 7,656 970 18

July 9,864 929 7,900 1,018 17 August 10,041 986 8,007 1,029 20 September 9,368 866 7,520 964 17 October 9,420 1,095 7,438 870 17 November 9,867 1,091 7,853 903 19 December 10,105 1,086 8,073 929 17

January 10,348 952 8,394 895 108 February 9,312 929 7,443 837 103 March 10,118 992 8,185 836 105

April 9,693 1,052 7,694 840 106 May 10,200 1,117 8,135 840 107 June 10,069 1,051 8,092 823 104

July 10,872 1,160 8,757 843 111 August 10,929 1,163 8,757 904 106 September 10,264 1,043 8,269 858 93 October 10,871 1,145 8,729 890 106 November 10,412 1,052 8,344 904 112 December 11,208 1,065 9,138 885 121 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.6.D. Landfill Gas: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 500 0 61 0 439 2004 1,158 0 415 5 738 2005 994 0 519 212 263 2006 1,034 0 267 549 218 2007 985 0 226 532 228 2008 552 0 271 211 70 2009 440 0 313 91 37 2010 847 0 643 174 30 2011 1,635 0 1,422 165 48 2012 1,630 0 1,441 156 32

January 61 0 44 14 3 February 58 0 42 13 3 March 67 0 49 15 3

April 67 0 49 15 3 May 68 0 49 16 3 June 73 0 56 14 3

July 73 0 55 16 2 August 69 0 52 15 3 September 79 0 62 14 3 October 75 0 59 14 2 November 71 0 55 15 2 December 87 0 71 13 2

January 160 0 142 14 4 February 143 0 127 13 3 March 141 0 123 14 3

April 123 0 105 14 4 May 122 0 104 14 4 June 126 0 108 14 4

July 129 0 112 13 4 August 145 0 127 13 5 September 144 0 126 14 4 October 157 0 138 15 4 November 86 0 67 14 5 December 160 0 144 12 4

January 157 0 141 14 2 February 149 0 133 14 2 March 124 0 108 14 2

April 130 0 114 13 3 May 136 0 119 13 3 June 108 0 92 13 3

July 151 0 134 13 3 August 133 0 118 11 3 September 146 0 132 11 3 October 153 0 137 13 3 November 94 0 77 15 2 December 149 0 134 12 3 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.6.E. Landfill Gas: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 66,270 3,930 59,149 1,753 1,438 2004 70,489 5,373 60,929 2,098 2,089 2005 68,897 5,650 59,144 2,571 1,532 2006 77,004 8,287 64,217 3,937 563 2007 80,697 8,620 68,657 2,875 544 2008 94,768 10,242 81,300 2,879 346 2009 100,261 9,748 87,086 3,089 337 2010 106,681 10,029 93,405 3,011 236 2011 114,173 11,146 91,279 11,497 251 2012 125,927 12,721 101,379 10,512 1,315

January 8,502 853 7,379 251 19 February 7,882 830 6,823 209 20 March 9,123 1,013 7,845 241 24

April 8,756 848 7,630 254 24 May 8,762 850 7,652 236 23 June 9,210 849 8,084 255 21

July 9,101 814 8,004 264 19 August 9,186 809 8,090 268 20 September 9,068 800 8,000 247 21 October 8,568 793 7,503 258 15 November 9,126 780 8,062 270 14 December 9,399 790 8,334 258 16

January 9,250 862 7,411 957 20 February 8,604 801 6,879 907 17 March 9,278 858 7,401 1,001 18

April 8,711 836 6,956 899 19 May 9,201 861 7,365 954 22 June 9,644 873 7,764 983 23

July 9,993 929 8,012 1,031 21 August 10,186 986 8,133 1,042 24 September 9,512 866 7,646 978 22 October 9,577 1,095 7,575 885 21 November 9,953 1,091 7,921 918 24 December 10,265 1,086 8,216 942 21

January 10,505 952 8,535 909 110 February 9,461 929 7,577 851 105 March 10,243 992 8,293 850 107

April 9,823 1,052 7,809 853 109 May 10,335 1,117 8,255 854 110 June 10,177 1,051 8,184 836 106

July 11,022 1,160 8,892 856 115 August 11,062 1,163 8,875 915 109 September 10,410 1,043 8,401 869 96 October 11,024 1,145 8,866 903 109 November 10,507 1,052 8,421 919 114 December 11,357 1,065 9,272 897 123 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.6.F. Landfill Gas: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 21,196 695 18,300 2,087 115 2004 19,587 444 17,308 1,811 24 2005 19,370 560 17,033 1,753 25 2006 19,629 500 17,343 1,761 25 2007 19,576 553 17,116 1,785 122 2008 19,805 509 17,487 1,809 0 2009 19,669 465 17,048 2,155 0 2010 19,437 402 16,802 2,233 0 2011 16,972 388 14,625 1,955 4 2012 16,968 418 14,235 2,304 12

January 1,546 30 1,332 184 0 February 1,384 25 1,215 144 0 March 1,650 36 1,434 180 0

April 1,655 33 1,426 196 0 May 1,692 33 1,454 204 0 June 1,674 36 1,442 196 0

July 1,697 37 1,472 188 0 August 1,689 37 1,452 201 0 September 1,609 32 1,383 194 0 October 1,602 35 1,388 179 0 November 1,599 34 1,383 182 0 December 1,639 33 1,421 185 0

January 1,282 26 1,100 156 0 February 1,206 23 1,046 136 0 March 1,412 29 1,229 154 0

April 1,387 31 1,201 156 0 May 1,440 36 1,227 177 0 June 1,482 38 1,274 170 0

July 1,514 36 1,305 173 1 August 1,481 37 1,274 170 1 September 1,429 36 1,226 166 1 October 1,445 34 1,241 169 1 November 1,422 30 1,226 165 1 December 1,472 31 1,275 164 1

January 1,361 30 1,147 183 1 February 1,274 27 1,067 179 1 March 1,380 36 1,151 192 0

April 1,362 38 1,134 189 1 May 1,485 41 1,235 207 1 June 1,473 37 1,238 196 1

July 1,519 35 1,284 199 1 August 1,468 40 1,232 195 1 September 1,389 30 1,161 197 1 October 1,407 38 1,174 194 1 November 1,398 34 1,180 182 1 December 1,454 31 1,231 190 1 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.7.A. Biogenic Municipal Solid Waste: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 1,358 0 311 865 182 2004 2,743 0 651 1,628 464 2005 2,719 0 623 1,536 560 2006 2,840 0 725 1,595 520 2007 2,219 0 768 1,136 315 2008 2,328 0 806 1,514 8 2009 2,426 0 823 1,466 137 2010 2,287 0 819 1,316 152 2011 2,044 0 742 1,148 154 2012 1,986 0 522 1,273 190

January 191 0 69 107 14 February 178 0 61 106 11 March 204 0 66 126 12

April 207 0 67 127 13 May 249 0 67 167 15 June 204 0 69 120 14

July 194 0 68 115 11 August 198 0 66 118 14 September 177 0 67 99 11 October 163 0 69 83 11 November 155 0 74 68 14 December 167 0 76 80 11

January 158 0 73 79 6 February 146 0 62 78 6 March 167 0 68 86 12

April 146 0 48 86 12 May 175 0 69 92 13 June 177 0 63 101 12

July 167 0 60 95 12 August 185 0 58 110 17 September 180 0 62 102 16 October 174 0 61 96 18 November 187 0 56 114 17 December 181 0 61 107 13

January 162 0 42 105 15 February 154 0 40 98 15 March 176 0 61 100 15

April 163 0 43 104 17 May 163 0 39 106 18 June 158 0 39 102 16

July 168 0 40 113 15 August 173 0 42 115 16 September 166 0 46 104 16 October 177 0 46 114 17 November 156 0 44 98 14 December 170 0 41 114 15 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.7.B. Biogenic Municipal Solid Waste: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 22,554 695 18,611 2,952 296 2004 22,330 444 17,959 3,439 488 2005 22,089 560 17,655 3,289 584 2006 22,469 500 18,068 3,356 545 2007 21,796 553 17,885 2,921 437 2008 22,134 509 18,294 3,323 8 2009 22,095 465 17,872 3,622 137 2010 21,725 402 17,621 3,549 152 2011 19,016 388 15,367 3,103 158 2012 18,954 418 14,757 3,577 203

January 1,737 30 1,402 291 14 February 1,562 25 1,276 250 11 March 1,854 36 1,500 306 12

April 1,862 33 1,492 323 13 May 1,940 33 1,521 371 15 June 1,878 36 1,512 316 14

July 1,891 37 1,540 303 11 August 1,887 37 1,518 318 14 September 1,787 32 1,451 293 11 October 1,765 35 1,456 262 11 November 1,755 34 1,457 250 14 December 1,807 33 1,497 265 11

January 1,441 26 1,173 235 6 February 1,352 23 1,108 214 6 March 1,579 29 1,298 240 12

April 1,534 31 1,248 242 12 May 1,615 36 1,296 270 13 June 1,659 38 1,338 271 12

July 1,681 36 1,365 268 13 August 1,667 37 1,332 279 18 September 1,609 36 1,288 268 16 October 1,619 34 1,302 265 18 November 1,609 30 1,283 279 17 December 1,653 31 1,336 272 14

January 1,523 30 1,189 288 16 February 1,427 27 1,106 278 16 March 1,557 36 1,212 293 15

April 1,525 38 1,177 293 18 May 1,648 41 1,274 313 20 June 1,631 37 1,277 299 18

July 1,688 35 1,325 311 16 August 1,641 40 1,274 310 17 September 1,555 30 1,207 301 18 October 1,583 38 1,220 308 18 November 1,554 34 1,224 280 15 December 1,623 31 1,272 304 16 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.7.C. Biogenic Municipal Solid Waste: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Thousand Tons) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 148,110 5,766 128,947 13,095 302 2004 141,577 3,705 124,815 12,909 146 2005 144,339 4,724 126,529 12,923 164 2006 146,987 4,078 129,779 12,964 165 2007 146,308 4,557 127,826 13,043 881 2008 148,452 4,476 130,041 13,934 0 2009 146,971 3,989 126,649 16,333 0 2010 144,934 3,322 124,437 17,176 0 2011 135,241 3,433 115,841 15,933 34 2012 135,735 3,910 113,418 18,307 100

January 11,540 244 9,886 1,410 0 February 10,313 190 9,030 1,094 0 March 12,214 293 10,555 1,366 0

April 12,384 276 10,586 1,522 0 May 12,645 278 10,780 1,587 0 June 12,471 297 10,668 1,506 0

July 12,593 308 10,840 1,444 0 August 12,572 309 10,730 1,534 0 September 11,988 261 10,229 1,498 0 October 11,979 297 10,297 1,385 0 November 11,964 294 10,268 1,403 0 December 12,269 275 10,567 1,428 0

January 10,271 231 8,780 1,260 0 February 9,567 207 8,254 1,106 0 March 11,176 256 9,690 1,231 0

April 11,046 277 9,496 1,273 0 May 11,442 319 9,685 1,438 0 June 11,809 336 10,079 1,395 0

July 12,098 313 10,338 1,441 5 August 11,731 326 10,033 1,365 7 September 11,301 316 9,652 1,327 5 October 11,551 304 9,850 1,392 5 November 11,424 266 9,798 1,355 6 December 11,825 282 10,186 1,351 6

January 10,943 271 9,208 1,455 9 February 10,284 261 8,563 1,455 5 March 11,022 317 9,169 1,532 4

April 10,986 390 9,060 1,527 8 May 11,856 427 9,792 1,627 10 June 11,681 318 9,813 1,542 8

July 12,107 332 10,184 1,583 8 August 11,638 350 9,728 1,551 10 September 11,021 286 9,181 1,544 9 October 11,242 348 9,346 1,540 9 November 11,318 341 9,527 1,440 10 December 11,637 268 9,847 1,512 9 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.7.D. Biogenic Municipal Solid Waste: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 13,694 0 3,118 8,858 1,718 2004 19,991 0 4,746 12,295 2,950 2005 20,296 0 4,551 11,991 3,754 2006 21,729 0 5,347 12,654 3,728 2007 16,174 0 5,683 8,350 2,141 2008 18,272 0 6,039 12,174 59 2009 18,785 0 6,229 11,535 1,021 2010 17,502 0 6,031 10,333 1,138 2011 16,766 0 5,807 9,731 1,227 2012 16,310 0 4,180 10,615 1,515

January 1,476 0 518 851 107 February 1,365 0 444 835 86 March 1,572 0 486 992 93

April 1,598 0 495 1,003 100 May 1,961 0 492 1,358 111 June 1,559 0 509 945 105

July 1,481 0 498 900 82 August 1,519 0 489 928 102 September 1,338 0 492 763 83 October 1,218 0 502 632 84 November 1,163 0 543 518 102 December 1,254 0 562 609 83

January 1,262 0 555 661 46 February 1,184 0 480 653 50 March 1,363 0 538 728 98

April 1,203 0 380 729 94 May 1,433 0 546 786 102 June 1,459 0 497 863 98

July 1,369 0 469 804 97 August 1,533 0 460 934 139 September 1,480 0 488 866 126 October 1,433 0 475 818 140 November 1,548 0 443 971 133 December 1,499 0 477 918 104

January 1,350 0 338 893 118 February 1,273 0 321 829 123 March 1,450 0 494 837 120

April 1,341 0 341 867 132 May 1,331 0 307 877 146 June 1,288 0 312 845 131

July 1,373 0 323 930 120 August 1,415 0 337 949 130 September 1,351 0 364 856 131 October 1,453 0 365 955 134 November 1,275 0 350 815 110 December 1,410 0 328 963 119 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.7.E. Biogenic Municipal Solid Waste: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 161,803 5,766 132,065 21,953 2,020 2004 161,567 3,705 129,562 25,204 3,096 2005 164,635 4,724 131,080 24,914 3,918 2006 168,716 4,078 135,127 25,618 3,893 2007 162,482 4,557 133,509 21,393 3,022 2008 166,723 4,476 136,080 26,108 59 2009 165,755 3,989 132,877 27,868 1,021 2010 162,436 3,322 130,467 27,509 1,138 2011 152,007 3,433 121,648 25,664 1,262 2012 152,045 3,910 117,598 28,923 1,614

January 13,015 244 10,405 2,260 107 February 11,678 190 9,473 1,929 86 March 13,786 293 11,042 2,359 93

April 13,982 276 11,081 2,525 100 May 14,605 278 11,272 2,945 111 June 14,030 297 11,177 2,451 105

July 14,073 308 11,339 2,345 82 August 14,091 309 11,220 2,461 102 September 13,326 261 10,721 2,261 83 October 13,197 297 10,799 2,017 84 November 13,127 294 10,811 1,920 102 December 13,523 275 11,129 2,037 83

January 11,533 231 9,335 1,920 46 February 10,751 207 8,734 1,759 50 March 12,539 256 10,228 1,958 98

April 12,249 277 9,876 2,002 94 May 12,875 319 10,231 2,224 102 June 13,268 336 10,576 2,258 98

July 13,467 313 10,807 2,245 101 August 13,264 326 10,493 2,299 146 September 12,781 316 10,140 2,193 131 October 12,984 304 10,325 2,210 146 November 12,972 266 10,241 2,326 139 December 13,324 282 10,663 2,269 110

January 12,292 271 9,546 2,348 127 February 11,557 261 8,884 2,283 129 March 12,472 317 9,663 2,369 123

April 12,327 390 9,402 2,395 140 May 13,187 427 10,100 2,504 156 June 12,969 318 10,125 2,386 140

July 13,480 332 10,507 2,513 128 August 13,053 350 10,065 2,500 139 September 12,372 286 9,545 2,400 140 October 12,695 348 9,711 2,494 142 November 12,593 341 9,876 2,255 120 December 13,047 268 10,175 2,475 129 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.7.F. Biogenic Municipal Solid Waste: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 34,775 2,456 15,859 4,566 11,894 2004 19,215 2,014 9,240 4,308 3,654 2005 17,852 2,485 7,365 4,677 3,325 2006 17,727 2,611 7,788 4,436 2,893 2007 19,083 2,992 8,861 4,049 3,181 2008 24,288 3,409 12,745 3,684 4,450 2009 24,847 3,679 13,231 3,760 4,177 2010 29,996 3,668 14,449 3,790 8,090 2011 30,771 4,488 16,115 3,816 6,352 2012 30,342 4,191 15,740 4,016 6,395

January 2,223 189 1,078 321 635 February 2,336 275 1,208 291 561 March 2,287 311 1,079 302 594

April 2,223 298 911 304 710 May 2,237 307 985 294 650 June 2,561 331 1,220 321 690

July 2,763 350 1,383 341 689 August 2,781 362 1,359 340 719 September 2,425 312 1,189 313 611 October 2,588 338 1,180 310 760 November 2,852 353 1,391 329 779 December 2,721 240 1,466 323 693

January 2,484 252 1,398 323 511 February 2,571 461 1,306 312 491 March 2,528 436 1,231 331 529

April 2,320 319 1,195 296 510 May 2,255 355 1,070 321 509 June 2,499 411 1,261 321 506

July 2,718 374 1,492 327 525 August 2,831 427 1,498 340 566 September 2,566 422 1,305 303 537 October 2,652 372 1,373 309 598 November 2,597 272 1,453 312 560 December 2,751 388 1,532 321 511

January 2,405 303 1,352 347 404 February 2,297 330 1,187 337 443 March 2,567 370 1,308 336 553

April 2,456 366 1,264 308 518 May 2,403 396 1,163 325 518 June 2,249 435 1,122 283 409

July 2,373 332 1,188 309 543 August 2,765 359 1,445 352 609 September 2,534 412 1,298 331 493 October 2,754 358 1,406 341 649 November 2,796 243 1,529 372 651 December 2,743 286 1,476 375 606 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.8.D. Other Waste Biomass: Consumption for Electricity Generation, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 29,854 0 10,655 757 18,442 2004 30,228 0 12,055 2,627 15,547 2005 38,010 0 10,275 2,086 25,649 2006 36,966 0 8,561 2,318 26,087 2007 41,757 0 10,294 2,643 28,820 2008 41,851 0 9,674 1,542 30,635 2009 41,810 0 10,355 1,638 29,817 2010 47,153 0 8,436 1,648 37,070 2011 43,483 0 6,460 1,566 35,458 2012 46,863 0 6,914 1,796 38,153

January 4,885 0 1,088 137 3,661 February 4,105 0 943 137 3,025 March 4,398 0 845 136 3,417

April 4,224 0 399 138 3,688 May 2,986 0 365 123 2,498 June 2,935 0 562 148 2,226

July 3,327 0 552 149 2,626 August 3,219 0 544 160 2,515 September 2,642 0 439 126 2,077 October 4,526 0 703 109 3,714 November 5,099 0 1,023 130 3,946 December 4,807 0 974 155 3,678

January 4,962 0 1,040 146 3,776 February 4,546 0 895 125 3,526 March 3,858 0 500 126 3,233

April 2,428 0 228 111 2,089 May 2,561 0 326 133 2,101 June 2,671 0 323 135 2,213

July 2,854 0 431 127 2,297 August 2,859 0 388 167 2,303 September 2,896 0 367 99 2,430 October 4,323 0 486 124 3,712 November 4,855 0 779 138 3,938 December 4,670 0 697 134 3,839

January 3,756 0 748 173 2,836 February 4,183 0 723 150 3,310 March 5,158 0 864 142 4,153

April 3,494 0 226 114 3,154 May 2,835 0 348 134 2,353 June 2,478 0 306 125 2,048

July 2,993 0 257 139 2,597 August 2,957 0 284 173 2,500 September 2,814 0 254 163 2,397 October 4,855 0 651 160 4,045 November 5,642 0 1,079 164 4,399 December 5,698 0 1,175 160 4,362 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.8.E. Other Waste Biomass: Consumption for Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsPeriod Total (all sectors) Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

2003 64,629 2,456 26,514 5,323 30,337 2004 49,443 2,014 21,294 6,935 19,201 2005 55,862 2,485 17,640 6,763 28,974 2006 54,693 2,611 16,348 6,755 28,980 2007 60,840 2,992 19,155 6,692 32,001 2008 66,139 3,409 22,419 5,227 35,085 2009 66,658 3,679 23,586 5,398 33,994 2010 77,150 3,668 22,884 5,438 45,159 2011 74,255 4,488 22,574 5,382 41,810 2012 77,205 4,191 22,654 5,812 44,548

January 7,109 189 2,166 458 4,295 February 6,441 275 2,151 429 3,586 March 6,685 311 1,924 439 4,011

April 6,447 298 1,309 442 4,397 May 5,223 307 1,351 417 3,148 June 5,496 331 1,782 469 2,915

July 6,089 350 1,935 490 3,315 August 6,000 362 1,903 500 3,235 September 5,067 312 1,628 440 2,687 October 7,114 338 1,883 419 4,474 November 7,951 353 2,413 459 4,725 December 7,528 240 2,440 478 4,370

January 7,445 252 2,438 469 4,287 February 7,117 461 2,201 437 4,018 March 6,386 436 1,731 457 3,762

April 4,748 319 1,423 407 2,599 May 4,816 355 1,396 454 2,610 June 5,170 411 1,583 456 2,719

July 5,573 374 1,923 454 2,822 August 5,690 427 1,886 508 2,869 September 5,462 422 1,671 402 2,967 October 6,974 372 1,859 433 4,311 November 7,452 272 2,232 451 4,498 December 7,421 388 2,229 455 4,349

January 6,162 303 2,100 520 3,239 February 6,480 330 1,910 487 3,753 March 7,725 370 2,172 478 4,705

April 5,950 366 1,490 422 3,672 May 5,237 396 1,511 459 2,871 June 4,727 435 1,428 407 2,457

July 5,365 332 1,445 448 3,140 August 5,723 359 1,729 525 3,110 September 5,348 412 1,552 494 2,890 October 7,609 358 2,057 501 4,693 November 8,438 243 2,608 536 5,050 December 8,441 286 2,652 535 4,968 2010

2011

2012

Notes: Beginning with the collection of Form EIA-923 in January 2008, the methodology to allocate total fuel consumption for electricity generation and consumption for useful thermal output was changed. The new methodology was retroactively applied to 2004-2007 data. See the Technical Notes (Appendix C) for further information. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms.Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA920, Combined Heat and Power Plant Report. 

### Table 5.8.F. Other Waste Biomass: Consumption for Electricity Generation and Useful Thermal Output, by Sector, 2002 - 2012 (Billion Btus) Electric Power Sector

Annual TotalsCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 1,787 2,998 -40.0% 520 898 1,257 2,087 0 0 10 12 Connecticut 297 317 -6.5% 0 0 297 317 0 0 0 0 Maine 11 14 -18.0% 0 0 6 7 0 0 5 6 Massachusetts 959 1,769 -46.0% 0 0 954 1,763 0 0 5 6 New Hampshire 520 898 -42.0% 520 898 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 44,000 53,658 -18.0% 6 16 43,734 53,052 4 1 256 589 New Jersey 833 1,805 -54.0% 0 0 833 1,805 0 0 0 0 New York 2,158 4,528 -52.0% 6 16 2,083 4,432 0 1 70 80 Pennsylvania 41,009 47,325 -13.0% 0 0 40,819 46,815 4 1 186 509 East North Central 182,280 210,082 -13.0% 128,058 145,150 53,050 63,646 97 112 1,076 1,174 Illinois 49,162 54,381 -9.6% 6,377 6,478 42,132 47,204 30 14 623 685 Indiana 46,587 52,590 -11.0% 43,475 47,863 3,062 4,678 36 36 14 13 Michigan 29,796 32,451 -8.2% 29,449 32,132 212 193 28 46 107 81 Ohio 37,242 47,611 -22.0% 29,475 35,865 7,645 11,570 2 13 121 162 Wisconsin 19,494 23,049 -15.0% 19,283 22,812 0 0 1 3 210 233 West North Central 135,575 146,881 -7.7% 133,859 145,208 0 0 64 97 1,651 1,576 Iowa 21,638 23,535 -8.1% 20,747 22,677 0 0 43 47 848 811 Kansas 17,759 20,129 -12.0% 17,759 20,129 0 0 0 0 0 0 Minnesota 13,704 17,003 -19.0% 13,384 16,515 0 0 1 24 319 464 Missouri 42,386 46,408 -8.7% 42,340 46,353 0 0 21 26 26 29 Nebraska 15,274 15,908 -4.0% 14,884 15,711 0 0 0 0 390 197 North Dakota 22,862 22,130 3.3% 22,795 22,056 0 0 0 0 68 74 South Dakota 1,950 1,768 10.0% 1,950 1,768 0 0 0 0 0 0 South Atlantic 116,543 140,060 -17.0% 96,679 118,044 19,242 21,139 31 26 591 851 Delaware 677 712 -5.0% 0 0 677 712 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 19,699 22,455 -12.0% 19,080 21,529 567 860 0 0 52 66 Georgia 20,985 29,092 -28.0% 20,836 28,894 0 0 0 0 149 198 Maryland 6,981 8,949 -22.0% 0 0 6,919 8,898 19 0 43 51 North Carolina 20,761 24,452 -15.0% 20,040 23,569 661 811 8 14 52 58 South Carolina 11,706 13,994 -16.0% 11,622 13,807 17 80 0 0 67 107 Virginia 6,213 8,414 -26.0% 5,634 7,453 451 820 4 11 124 130 West Virginia 29,521 31,993 -7.7% 19,468 22,793 9,950 8,959 0 0 103 241 East South Central 84,979 97,157 -13.0% 81,613 94,110 3,081 2,729 4 5 281 314 Alabama 23,056 28,180 -18.0% 22,993 28,098 15 27 0 0 47 54 Kentucky 38,978 42,543 -8.4% 38,978 42,543 0 0 0 0 0 0 Mississippi 5,240 6,203 -16.0% 2,175 3,502 3,066 2,701 0 0 0 0 Tennessee 17,705 20,232 -12.0% 17,466 19,967 0 0 4 5 234 260 West South Central 147,598 166,132 -11.0% 76,768 84,931 70,624 80,650 0 0 207 551 Arkansas 17,048 17,491 -2.5% 14,571 15,123 2,451 2,343 0 0 25 26 Louisiana 14,747 16,717 -12.0% 8,106 8,421 6,640 8,292 0 0 0 4 Oklahoma 18,499 21,497 -14.0% 17,115 19,993 1,201 1,311 0 0 182 193 Texas 97,305 110,426 -12.0% 36,974 41,394 60,331 68,705 0 0 0 328 Mountain 107,089 110,554 -3.1% 96,176 98,799 10,421 11,195 0 0 493 560 Arizona 21,519 23,307 -7.7% 21,461 23,217 0 0 0 0 58 90 Colorado 19,025 18,541 2.6% 18,983 18,500 36 41 0 0 5 0 Idaho 18 19 -8.2% 0 0 0 0 0 0 18 19 Montana 9,064 9,772 -7.2% 248 298 8,809 9,460 0 0 7 14 Nevada 2,258 2,863 -21.0% 1,630 2,136 628 727 0 0 0 0 New Mexico 14,452 15,496 -6.7% 14,452 15,496 0 0 0 0 0 0 Utah 14,304 15,242 -6.2% 13,639 14,582 445 422 0 0 220 237 Wyoming 26,449 25,313 4.5% 25,763 24,570 502 545 0 0 184 199 Pacific Contiguous 4,596 6,196 -26.0% 1,583 1,985 2,930 4,124 0 0 83 87 California 502 779 -36.0% 0 0 428 699 0 0 74 80 Oregon 1,583 1,985 -20.0% 1,583 1,985 0 0 0 0 0 0 Washington 2,511 3,432 -27.0% 0 0 2,502 3,425 0 0 9 7 Pacific Noncontiguous 1,287 1,221 5.4% 206 175 958 919 105 106 17 21 Alaska 530 512 3.6% 206 175 219 231 105 106 0 0 Hawaii 757 709 6.7% 0 0 739 688 0 0 17 21 U.S. Total 825,734 934,938 -12.0% 615,467 689,316 205,295 239,541 307 347 4,665 5,735

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 5.9. Consumption of Coal for Electricity Generation by State by Sector, 2012 and 2011 (Thousand Tons) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 891 1,267 -30.0% 119 249 650 860 80 81 41 77 Connecticut 259 369 -30.0% 8 10 247 355 0 0 4 4 Maine 197 320 -39.0% 0 1 176 237 6 9 14 73 Massachusetts 325 361 -10.0% 30 73 226 265 46 23 22 NM New Hampshire 58 143 -60.0% 46 126 0 1 11 16 0 0 Rhode Island 31 28 8.0% 29 21 0 2 1 5 0 0 Vermont 22 46 -53.0% 6 19 0 0 15 27 0 0 Middle Atlantic 1,720 2,823 -39.0% 642 916 986 1,785 22 24 71 97 New Jersey 77 233 -67.0% 9 10 67 221 1 1 1 2 New York 1,053 1,672 -37.0% 633 906 338 658 17 18 65 90 Pennsylvania 590 918 -36.0% 0 0 582 906 4 5 4 6 East North Central 1,262 1,519 -17.0% 1,058 1,269 182 215 3 7 18 28 Illinois 137 161 -15.0% 49 56 88 105 0 0 0 0 Indiana 217 310 -30.0% 208 289 0 0 1 2 8 19 Michigan 281 374 -25.0% 273 365 0 0 2 4 6 5 Ohio 526 589 -11.0% 433 486 90 101 0 0 3 2 Wisconsin 100 85 18.0% 95 74 4 10 0 0 1 1 West North Central 634 639 -0.7% 617 624 11 8 2 3 3 4 Iowa 204 158 29.0% 199 155 4 3 0 0 0 0 Kansas 78 86 -9.3% 78 86 0 0 0 0 0 0 Minnesota 62 56 12.0% 53 48 6 4 2 2 2 2 Missouri 163 165 -1.1% 163 164 0 0 0 0 0 1 Nebraska 43 70 -39.0% 43 70 0 0 0 0 0 0 North Dakota 66 83 -20.0% 64 81 0 0 0 0 1 2 South Dakota 18 21 -16.0% 17 20 1 1 0 0 0 0 South Atlantic 3,416 5,304 -36.0% 2,539 4,140 535 985 149 7 194 172 Delaware 46 75 -39.0% 1 3 44 72 0 0 0 0 District of Columbia 26 275 -91.0% 0 0 26 275 0 0 0 0 Florida 1,262 2,441 -48.0% 1,206 2,375 20 27 0 0 36 39 Georgia 232 233 -0.4% 126 167 3 7 3 3 99 56 Maryland 409 467 -13.0% 15 17 243 447 143 0 7 3 North Carolina 352 406 -13.0% 330 372 10 8 0 0 12 25 South Carolina 216 213 1.6% 196 192 4 0 0 1 16 20 Virginia 624 867 -28.0% 417 706 182 129 2 3 23 30 West Virginia 250 327 -24.0% 249 308 2 19 0 0 0 0 East South Central 757 927 -18.0% 691 869 4 11 0 0 62 47 Alabama 198 228 -13.0% 138 176 4 11 0 0 57 41 Kentucky 232 256 -9.4% 232 256 0 0 0 0 0 0 Mississippi 29 68 -57.0% 26 65 0 0 0 0 3 4 Tennessee 297 374 -21.0% 295 372 0 0 0 0 2 2 West South Central 415 494 -16.0% 126 261 268 211 1 3 20 20 Arkansas 56 96 -41.0% 32 58 23 36 0 0 2 3 Louisiana 73 97 -24.0% 23 49 35 33 0 0 16 14 Oklahoma 22 31 -30.0% 21 30 0 0 0 0 1 0 Texas 264 271 -2.4% 51 124 210 141 1 2 2 3 Mountain 433 488 -11.0% 382 439 45 46 0 0 6 2 Arizona 77 98 -22.0% 76 96 0 0 0 0 1 2 Colorado 31 56 -44.0% 31 56 0 0 0 0 0 0 Idaho 0 0 -25.0% 0 0 0 0 0 0 0 0 Montana 31 38 -18.0% 0 5 31 34 0 0 0 0 Nevada 41 28 45.0% 30 20 11 8 0 0 0 0 New Mexico 88 72 22.0% 86 67 1 5 0 0 0 0 Utah 71 88 -20.0% 67 88 2 0 0 0 2 0 Wyoming 95 107 -12.0% 92 107 0 0 0 0 3 0 Pacific Contiguous 166 163 2.3% 85 87 47 37 2 2 33 37 California 97 88 11.0% 61 64 32 18 1 1 3 5 Oregon 12 13 -3.1% 12 12 0 0 0 0 0 1 Washington 57 62 -8.5% 12 12 15 19 0 0 30 31 Pacific Noncontiguous 12,910 13,703 -5.8% 11,261 11,989 1,382 1,475 12 8 254 232 Alaska 1,710 1,613 6.0% 1,615 1,517 0 0 9 4 86 92 Hawaii 11,200 12,090 -7.4% 9,646 10,472 1,382 1,475 4 4 168 140 U.S. Total 22,604 27,326 -17.0% 17,521 20,844 4,110 5,633 272 133 702 716

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 5.10. Consumption of Petroleum Liquids for Electricity Generation by State, by Sector,. 2012 and 2011 (Thousand Barrels) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 0 0

-- 0 0 0 0 0 0 0 0 Connecticut 0 0

-- 0 0 0 0 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts 0 0

-- 0 0 0 0 0 0 0 0 New Hampshire 0 0

-- 0 0 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 56 121 -54.0% 0 0 0 94 0 0 56 27 New Jersey 11 6 69.0% 0 0 0 0 0 0 11 6 New York 0 94 -100.0% 0 0 0 94 0 0 0 0 Pennsylvania 46 21 116.0% 0 0 0 0 0 0 46 21 East North Central 801 933 -14.0% 236 438 502 435 0 0 64 60 Illinois 0 0

-- 0 0 0 0 0 0 0 0 Indiana 204 286 -29.0% 204 286 0 0 0 0 0 0 Michigan 53 47 12.0% 0 0 34 31 0 0 19 16 Ohio 468 403 16.0% 0 0 468 403 0 0 0 0 Wisconsin 76 196 -61.0% 31 152 0 0 0 0 45 44 West North Central 6 42 -85.0% 5 41 0 0 1 1 0 0 Iowa 6 28 -79.0% 5 28 0 0 1 1 0 0 Kansas 0 13 -100.0% 0 13 0 0 0 0 0 0 Minnesota 0 0

-- 0 0 0 0 0 0 0 0 Missouri 0 0

-- 0 0 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 298 766 -61.0% 246 695 0 0 0 0 52 71 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 246 695 -65.0% 246 695 0 0 0 0 0 0 Georgia 52 71 -26.0% 0 0 0 0 0 0 52 71 Maryland 0 0

-- 0 0 0 0 0 0 0 0 North Carolina 0 0

-- 0 0 0 0 0 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 0 0

-- 0 0 0 0 0 0 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central 542 608 -11.0% 542 608 0 0 0 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 542 608 -11.0% 542 608 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 0 0

-- 0 0 0 0 0 0 0 0 West South Central 1,741 2,019 -14.0% 1,076 1,667 25 225 0 0 640 128 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 1,155 1,750 -34.0% 1,076 1,667 0 0 0 0 79 83 Oklahoma 0 0

-- 0 0 0 0 0 0 0 0 Texas 586 269 118.0% 0 0 25 225 0 0 561 44 Mountain 172 168 2.2% 0 0 172 168 0 0 0 0 Arizona 0 0

-- 0 0 0 0 0 0 0 0 Colorado 0 0

-- 0 0 0 0 0 0 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 172 168 2.2% 0 0 172 168 0 0 0 0 Nevada 0 0

-- 0 0 0 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 0 0

-- 0 0 0 0 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 58 356 -84.0% 0 0 58 356 0 0 0 0 California 58 356 -84.0% 0 0 58 356 0 0 0 0 Oregon 0 0

-- 0 0 0 0 0 0 0 0 Washington 0 0

-- 0 0 0 0 0 0 0 0 Pacific Noncontiguous 0 0

-- 0 0 0 0 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 3,675 5,012 -27.0% 2,105 3,449 756 1,277 1 1 812 286

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 5.11. Consumption of Petroleum Coke for Electricity Generation by State, by Sector, 2012 and 2011 (Thousand Tons) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 460,887 461,590 -0.2% 3,652 4,218 428,781 432,350 8,630 6,287 19,824 18,735 Connecticut 120,380 110,546 8.9% 69 730 113,620 105,965 3,952 2,061 2,739 1,790 Maine 44,424 49,352 -10.0% 0 0 28,456 33,555 307 12 15,662 15,785 Massachusetts 184,330 190,063 -3.0% 2,792 2,393 176,497 182,865 3,749 3,761 1,293 1,045 New Hampshire 50,678 46,927 8.0% 754 1,046 49,655 45,765 139 0 131 115 Rhode Island 61,037 64,652 -5.6% 0 0 60,553 64,198 483 453 0 0 Vermont 38 49 -24.0% 38 49 0 0 0 0 0 0 Middle Atlantic 1,096,021 919,372 19.0% 131,110 128,822 946,544 773,751 8,003 6,385 10,364 10,414 New Jersey 219,175 188,343 16.0% 320 0 213,482 183,312 1,380 744 3,993 4,287 New York 491,430 426,610 15.0% 130,766 128,772 353,376 290,943 5,443 5,122 1,845 1,772 Pennsylvania 385,415 304,420 27.0% 24 50 379,686 299,495 1,180 519 4,525 4,356 East North Central 638,823 371,576 72.0% 232,311 138,800 379,014 216,434 14,395 7,745 13,103 8,597 Illinois 95,068 49,876 91.0% 12,659 10,104 72,451 33,739 7,729 3,580 2,228 2,453 Indiana 113,236 80,758 40.0% 85,667 56,214 24,183 20,711 318 277 3,068 3,556 Michigan 169,806 99,748 70.0% 41,177 25,010 119,531 71,784 2,874 1,415 6,224 1,539 Ohio 173,754 93,220 86.0% 45,449 23,897 124,273 66,884 3,159 1,979 872 460 Wisconsin 86,961 47,975 81.0% 47,358 23,575 38,576 23,317 315 493 711 590 West North Central 170,587 113,993 50.0% 144,889 99,437 20,583 11,622 3,050 2,111 2,066 823 Iowa 17,124 9,963 72.0% 16,508 9,893 0 0 55 35 560 35 Kansas 33,262 30,508 9.0% 32,520 30,501 0 0 0 0 742 7 Minnesota 58,725 29,484 99.0% 47,262 22,369 9,074 5,419 1,901 1,345 488 352 Missouri 51,047 37,796 35.0% 38,436 30,862 11,508 6,203 1,090 714 13 17 Nebraska 7,867 4,563 72.0% 7,696 4,223 0 0 4 17 167 324 North Dakota 97 89 9.7% 1 0 0 0 0 0 97 88 South Dakota 2,465 1,589 55.0% 2,465 1,589 0 0 0 0 0 0 South Atlantic 2,027,1161,647,571 23.0%1,556,2381,289,259 444,508 341,903 3,250 2,315 23,120 14,093 Delaware 60,033 40,908 47.0% 87 172 53,163 38,620 0 0 6,783 2,115 District of Columbia 1,019 1,003 1.6% 0 1,003 0 0 1,019 0 0 0 Florida 1,143,2531,050,028 8.9%1,036,033 956,166 97,848 85,329 166 181 9,207 8,352 Georgia 311,419 197,831 57.0% 182,391 96,581 125,140 99,567 0 0 3,888 1,682 Maryland 51,189 23,084 122.0% 0 0 48,313 20,026 2,023 2,124 852 934 North Carolina 151,311 90,156 68.0% 127,498 71,379 23,368 18,420 42 5 403 352 South Carolina 116,711 100,013 17.0% 98,325 86,623 17,592 13,227 0 5 794 158 Virginia 189,760 141,946 34.0% 111,469 76,938 77,159 64,532 0 0 1,132 477 West Virginia 2,421 2,603 -7.0% 435 398 1,925 2,181 0 0 62 24 East South Central 813,127 640,447 27.0% 439,019 349,841 346,672 278,444 1,454 949 25,982 11,214 Alabama 409,036 349,641 17.0% 114,320 106,303 285,876 236,041 0 0 8,840 7,296 Kentucky 33,068 17,343 91.0% 27,707 13,927 3,487 1,647 0 0 1,874 1,769 Mississippi 306,475 245,953 25.0% 234,031 203,296 57,309 40,755 103 115 15,031 1,787 Tennessee 64,548 27,510 135.0% 62,961 26,314 0 0 1,351 834 236 362 West South Central 2,572,2692,384,064 7.9% 824,116 786,5261,293,0551,162,264 6,077 3,851 449,020 431,422 Arkansas 123,878 101,960 21.0% 24,399 29,389 98,125 71,364 7 5 1,348 1,202 Louisiana 498,772 462,060 7.9% 225,881 225,596 79,084 50,678 255 262 193,552 185,523 Oklahoma 318,424 264,642 20.0% 232,526 202,132 85,234 61,912 60 138 605 460 Texas 1,631,1941,555,402 4.9% 341,311 329,4091,030,613 978,309 5,755 3,447 253,516 244,237 Mountain 654,440 556,922 18.0% 394,561 350,199 242,649 198,247 3,086 2,016 14,144 6,460 Arizona 229,825 181,309 27.0% 111,256 80,898 117,416 99,878 1,115 511 38 23 Colorado 84,984 84,305 0.8% 48,631 68,541 36,116 15,571 28 28 210 164 Idaho 13,685 8,376 63.0% 4,394 1,615 8,827 6,293 0 0 464 467 Montana 5,370 4,681 15.0% 5,145 4,571 224 110 0 0 0 0 Nevada 188,769 161,699 17.0% 136,828 113,552 48,990 46,006 629 606 2,322 1,535 New Mexico 72,592 72,235 0.5% 48,015 45,308 23,734 25,548 839 871 4 509 Utah 55,880 41,389 35.0% 39,975 35,377 7,163 4,761 476 0 8,266 1,250 Wyoming 3,335 2,929 14.0% 317 338 179 80 0 0 2,840 2,511 Pacific Contiguous 1,011,056 745,740 36.0% 336,272 257,246 584,454 404,093 15,153 15,492 75,178 68,909 California 889,837 650,871 37.0% 276,436 210,336 524,909 357,290 14,552 15,054 73,940 68,190 Oregon 81,995 60,164 36.0% 27,956 19,864 52,659 39,474 570 403 810 423 Washington 39,224 34,705 13.0% 31,880 27,046 6,885 7,329 31 34 428 297 Pacific Noncontiguous 40,383 42,591 -5.2% 39,758 41,738 0 0 18 19 606 834 Alaska 40,383 42,591 -5.2% 39,758 41,738 0 0 18 19 606 834 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 9,484,7107,883,865 20.0%4,101,9273,446,0874,686,2603,819,107 63,116 47,170 633,407 571,501

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 5.12. Consumption of Nautral Gas for Electricity Generation by State, by Sector, 2012 and 2011 (Million Cubic Feet) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 9,595 9,945 -3.5% 0 0 9,074 9,945 520 0 0 0 Connecticut 595 624 -4.6% 0 0 595 624 0 0 0 0 Maine 518 524 -1.0% 0 0 518 524 0 0 0 0 Massachusetts 3,603 3,623 -0.6% 0 0 3,603 3,623 0 0 0 0 New Hampshire 1,790 1,485 21.0% 0 0 1,270 1,485 520 0 0 0 Rhode Island 2,409 3,037 -21.0% 0 0 2,409 3,037 0 0 0 0 Vermont 679 653 4.0% 0 0 679 653 0 0 0 0 Middle Atlantic 51,169 47,289 8.2% 0 0 50,867 44,820 302 2,469 0 0 New Jersey 9,691 8,192 18.0% 0 0 9,691 5,993 0 2,199 0 0 New York 16,418 15,564 5.5% 0 0 16,418 15,564 0 0 0 0 Pennsylvania 25,060 23,533 6.5% 0 0 24,758 23,263 302 270 0 0 East North Central 63,904 58,219 9.8% 6,497 6,693 56,893 50,865 210 277 303 384 Illinois 16,204 15,856 2.2% 0 0 16,204 15,856 0 0 0 0 Indiana 6,601 6,953 -5.1% 6,297 6,569 0 0 0 0 303 384 Michigan 18,536 16,711 11.0% 0 0 18,536 16,711 0 0 0 0 Ohio 9,784 5,780 69.0% 0 0 9,784 5,780 0 0 0 0 Wisconsin 12,780 12,918 -1.1% 200 124 12,369 12,518 210 277 0 0 West North Central 9,301 8,395 11.0% 2,903 2,011 6,398 6,384 0 0 0 0 Iowa 2,021 2,096 -3.6% 0 0 2,021 2,096 0 0 0 0 Kansas 1,205 1,338 -10.0% 0 0 1,205 1,338 0 0 0 0 Minnesota 3,489 2,482 41.0% 768 0 2,720 2,482 0 0 0 0 Missouri 1,488 1,209 23.0% 1,037 742 452 468 0 0 0 0 Nebraska 1,098 1,269 -13.0% 1,098 1,269 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 41,593 32,175 29.0% 4,763 5,156 32,235 25,258 2,353 1,761 2,242 0 Delaware 2,426 3,510 -31.0% 0 0 2,426 3,510 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 7,839 8,307 -5.6% 1,718 1,708 6,122 6,598 0 0 0 0 Georgia 2,924 1,866 57.0% 0 0 2,452 1,378 472 488 0 0 Maryland 3,374 2,015 67.0% 0 0 1,797 742 1,577 1,273 0 0 North Carolina 6,497 4,931 32.0% 0 0 6,461 4,931 36 0 0 0 South Carolina 5,490 3,749 46.0% 2,953 3,189 295 560 0 0 2,242 0 Virginia 12,779 7,528 70.0% 92 259 12,420 7,269 267 0 0 0 West Virginia 262 270 -2.8% 0 0 262 270 0 0 0 0 East South Central 3,898 1,912 104.0% 2,398 1,162 1,500 750 0 0 0 0 Alabama 226 0

-- 0 0 226 0 0 0 0 0 Kentucky 2,398 1,162 106.0% 2,398 1,162 0 0 0 0 0 0 Mississippi 48 0

-- 0 0 48 0 0 0 0 0 Tennessee 1,226 750 63.0% 0 0 1,226 750 0 0 0 0 West South Central 15,086 14,334 5.2% 0 0 14,429 13,704 657 630 0 0 Arkansas 1,193 1,256 -5.0% 0 0 1,193 1,256 0 0 0 0 Louisiana 0 0

-- 0 0 0 0 0 0 0 0 Oklahoma 0 0

-- 0 0 0 0 0 0 0 0 Texas 13,893 13,078 6.2% 0 0 13,237 12,448 657 630 0 0 Mountain 4,328 3,548 22.0% 948 708 3,380 2,840 0 0 0 0 Arizona 1,367 1,222 12.0% 728 708 639 514 0 0 0 0 Colorado 565 606 -6.8% 0 0 565 606 0 0 0 0 Idaho 741 523 42.0% 220 0 521 523 0 0 0 0 Montana 0 0

-- 0 0 0 0 0 0 0 0 Nevada 402 0

-- 0 0 402 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 1,253 1,197 4.7% 0 0 1,253 1,197 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 57,502 56,978 0.9% 7,684 6,356 27,187 26,290 22,630 24,332 0 0 California 50,347 51,408 -2.1% 3,549 3,452 24,663 24,148 22,134 23,808 0 0 Oregon 4,165 3,932 5.9% 1,360 1,412 2,309 1,997 496 524 0 0 Washington 2,990 1,638 83.0% 2,775 1,493 215 145 0 0 0 0 Pacific Noncontiguous 0 0

-- 0 0 0 0 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 256,376 232,795 10.0% 25,193 22,086 201,965 180,856 26,672 29,469 2,545 384

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 5.13. Consumption of Landfill Gas for Electricity Generation by State, by Sector, 2012 and 2011 (Million Cubic Feet) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 4,041 4,122 -2.0% 0 0 3,838 3,922 203 200 0 0 Connecticut 1,415 1,442 -1.9% 0 0 1,415 1,442 0 0 0 0 Maine 440 445 -1.3% 0 0 237 246 203 200 0 0 Massachusetts 2,017 2,063 -2.2% 0 0 2,017 2,063 0 0 0 0 New Hampshire 169 172 -2.0% 0 0 169 172 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 5,512 5,308 3.8% 0 0 4,315 4,485 1,198 823 0 0 New Jersey 1,367 1,388 -1.6% 0 0 1,015 1,039 351 349 0 0 New York 2,077 2,011 3.3% 0 0 1,505 1,799 572 212 0 0 Pennsylvania 2,069 1,909 8.4% 0 0 1,795 1,647 274 263 0 0 East North Central 272 252 7.9% 37 35 0 0 234 216 0 0 Illinois 0 0

-- 0 0 0 0 0 0 0 0 Indiana 12 11 11.0% 0 0 0 0 12 11 0 0 Michigan 222 205 8.1% 0 0 0 0 222 205 0 0 Ohio 0 0

-- 0 0 0 0 0 0 0 0 Wisconsin 37 35 5.7% 37 35 0 0 0 0 0 0 West North Central 630 600 5.1% 380 353 229 233 21 14 0 0 Iowa 0 0

-- 0 0 0 0 0 0 0 0 Kansas 0 0

-- 0 0 0 0 0 0 0 0 Minnesota 630 600 5.1% 380 353 229 233 21 14 0 0 Missouri 0 0

-- 0 0 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 5,429 5,545 -2.1% 0 0 5,041 5,170 388 375 0 0 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 3,654 3,708 -1.5% 0 0 3,654 3,708 0 0 0 0 Georgia 0 0

-- 0 0 0 0 0 0 0 0 Maryland 737 752 -2.0% 0 0 737 752 0 0 0 0 North Carolina 0 27 -100.0% 0 0 0 27 0 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 1,038 1,058 -1.9% 0 0 650 684 388 375 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central 0 0

-- 0 0 0 0 0 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 0 0

-- 0 0 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 0 0

-- 0 0 0 0 0 0 0 0 West South Central 12 4 189.0% 0 0 0 0 0 0 12 4 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 0 0

-- 0 0 0 0 0 0 0 0 Oklahoma 12 4 189.0% 0 0 0 0 0 0 12 4 Texas 0 0

-- 0 0 0 0 0 0 0 0 Mountain 3 3 -0.1% 0 0 3 3 0 0 0 0 Arizona 0 0

-- 0 0 0 0 0 0 0 0 Colorado 0 0

-- 0 0 0 0 0 0 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 0 0

-- 0 0 0 0 0 0 0 0 Nevada 0 0

-- 0 0 0 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 3 3 -0.1% 0 0 3 3 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 810 811 -0.1% 0 0 810 811 0 0 0 0 California 515 517 -0.3% 0 0 515 517 0 0 0 0 Oregon 120 119 1.3% 0 0 120 119 0 0 0 0 Washington 175 175 -0.4% 0 0 175 175 0 0 0 0 Pacific Noncontiguous 260 327 -21.0% 0 0 0 0 260 327 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 260 327 -21.0% 0 0 0 0 260 327 0 0 U.S. Total 16,968 16,972 0.0% 418 388 14,235 14,625 2,304 1,955 12 4

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 5.14. Consumption of Biogenic Municipal Solid Waste for Electricity Generation by State, by Sector, 2012 and 2011 (Thousand Tons) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial Sector

# Chapter 6

Fossil Fuel Stocks for Electricity GenerationPeriod Coal (Thousand Tons) Petroluem Liquids (Thousand Barrels) Petroleum Coke (Thousand Tons) Coal (Thousand Tons) Petroluem Liquids (Thousand Barrels) Petroleum Coke (Thousand Tons) Coal (Thousand Tons) Petroluem Liquids (Thousand Barrels) Petroleum Coke (Thousand Tons)

2002 141,714 43,935 1,711 116,952 29,601 328 24,761 14,334 1,383 2003 121,567 45,752 1,484 97,831 28,062 378 23,736 17,691 1,105 2004 106,669 46,750 937 84,917 29,144 627 21,751 17,607 309 2005 101,137 47,414 530 77,457 29,532 374 23,680 17,882 156 2006 140,964 48,216 674 110,277 29,799 456 30,688 18,416 217 2007 151,221 44,433 554 120,504 28,032 253 30,717 16,401 301 2008 161,589 40,804 739 127,463 26,108 468 34,126 14,696 270 2009 189,467 39,210 1,394 154,815 25,811 1,194 34,652 13,399 201 2010 174,917 35,706 1,019 143,744 24,798 850 31,173 10,908 168 2011 172,387 34,847 508 142,103 25,648 404 30,284 9,198 104 2012 185,116 32,224 495 150,942 23,875 414 34,174 8,349 81

January 178,091 37,426 1,406 146,174 24,732 1,178 31,917 12,693 228 February 171,026 38,163 1,280 140,533 25,561 1,045 30,493 12,602 235 March 177,742 38,137 1,240 145,182 25,578 983 32,559 12,558 258

April 189,260 37,875 1,243 152,253 25,360 1,022 37,007 12,516 221 May 191,669 37,355 1,188 153,295 25,019 986 38,374 12,336 202 June 181,490 36,623 1,117 146,130 24,305 943 35,359 12,318 174 July 169,504 35,627 1,046 138,240 23,858 907 31,265 11,769 139 August 159,987 35,317 1,112 131,072 23,887 976 28,915 11,430 136 September 163,776 36,208 1,158 133,943 24,857 1,017 29,833 11,350 141 October 175,686 36,857 1,197 143,363 25,309 1,006 32,323 11,548 191 November 183,389 36,926 1,098 149,066 25,660 894 34,323 11,266 204 December 174,917 35,706 1,019 143,744 24,798 850 31,173 10,908 168

January 164,575 35,116 799 134,983 24,759 657 29,591 10,357 142 February 161,064 34,662 707 131,893 24,552 594 29,171 10,110 113 March 166,255 34,318 495 135,359 24,448 437 30,896 9,870 59

April 173,427 33,895 526 141,094 24,222 463 32,334 9,672 63 May 174,093 33,745 563 140,536 24,187 490 33,557 9,557 73 June 165,149 35,339 496 133,988 25,847 433 31,161 9,492 64 July 147,296 34,903 463 120,226 25,535 411 27,070 9,368 52 August 138,527 34,637 437 113,210 25,297 379 25,317 9,339 58 September 143,711 34,666 385 118,038 25,313 332 25,673 9,353 53 October 156,196 35,293 440 128,170 25,756 346 28,026 9,536 94 November 167,754 35,437 494 137,122 25,967 391 30,632 9,470 102 December 172,387 34,847 508 142,103 25,648 404 30,284 9,198 104

January 180,091 34,660 409 144,615 25,518 324 35,476 9,142 85 February 186,866 34,431 374 150,246 25,311 293 36,620 9,119 81 March 195,380 34,552 453 157,444 25,463 351 37,935 9,089 102

April 202,265 34,375 457 161,926 25,356 332 40,339 9,019 125 May 203,137 33,973 406 162,992 25,046 270 40,146 8,926 136 June 197,924 33,747 458 158,366 24,964 287 39,558 8,783 171 July 183,958 33,502 406 148,517 24,947 216 35,442 8,555 190 August 178,537 32,619 336 144,975 24,297 198 33,562 8,322 139 September 182,020 32,316 353 147,916 24,175 267 34,104 8,141 86 October 186,396 32,182 406 151,418 24,078 339 34,978 8,104 67 November 188,291 32,045 416 152,864 23,982 346 35,428 8,062 70 December 185,116 32,224 495 150,942 23,875 414 34,174 8,349 81 2011, End of Month Stocks

2012, End of Month Stocks

Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 6.1. Stocks of Coal, Petroleum Liquids, and Petroleum Coke: Electric Power Sector, 2002 - 2012 Electric Power Sector Electric Utilities Independent Power Producers

End of Year Stocks

2010, End of Month StocksCensus Division and State

December 2012December 2011Percentage ChangeDecember 2012December 2011Percentage ChangeDecember 2012December 2011Percentage Change New England 1,030 1,389 -26.0% 2,483 2,680 -7.3% 0 0

-- Connecticut W W W 1,300 954 36.0% 0 0

-- Maine 0 0

-- W W W 0 0

-- Massachusetts W 675 W 837 990 -15.0% 0 0

-- New Hampshire W W W W W W 0 0

-- Rhode Island 0 0

-- W W W 0 0

-- Vermont 0 0

-- 51 49 3.0% 0 0

-- Middle Atlantic 7,553 7,800 -3.2% 5,496 6,591 -17.0% W W W New Jersey 926 871 6.3% 1,084 1,113 -2.6% 0 0

-- New York 556 898 -38.0% 3,498 4,276 -18.0% 0 0

-- Pennsylvania 6,070 6,031 0.6% 914 1,201 -24.0% W W W East North Central 36,139 37,262 -3.0% 1,223 1,581 -23.0% 56 W W Illinois 8,931 8,905 0.3% 118 139 -15.0% 0 0

-- Indiana 9,127 9,094 0.4% 117 128 -9.0% 0 0

-- Michigan 6,729 6,512 3.3% 439 666 -34.0% W W W Ohio 6,340 7,331 -14.0% 316 364 -13.0% W W W Wisconsin 5,012 5,420 -7.5% 234 285 -18.0% W W W West North Central 30,554 28,544 7.0% 1,052 1,297 -19.0% 0 W W Iowa 8,580 7,199 19.0% 152 161 -5.8% 0 W W Kansas 3,741 3,669 2.0% 165 272 -39.0% 0 0

-- Minnesota 2,691 3,247 -17.0% 168 195 -14.0% 0 0

-- Missouri 10,230 8,210 25.0% 316 327 -3.1% 0 0

-- Nebraska 3,321 3,607 -7.9% 132 210 -37.0% 0 0

-- North Dakota W W W 36 37 -3.3% 0 0

-- South Dakota W W W 83 95 -13.0% 0 0

-- South Atlantic 38,859 36,920 5.3% 13,603 14,316 -5.0% W W W Delaware W W W 392 402 -2.5% 0 0

--
District of Columbia 0 0

-- 0 93 -100.0% 0 0

-- Florida W 6,374 W 7,128 7,789 -8.5% W W W Georgia 9,970 7,885 26.0% 908 895 1.5% 0 0

-- Maryland 1,544 1,860 -17.0% 826 833 -0.8% 0 0

-- North Carolina 7,164 6,642 7.9% 1,110 1,033 7.4% 0 0

-- South Carolina W 6,527 W 650 597 9.0% W W W Virginia 2,118 2,480 -15.0% 2,440 2,530 -3.6% 0 0

-- West Virginia 5,643 W W 150 145 3.2% W W W East South Central 19,657 17,185 14.0% 1,928 2,064 -6.6% W W W Alabama 6,123 4,499 36.0% 279 318 -12.0% 0 0

-- Kentucky 8,417 7,357 14.0% 257 264 -2.5% W W W Mississippi 1,964 1,450 36.0% 559 562 -0.5% 0 0

-- Tennessee 3,153 3,879 -19.0% 832 921 -9.6% 0 0

--
West South Central 28,807 22,910 26.0% 2,548 2,560 -0.5% W W W Arkansas 4,181 3,590 16.0% 245 157 56.0% 0 0

-- Louisiana 3,342 2,331 43.0% 662 605 9.5% W W W Oklahoma 4,739 3,872 22.0% 209 196 6.6% 0 0

-- Texas 16,545 13,117 26.0% 1,432 1,602 -11.0% W 0 W Mountain 20,385 18,543 9.9% 654 677 -3.3% W W W Arizona 4,235 2,750 54.0% 209 229 -8.6% 0 0

-- Colorado 4,131 4,342 -4.9% 129 139 -7.3% 0 0

-- Idaho 0 0

-- W W W 0 0

-- Montana W W W W W W W W W Nevada W W W 179 180 -0.6% 0 0

-- New Mexico W W W 49 34 41.0% 0 0

-- Utah 4,737 4,947 -4.2% NM 39 NM 0 0

-- Wyoming 3,962 3,275 21.0% 29 38 -24.0% 0 0

-- Pacific Contiguous W W W 395 424 -7.0% W 5 W California W W W NM 199 NM W 5 W Oregon W W W W W W 0 0

-- Washington W W W W W W 0 0

-- Pacific Noncontiguous W W W 2,842 2,656 7.0% 0 0

-- Alaska W W W 279 283 -1.3% 0 0

-- Hawaii W W W 2,562 2,373 8.0% 0 0

-- U.S. Total 185,116 172,387 7.4% 32,224 34,847 -7.5% 495 508 -2.6%

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Negative generation denotes that electric power consumed for plant use exceeds gross generation. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 6.2 Stocks of Coal, Petroleum Liquids, and Petroleum Coke: Electric Power Sector, by State, 2012 and 2011 Coal (Thousand Tons) Petroleum Liquids (Thousand Barrels) Petroleum Coke (Thousand Tons)Census Division December 2012December 2011 Percentage ChangeDecember 2012December 2011December 2012December 2011

New England 1,030 1,389 -25.9% W W W W Middle Atlantic 7,553 7,800 -3.2% W W W W East North Central 36,139 37,262 -3.0% 27,069 27,316 9,070 9,946 West North Central 30,554 28,544 7.0% 30,554 28,544 0 0 South Atlantic 38,859 36,920 5.3% 35,527 33,163 3,331 3,757 East South Central 19,657 17,185 14.4% 19,657 17,185 0 0 West South Central 28,807 22,910 25.7% 17,047 15,125 11,760 7,785 Mountain 20,385 18,543 9.9% W W W W Pacific Contiguous W W W W W W W Pacific Noncontiguous W W W W W W W U.S. Total 185,116 172,387 7.4% 150,942 142,103 34,174 30,284

New England 2,483 2,680 -7.3% 464 703 2,020 1,978 Middle Atlantic 5,496 6,591 -16.6% 2,482 2,931 3,014 3,660 East North Central 1,223 1,581 -22.6% 1,007 1,313 217 268 West North Central 1,052 1,297 -18.9% 1,020 1,260 31 37 South Atlantic 13,603 14,316 -5.0% 11,314 11,933 2,289 2,383 East South Central 1,928 2,064 -6.6% W W W W West South Central 2,548 2,560 -0.5% 1,953 1,901 595 659 Mountain 654 677 -3.3% W W W W Pacific Contiguous 395 424 -7.0% W 331 W 93 Pacific Noncontiguous 2,842 2,656 7.0% W W W W U.S. Total 32,224 34,847 -7.5% 23,875 25,648 8,349 9,198

New England 0 0

-- 0 0 0 0 Middle Atlantic W W W 0 0 W W East North Central 56 W W W W W W West North Central 0 W W 0 W 0 0 South Atlantic W W W W W W W East South Central W W W W W 0 0 West South Central W W W W W W 0 Mountain W W W 0 0 W W Pacific Contiguous W 5 W 0 0 W 5 Pacific Noncontiguous 0 0

-- 0 0 0 0 U.S. Total 495 508 -2.6% 414 404 81 104 Petroleum Liquids (Thousand Barrels)

Petroleum Coke (Thousand Tons)

W = Withheld to avoid disclosure of individual company data. Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding. Source: U.S. Energy Information Administration, Form-923, 'Power Plant Operations Report.' 

### Table 6.3 Stocks of Coal, Petroleum Liquids, and Petroleum Coke: Electric Power Sector, by Census Divison, 2012 and 2011 Electric Power Sector Electric Utilities Independent Power Producers

Coal (Thousand Tons)Period Bituminous Coal Subbituminous Coal Lignite Coal Total

2002 70,704 66,593 4,417 141,714 2003 57,716 59,884 3,967 121,567 2004 49,022 53,618 4,029 106,669 2005 52,923 44,377 3,836 101,137 2006 67,760 68,408 4,797 140,964 2007 63,964 82,692 4,565 151,221 2008 65,818 91,214 4,556 161,589 2009 91,922 92,448 5,097 189,467 2010 81,108 86,915 6,894 174,917 2011 82,056 85,151 5,179 172,387 2012 86,437 93,833 4,846 185,116

January 86,354 86,893 4,845 178,091 February 82,469 83,721 4,836 171,026 March 86,698 86,014 5,030 177,742

April 92,621 89,545 7,095 189,260 May 93,069 91,514 7,085 191,669 June 87,123 87,299 7,068 181,490

July 80,465 81,933 7,107 169,504 August 76,303 77,081 6,604 159,987 September 78,201 78,906 6,669 163,776 October 84,103 84,992 6,592 175,686 November 87,548 88,880 6,961 183,389 December 81,108 86,915 6,894 174,917

January 76,100 82,111 6,364 164,575 February 75,549 79,101 6,414 161,064 March 77,414 82,337 6,504 166,255

April 79,734 86,900 6,793 173,427 May 79,250 88,099 6,744 174,093 June 75,011 83,599 6,539 165,149

July 66,549 74,518 6,229 147,296 August 64,584 67,775 6,168 138,527 September 66,763 70,804 6,144 143,711 October 74,236 75,766 6,193 156,196 November 79,726 81,302 6,726 167,754 December 82,056 85,151 5,179 172,387

January 83,807 91,263 5,021 180,091 February 87,674 94,462 4,729 186,866 March 90,520 100,126 4,734 195,380

April 93,508 103,798 4,960 202,265 May 94,058 103,893 5,187 203,137 June 92,348 100,431 5,146 197,924

July 83,754 95,299 4,906 183,958 August 80,888 92,705 4,944 178,537 September 82,766 94,464 4,789 182,020 October 86,510 95,156 4,730 186,396 November 87,622 95,917 4,752 188,291 December 86,437 93,833 4,846 185,116

Notes: See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. and predecessor forms. Totals may not equal sum of components because of independent rounding. Sources: U.S. Energy Information Administration, Form EIA-906, Power Plant Report; U.S. Energy Information Administration, Form EIA-920 Combined Heat and Power Plant Report, and predecessor forms. Beginning with 2008 data, the Form EIA-923, Power Plant Operations Report, replaced the following: Form EIA-906, Power Plant Report; Form EIA-920, Combined Heat and Power Plant Report; Form EIA-423, Monthly Cost and Quality of Fuels for Electric Plants Report; and Federal Energy Regulatory Commission, FERC Form 423, Monthly Report of Cost and Quality of Fuels for Electric Plants. 

### Table 6.4. Stocks of Coal by Coal Rank: Electric Power Sector, 2002 - 2012Electric Power Sector

End of Year Stocks

2010, End of Month Stocks

2011, End of Month Stocks

2012, End of Month Stocks

# Chapter 7
Receipts, Cost, and Quality of Fossil FuelsAll Fossil Fuels Average

Cost Average Cost

Period Receipts (Thousand Tons)Average Sulfur Percent by Weight(Dollars per MMBtu)(Dollars per Ton)Receipts (Thousand Barrels)Average Sulfur Percent by Weight(Dollars per MMBtu)(Dollars per Barrel)Receipts (Thousand Mcf)(Dollars per MMBtu)(Dollars per MMBtu) 2002 884,287 0.94 1.25 25.52 120,851 1.64 3.34 20.775,607,737 3.56 1.86 2003 986,026 0.97 1.28 26.00 185,567 1.53 4.33 26.785,500,704 5.39 2.28 20041,002,032 0.97 1.36 27.42 186,655 1.66 4.29 26.565,734,054 5.96 2.48 20051,021,437 0.98 1.54 31.20 194,733 1.61 6.44 39.656,181,717 8.21 3.25 20061,079,943 0.97 1.69 34.09 100,965 2.31 6.23 37.666,675,246 6.94 3.02 20071,054,664 0.96 1.77 35.48 88,347 2.10 7.17 43.507,200,316 7.11 3.23 20081,069,709 0.97 2.07 41.14 96,341 2.21 10.87 64.897,879,046 9.02 4.11 2009 981,477 1.01 2.21 43.74 88,951 2.14 7.02 41.648,118,550 4.74 3.04 2010 979,918 1.16 2.27 44.64 75,285 2.14 9.54 56.358,673,070 5.09 3.26 2011 956,538 1.19 2.39 46.65 66,058 2.49 12.48 73.299,056,164 4.72 3.29 2012 841,183 1.25 2.38 46.09 40,364 3.61 12.48 73.309,531,389 3.42 2.83

* = Value is less than half of the smallest unit of measure. (e.g., for values with no decimals, the smallest unit is 1 then values under 0.5 are shown as *.) NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum includes Petroleum Liquids and Petroleum Coke. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants" 

### Table 7.1. Receipts, Average Cost, and Quality of Fossil Fuels for the Electric Power Industry, 2002 through 2012

Coal Petroleum Natural Gas
Average Cost Average CostPeriod Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight 2002 423,128 1.47 10.1 391,785 0.36 6.2 65,555 0.93 13.3 2003 467,286 1.50 10.0 432,513 0.38 6.4 79,869 1.03 14.4 2004 470,619 1.52 10.4 445,603 0.36 6.0 78,268 1.05 14.2 2005 480,179 1.56 10.5 456,856 0.36 6.2 77,677 1.02 14.0 2006 489,550 1.59 10.5 504,947 0.35 6.1 75,742 0.95 14.4 2007 467,817 1.62 10.3 505,155 0.34 6.0 71,930 0.90 14.0 2008 464,362 1.68 10.6 522,228 0.34 5.8 68,945 0.86 13.8 2009 418,688 1.77 10.5 484,007 0.34 5.8 64,966 0.95 14.0 2010 403,619 1.90 10.4 491,425 0.33 5.8 71,416 0.90 14.1 2011 380,184 2.01 10.5 488,366 0.33 5.8 75,675 0.90 14.4 2012 317,398 2.23 10.6 442,674 0.32 5.8 71,848 0.93 14.6 

### Table 7.2. Receipts and Quality of Coal Delivered for the Electric Power Industry, 2002 through 2012

Bituminous Subbituminous Lignite

* = Value is less than half of the smallest unit of measure. (e.g., for values with no decimals, the smallest unit is 1 then values under 0.5 are shown as *.) NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Bituminous coal includes anthracite, synthetic, and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"Natural Gas

PeriodAverage Btu per PoundAverage Sulfur Percent by WeightAverage Ash Percent by WeightAverage Btu per GallonAverage Sulfur Percent by WeightAverage Ash Percent by WeightAverage Btu per Cubic Foot 2002 10,168 0.94 8.7 147,903 1.64 0.2 1,025 2003 10,137 0.97 9.0 147,086 1.53 0.1 1,030 2004 10,074 0.97 9.0 147,286 1.66 0.2 1,027 2005 10,107 0.98 9.0 146,481 1.61 0.2 1,028 2006 10,063 0.97 9.0 143,883 2.31 0.2 1,027 2007 10,028 0.96 8.8 144,546 2.10 0.1 1,027 2008 9,947 0.97 9.0 142,205 2.21 0.3 1,027 2009 9,902 1.01 8.9 141,321 2.14 0.2 1,025 2010 9,842 1.16 8.8 140,598 2.14 0.2 1,022 2011 9,762 1.19 8.8 139,795 2.49 0.4 1,021 2012 9,668 1.25 8.8 139,567 3.61 0.5 1,023 

### Table 7.3. Average Quality of Fossil Fuel Receipts for the Electric Power Industry, 2002 through 2012

Coal Petroleum

* = Value is less than half of the smallest unit of measure. (e.g., for values with no decimals, the smallest unit is 1 then values under 0.5 are shown as *.) NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum includes Petroleum Liquids and Petroleum Coke. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"Period Receipts (Trillion Btu)Average Cost (Dollars

per MMBtu)Receipts (Trillion Btu)Average Cost (Dollars

per MMBtu)Receipts (Trillion Btu)Average Cost (Dollars

per MMBtu)Receipts (Trillion Btu)Average Cost (Dollars

per MMBtu)Receipts (Trillion Btu)Average Cost (Dollars

per MMBtu)Receipts (Trillion Btu)Average Cost (Dollars

per MMBtu)Receipts (Trillion Btu)Average Cost (Dollars

per MMBtu) 2002 10,198 1.41 6,878 1.05 851 1.04 17,982 1.25 751 3.34 5,750 3.56 24,483 1.86 2003 11,284 1.43 7,598 1.10 1,026 1.03 19,990 1.28 1,146 4.33 5,663 5.39 26,799 2.28 2004 11,260 1.55 7,817 1.12 1,012 1.06 20,189 1.36 1,155 4.29 5,891 5.96 27,234 2.48 2005 11,546 1.83 8,004 1.19 1,008 1.07 20,647 1.54 1,198 6.44 6,357 8.21 28,202 3.25 2006 11,789 2.03 8,842 1.31 982 1.15 21,735 1.69 610 6.23 6,856 6.94 29,201 3.02 2007 11,279 2.07 8,826 1.45 925 1.28 21,152 1.77 536 7.17 7,396 7.11 29,085 3.23 2008 11,119 2.50 9,087 1.62 896 1.41 21,280 2.07 575 10.87 8,089 9.02 29,945 4.11 2009 10,010 2.75 8,421 1.64 835 1.58 19,438 2.21 528 7.02 8,319 4.74 28,285 3.04 2010 9,652 2.81 8,545 1.73 925 1.62 19,290 2.27 445 9.54 8,867 5.09 28,602 3.26 2011 9,040 2.94 8,498 1.91 986 1.62 18,676 2.39 388 12.48 9,251 4.72 28,314 3.29 2012 7,502 2.89 7,722 1.97 931 1.80 16,266 2.38 237 12.48 9,747 3.42 26,249 2.83 ( g , , ) NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; coal synfuel and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Bituminous coal includes anthracite coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum includes Petroleum Liquids and Petroleum Coke. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants" 

### Table 7.4. Weighted Average Cost of Fossil Fuels for the Electric Power Industry, 2002 through 2012 Coal Petroleum Natural Gas Total Fossil

Bituminous Subbituminous Lignite All Coal RanksPeriod (Billion Btu)(Thousand Tons) (Dollars per MMBtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Barrels) (Dollars per MMBtu) (Dollars per Barrel)Average Sulfur Percent by WeightPercentage of Consumption

200213,967,326 687,747 1.22 24.74 0.87 89.6 407,442 63,809 3.74 23.88 0.99 72.0 200315,292,394 746,594 1.26 25.82 0.91 98.6 605,651 95,534 4.68 29.66 0.95 90.7 200415,440,681 758,557 1.34 27.30 0.91 98.2 592,478 93,034 4.80 30.57 1.01 89.6 200515,836,924 775,890 1.53 31.22 0.94 101.9 566,320 89,303 7.17 45.46 0.89 90.9 200616,197,852 797,361 1.69 34.26 0.92 105.8 269,033 42,415 8.33 52.80 0.82 79.2 200715,561,395 767,377 1.78 36.06 0.92 100.3 216,349 34,026 9.24 58.73 0.77 59.8 200815,347,396 764,399 2.06 41.32 0.93 100.5 240,937 38,891 15.83 98.09 0.60 99.7 200914,402,019 719,253 2.22 44.47 0.99 103.4 202,598 32,959 10.44 64.18 0.51 103.5 201014,226,995 713,094 2.27 45.33 1.14 98.8 189,790 31,099 13.94 85.07 0.48 101.0 201113,871,559 699,353 2.40 47.67 1.16 101.5 144,255 23,859 20.30 122.72 0.53 114.5 201211,939,543 609,445 2.43 47.51 1.18 99.0 86,030 14,252 22.11 133.44 0.41 81.3

January 1,101,993 55,521 2.21 43.89 1.09 82.6 23,632 3,860 13.16 80.54 0.54 88.1 February 1,073,034 53,695 2.26 45.26 1.16 90.6 13,223 2,179 13.59 82.50 0.40 136.3 March 1,231,470 61,038 2.32 46.85 1.16 108.5 11,782 1,943 14.11 85.52 0.28 109.5

April 1,168,587 57,821 2.30 46.45 1.17 115.7 8,388 1,398 14.96 89.76 0.24 85.6 May 1,168,195 58,565 2.27 45.27 1.12 103.0 16,261 2,649 13.61 83.58 0.62 102.2 June 1,169,040 58,803 2.24 44.62 1.13 90.6 18,097 2,937 13.16 81.08 0.62 80.1 July 1,209,770 60,990 2.27 44.95 1.07 87.2 21,588 3,497 13.29 82.07 0.47 98.6 August 1,294,681 64,603 2.30 46.16 1.13 92.5 20,667 3,331 13.08 81.14 0.60 103.1 September 1,208,559 60,693 2.28 45.47 1.11 104.3 18,501 2,988 13.35 82.68 0.62 138.8 October 1,235,011 61,883 2.29 45.68 1.15 120.5 11,210 1,858 14.98 90.39 0.35 117.5 November 1,172,469 58,841 2.27 45.29 1.19 111.1 12,889 2,191 15.82 93.06 0.35 147.4 December 1,194,186 60,641 2.23 43.90 1.14 93.8 13,552 2,267 16.79 100.36 0.25 71.7

January 1,181,833 59,577 2.34 46.34 1.15 90.2 14,279 2,372 16.98 102.20 0.53 107.5 February 1,078,032 54,003 2.36 47.10 1.20 99.2 9,943 1,659 18.27 109.47 0.47 104.4 March 1,163,288 58,858 2.35 46.35 1.12 108.8 13,842 2,284 19.55 118.45 0.52 131.5

April 1,093,579 55,135 2.39 47.33 1.14 111.5 11,543 1,898 20.30 123.47 0.40 90.8 May 1,100,898 55,254 2.44 48.70 1.16 100.5 16,158 2,618 19.03 117.46 0.75 138.8 June 1,123,670 56,315 2.39 47.78 1.20 89.8 15,427 2,528 21.88 133.55 0.66 144.9 July 1,135,869 56,951 2.45 48.91 1.18 81.4 9,455 1,569 21.86 131.77 0.47 82.3 August 1,252,336 62,531 2.49 49.81 1.18 91.8 9,575 1,579 20.63 125.10 0.43 90.3 September 1,217,947 61,325 2.46 48.78 1.17 109.8 10,186 1,683 20.94 126.69 0.49 118.0 October 1,200,982 60,696 2.41 47.77 1.14 119.9 13,068 2,171 21.63 130.21 0.48 146.6 November 1,145,469 58,329 2.39 46.88 1.15 119.3 11,052 1,853 21.75 129.72 0.48 124.5 December 1,177,657 60,381 2.37 46.18 1.14 111.5 9,729 1,645 21.94 129.73 0.48 106.9

January 1,065,584 54,942 2.39 46.44 1.14 105.0 8,221 1,366 21.73 130.71 0.42 91.4 February 977,965 50,084 2.41 47.06 1.22 106.8 5,975 995 22.16 133.14 0.38 79.9 March 948,751 48,359 2.44 47.94 1.21 111.4 7,907 1,294 22.94 140.22 0.42 95.1

April 873,863 43,906 2.49 49.64 1.27 110.0 6,007 1,002 23.78 142.55 0.48 74.8 May 929,247 47,009 2.47 48.73 1.25 100.2 6,122 1,029 23.35 138.90 0.46 71.4 June 952,000 48,574 2.42 47.38 1.20 90.4 9,006 1,481 22.42 136.33 0.47 85.5 July 1,051,379 53,700 2.44 47.70 1.15 83.3 9,357 1,538 20.71 126.01 0.40 75.7 August 1,118,779 56,932 2.43 47.75 1.16 92.6 7,640 1,266 21.17 127.71 0.40 79.3 September 1,011,975 51,891 2.43 47.40 1.12 100.7 6,246 1,026 21.88 133.24 0.37 80.2 October 1,013,074 51,751 2.40 47.07 1.16 105.5 6,497 1,074 22.21 134.37 0.29 78.3 November 999,479 51,032 2.40 46.93 1.17 99.5 5,800 970 22.46 134.34 0.34 75.6 December 997,447 51,264 2.39 46.58 1.19 94.0 7,253 1,212 21.36 127.87 0.42 90.1 

### Table 7.5. Receipts, Average Cost, and Quality of Fossil Fuels: Electric Utilities, 2002 - 2012 Coal Petroleum Liquids Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"All Fossil Fuels Average Cost

Period (Billion Btu)(Thousand Tons) (Dollars per MMbtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Mcf) (Dollars per MMBtu) (Dollars per Mcf)Percentage of Consumption(Dollars per MMBtu)

2002 75,711 2,677 0.63 17.68 4.98 126.0 1,680,518 1,634,734 3.68 3.78 72.3 1.53 2003 89,618 3,165 0.74 20.94 5.51 124.0 1,486,088 1,439,513 5.59 5.77 81.6 1.74 2004 107,985 3,817 0.89 25.15 5.10 92.0 1,542,746 1,499,933 6.15 6.33 82.9 1.87 2005 102,450 3,632 1.29 36.31 5.16 87.9 1,835,221 1,780,721 8.32 8.57 83.4 2.38 2006 99,471 3,516 1.49 42.21 5.11 97.2 2,222,289 2,163,113 7.36 7.56 87.3 2.45 2007 84,812 2,964 1.73 49.57 5.09 105.6 2,378,104 2,315,637 7.47 7.67 84.6 2.61 2008 80,987 2,843 2.13 60.51 5.36 123.8 2,856,354 2,784,642 9.15 9.39 102.0 3.33 2009 109,126 3,833 1.68 47.84 5.02 138.8 3,033,133 2,962,640 5.50 5.63 101.8 2.87 2010 103,152 3,628 2.38 67.65 5.03 109.1 3,395,962 3,327,919 5.43 5.54 101.1 2.99 2011 99,208 3,445 3.08 88.73 5.17 99.9 3,571,348 3,507,613 5.00 5.09 101.8 3.08 2012 72,782 2,521 2.30 66.40 5.46 119.8 4,083,579 4,003,457 3.74 3.81 97.6 2.86

January 9,040 317 1.76 50.18 5.38 112.1 254,841 249,848 6.93 7.07 102.0 3.26 February 5,337 188 1.96 55.49 5.09 72.9 217,554 213,267 6.39 6.52 100.6 3.06 March 8,021 284 2.24 63.36 4.99 92.2 214,554 210,587 5.72 5.83 101.3 2.91

April 9,899 347 2.30 65.45 5.03 137.3 218,064 213,690 5.20 5.30 101.6 2.82 May 7,673 269 2.32 66.03 4.99 103.1 270,661 265,218 5.20 5.30 101.3 2.94 June 8,998 317 2.22 63.05 5.32 99.2 324,142 317,528 5.42 5.54 101.0 3.05 July 9,979 354 2.50 70.63 4.71 103.9 399,566 391,191 5.47 5.58 100.8 3.19 August 11,742 410 2.69 76.96 4.91 143.5 421,843 413,154 5.24 5.35 100.4 3.14 September 10,150 355 2.71 77.34 4.93 120.0 315,571 308,882 4.81 4.92 100.9 2.93 October 8,639 301 2.51 72.03 4.90 123.2 269,281 263,756 4.77 4.87 101.4 2.82 November 5,740 208 2.28 62.94 5.22 103.3 226,257 222,019 4.73 4.83 101.2 2.79 December 7,933 277 2.75 78.60 5.05 101.0 263,628 258,780 5.64 5.75 101.8 2.97

January 8,049 282 3.35 95.62 5.29 70.5 250,362 245,767 5.49 5.59 103.0 3.03 February 7,252 252 3.02 87.15 5.43 85.3 219,131 214,884 5.34 5.45 102.9 2.98 March 7,009 241 3.32 96.60 5.70 70.2 224,855 220,793 4.95 5.04 101.5 2.93

April 7,274 252 3.52 101.68 5.20 115.4 255,479 251,362 5.19 5.27 103.1 3.07 May 7,519 261 3.57 102.83 5.01 112.7 278,209 273,629 5.17 5.25 101.8 3.18 June 8,072 278 2.85 82.53 5.08 92.2 341,274 335,202 5.28 5.37 101.5 3.26 July 10,742 374 3.41 98.06 4.79 104.0 443,001 434,122 5.11 5.22 100.9 3.31 August 10,040 349 3.18 91.43 5.26 105.9 434,451 425,557 4.97 5.07 101.1 3.22 September 9,822 341 2.94 84.64 5.14 102.3 316,215 311,382 4.89 4.97 101.5 3.08 October 8,352 289 3.23 93.48 5.11 126.2 275,463 270,541 4.71 4.80 101.4 3.01 November 7,303 253 2.11 60.87 5.15 163.4 250,718 246,675 4.50 4.57 101.8 2.91 December 7,774 273 2.34 66.68 5.09 108.4 282,188 277,700 4.40 4.47 102.5 2.88

January 7,379 255 2.45 71.02 4.81 85.9 279,420 274,897 4.05 4.12 96.4 2.85 February 6,359 217 2.46 71.86 5.19 94.5 273,306 268,688 3.72 3.79 97.7 2.78 March 5,557 194 1.93 55.37 5.76 181.7 293,402 288,321 3.39 3.45 97.6 2.79

April 4,870 169 1.98 57.09 5.08 140.6 323,371 315,071 3.12 3.21 98.1 2.76 May 4,136 143 2.75 79.88 5.42 95.2 376,312 368,744 3.27 3.33 97.8 2.79 June 5,504 188 2.40 70.40 5.87 110.8 400,778 392,707 3.42 3.49 97.4 2.84 July 3,695 127 2.64 76.56 5.84 70.0 491,080 480,504 3.64 3.72 97.7 2.92 August 5,434 188 2.62 75.86 5.63 110.5 444,330 435,215 3.80 3.88 97.3 2.91 September 8,450 294 2.50 71.95 5.53 162.9 356,511 349,654 3.74 3.82 97.4 2.85 October 7,203 251 2.07 59.25 5.53 161.4 304,602 298,960 4.18 4.26 98.1 2.90 November 6,304 221 2.00 57.04 5.51 126.3 262,811 257,894 4.49 4.58 97.3 2.91 December 7,891 276 2.05 58.55 5.55 162.2 277,655 272,801 4.47 4.55 98.5 2.94 

### Table 7.6. Receipts, Average Cost, and Quality of Fossil Fuels: Electric Utilities, 2002 - 2012 (continued)

Petroleum Coke Natural Gas Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"Period (Billion Btu)(Thousand Tons) (Dollars per MMBtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Barrels) (Dollars per MMBtu) (Dollars per Barrel)Average Sulfur Percent by WeightPercentage of Consumption

2002 3,710,847 182,482 1.37 27.96 1.15 87.0 186,271 30,043 4.19 25.98 0.61 76.4 2003 4,365,996 223,984 1.34 26.20 1.15 90.4 347,546 56,138 5.41 33.50 0.58 89.7 2004 4,410,775 227,700 1.41 27.27 1.13 93.3 337,011 54,152 5.35 33.31 0.61 93.6 2005 4,459,333 229,071 1.56 30.39 1.10 83.0 381,871 61,753 8.30 51.34 0.54 97.2 2006 5,204,402 266,856 1.69 33.04 1.09 97.7 117,524 19,236 9.65 58.98 0.45 104.9 2007 5,275,454 273,216 1.71 33.11 1.06 97.5 125,025 20,486 10.49 64.01 0.45 85.0 2008 5,395,142 281,258 2.03 38.98 1.04 100.4 82,124 13,657 16.30 98.03 0.41 94.4 2009 4,563,080 240,687 2.11 39.94 1.06 101.1 68,030 11,408 10.02 59.76 0.37 102.0 2010 4,555,898 243,585 2.20 41.15 1.21 96.0 49,598 8,420 14.80 87.19 0.35 89.9 2011 4,292,284 233,295 2.28 41.95 1.25 95.9 41,599 7,096 20.30 119.01 0.50 106.9 2012 4,036,436 218,341 2.21 40.92 1.42 104.9 23,922 4,073 22.34 131.28 0.44 79.8

January 376,680 19,830 2.21 42.01 1.20 85.3 5,186 895 14.92 86.41 0.30 75.4 February 343,015 18,198 2.21 41.75 1.18 88.3 2,397 416 14.78 85.23 0.30 78.2 March 401,656 21,348 2.23 41.96 1.20 107.5 4,487 747 13.69 82.23 0.55 201.3

April 359,489 19,062 2.23 41.96 1.25 113.2 2,017 354 15.12 86.17 0.30 90.2 May 374,626 19,964 2.19 41.15 1.28 106.5 2,963 508 15.27 89.08 0.36 86.2 June 342,601 18,471 2.19 40.68 1.22 83.4 4,357 738 14.22 83.97 0.33 87.9 July 370,780 20,113 2.23 41.09 1.12 81.8 6,753 1,125 13.66 81.95 0.41 67.0 August 414,300 21,970 2.23 42.11 1.25 90.1 4,622 777 14.55 86.52 0.27 75.1 September 404,409 21,646 2.20 41.04 1.23 103.2 4,031 678 13.97 83.02 0.31 95.5 October 412,301 22,106 2.15 40.10 1.23 115.5 3,720 626 15.45 91.85 0.35 135.1 November 387,870 20,899 2.15 39.94 1.19 106.9 3,898 679 16.19 92.92 0.36 120.4 December 368,173 19,977 2.18 40.13 1.18 84.9 5,167 876 16.62 97.98 0.31 87.6

January 381,239 20,717 2.23 40.96 1.20 86.5 4,653 783 17.44 103.58 0.56 71.2 February 336,384 18,030 2.26 42.18 1.29 94.7 3,276 560 18.64 108.99 0.77 118.7 March 363,257 19,787 2.26 41.58 1.19 107.9 2,270 392 21.18 122.73 0.55 92.1

April 330,831 17,944 2.28 42.03 1.21 102.6 3,235 550 21.43 126.18 0.27 144.8 May 348,283 18,569 2.32 43.58 1.33 101.0 2,752 466 21.66 127.89 0.59 108.5 June 330,390 17,898 2.34 43.25 1.23 84.4 3,232 553 20.81 121.69 0.48 87.0 July 351,423 19,120 2.35 43.14 1.24 79.4 5,604 955 21.18 124.33 0.40 91.4 August 386,958 20,994 2.34 43.11 1.26 87.9 2,883 497 16.66 96.71 0.49 86.7 September 377,183 20,755 2.31 42.04 1.25 100.2 2,674 462 22.29 129.10 0.53 107.1 October 379,229 20,611 2.25 41.35 1.27 109.6 3,946 655 20.28 122.12 0.52 178.5 November 357,960 19,649 2.24 40.77 1.24 108.9 3,617 635 20.57 117.22 0.44 175.8 December 349,148 19,221 2.18 39.64 1.23 100.0 3,457 589 22.35 131.11 0.47 140.6

January 388,350 21,060 2.26 41.77 1.31 115.4 2,714 456 22.60 134.74 0.30 105.3 February 337,872 18,053 2.27 42.45 1.46 113.6 1,746 295 23.54 139.55 0.43 98.9 March 301,945 16,043 2.19 41.20 1.38 115.8 893 151 24.81 146.34 0.43 63.0

April 279,069 14,935 2.14 39.96 1.36 128.0 1,229 210 25.16 147.95 0.44 77.7 May 301,903 16,397 2.21 40.78 1.39 104.1 1,913 324 23.65 139.61 0.42 75.9 June 319,532 17,466 2.14 39.18 1.56 98.3 2,573 433 21.63 128.42 0.44 71.3 July 327,180 17,996 2.24 40.71 1.31 82.4 2,341 397 20.68 121.95 0.56 61.1 August 359,430 19,491 2.25 41.57 1.42 92.8 1,813 310 21.95 128.49 0.44 73.6 September 347,329 18,971 2.17 39.83 1.41 106.6 1,531 262 W W 0.48 81.4 October 360,456 19,549 2.19 40.38 1.41 113.1 1,785 306 23.25 135.64 0.43 87.1 November 365,210 19,708 2.22 41.11 1.46 106.7 2,446 410 22.75 135.68 0.40 108.5 December 348,160 18,669 2.24 41.72 1.50 101.0 2,937 518 19.60 110.92 0.51 73.8 

### Table 7.7 Receipts, Average Cost, and Quality of Fossil Fuels: Independent Power Producers, 2002 - 2012 Coal Petroleum Liquids Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"All Fossil Fuels Average Cost

Period (Billion Btu)(Thousand Tons) (Dollars per MMbtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Mcf) (Dollars per MMBtu) (Dollars per Mcf)Percentage of Consumption(Dollars per MMBtu)

2002 47,805 1,639 1.03 29.98 4.85 44.4 3,198,108 3,126,308 3.55 3.63 91.6 2.42 2003 59,377 2,086 0.60 17.16 4.88 64.3 3,335,086 3,244,368 5.33 5.48 96.2 3.15 2004 73,745 2,609 0.72 20.30 4.95 81.0 3,491,942 3,403,474 5.86 6.01 93.1 3.43 2005 92,706 3,277 0.90 25.42 5.09 82.9 3,675,165 3,578,722 8.20 8.42 95.8 4.69 2006 85,924 3,031 1.07 30.34 5.13 87.1 3,742,865 3,647,102 6.66 6.84 97.4 3.82 2007 56,580 1,994 1.02 28.95 4.88 69.3 4,097,825 3,990,546 6.92 7.11 97.2 4.06 2008 79,122 2,788 1.47 41.85 4.63 98.8 4,061,830 3,956,155 8.93 9.17 100.5 5.07 2009 49,619 1,732 1.31 37.63 3.87 93.6 4,087,573 3,987,721 4.30 4.41 100.7 3.18 2010 30,079 1,050 1.74 49.80 3.84 72.3 4,212,611 4,119,103 4.94 5.05 100.6 3.57 2011 33,643 1,175 2.54 72.85 4.55 84.6 4,252,040 4,158,617 4.62 4.72 100.8 3.52 2012 23,024 801 0.82 23.98 5.49 92.1 4,810,553 4,696,637 3.17 3.25 93.8 2.74

January 3,804 133 1.44 41.35 3.37 101.7 308,109 301,125 6.75 6.90 100.1 4.32 February 2,918 101 1.48 42.64 3.46 77.2 274,889 268,803 5.95 6.08 100.4 3.91 March 3,499 121 1.63 47.30 3.33 101.4 256,384 250,712 5.06 5.17 100.7 3.39

April 1,376 47 1.08 31.18 4.33 40.8 267,989 261,844 4.48 4.58 100.2 3.22 May 2,468 86 1.78 50.77 3.83 62.4 306,425 299,565 4.55 4.65 100.6 3.30 June 2,619 91 1.75 50.31 4.00 60.0 401,342 392,478 5.01 5.12 100.3 3.77 July 2,705 95 1.94 55.02 4.47 58.5 522,419 510,999 5.04 5.15 100.4 3.94 August 1,779 64 2.26 63.33 3.98 59.1 546,215 534,075 4.72 4.82 100.5 3.70 September 1,349 47 2.36 67.67 3.01 61.5 401,881 393,000 4.27 4.36 100.6 3.28 October 3,342 117 2.01 57.26 3.88 116.1 321,547 314,248 4.00 4.09 101.3 3.02 November 2,286 80 1.76 50.12 4.24 80.2 285,549 279,359 4.23 4.33 100.8 3.10 December 1,933 67 1.63 46.81 4.67 57.6 319,863 312,895 5.49 5.62 100.9 3.81

January 1,730 60 W W 4.24 46.8 309,865 303,301 5.59 5.71 100.7 W February 1,809 64 W W 4.21 52.2 283,811 277,469 5.06 5.17 100.9 W March 2,563 89 W W 3.37 54.8 271,713 265,931 4.57 4.67 100.6 W

April 3,046 106 2.36 67.43 3.57 103.0 284,857 278,599 4.71 4.82 100.4 3.49 May 3,339 116 2.44 70.04 4.01 103.9 312,436 305,861 4.75 4.85 100.9 3.54 June 2,623 92 1.99 56.95 4.81 78.6 379,462 371,553 4.95 5.05 100.7 3.80 July 3,119 107 2.39 69.60 4.60 75.3 520,203 508,834 4.94 5.05 100.1 4.00 August 3,166 110 W W 4.84 90.6 515,581 504,743 4.57 4.67 100.9 W September 2,511 88 W W 4.87 83.4 391,415 382,298 4.39 4.49 101.3 W October 3,603 126 W W 5.08 139.5 320,549 313,229 4.12 4.22 101.6 W November 2,652 94 W W 5.52 108.9 308,988 301,865 3.92 4.01 100.5 W December 3,483 123 W W 5.08 125.6 353,160 344,934 3.86 3.95 100.6 W

January 2,378 84 0.75 21.66 5.78 81.3 349,484 341,570 3.44 3.52 93.9 2.83 February 2,027 71 W W 5.74 80.6 354,095 345,712 3.08 3.15 93.6 W March 2,331 81 W W 5.72 113.6 361,777 353,324 2.65 2.72 93.3 W

April 1,925 67 W W 5.46 145.3 381,808 373,193 2.34 2.40 94.9 W May 1,868 65 W W 5.66 105.2 421,157 411,534 2.68 2.74 94.5 W June 2,609 90 1.52 44.78 5.17 153.1 460,670 449,871 2.85 2.92 94.4 2.59 July 2,447 86 1.37 40.26 5.40 119.6 568,098 555,197 3.28 3.35 94.2 2.89 August 1,096 38 1.02 29.88 5.35 39.1 533,502 520,978 3.25 3.32 93.6 2.84 September 832 29 W W 5.05 40.7 431,134 420,686 3.17 3.25 94.8 W October 951 33 W W 5.25 45.2 351,334 342,548 3.63 3.72 94.0 W November 2,194 76 W W 5.33 120.2 296,103 288,823 4.16 4.26 91.8 W December 2,364 82 W W 5.58 125.5 301,391 293,201 4.03 4.14 90.9 W 

### Table 7.8. Receipts, Average Cost, and Quality of Fossil Fuels: Independent Power Producers, 2002 - 2012 (continued)

Petroleum Coke Natural Gas Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"Period (Billion Btu)(Thousand Tons) (Dollars per MMBtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Barrels) (Dollars per MMBtu) (Dollars per Barrel)Average Sulfur Percent by WeightPercentage of Consumption

2002 9,580 399 2.10 50.44 2.59 28.4 503 91 5.38 29.73 0.02 7.5 2003 8,835 372 1.99 47.24 2.43 20.5 248 43 7.00 40.82 0.04 3.1 2004 10,682 451 2.08 49.32 2.48 23.5 3,066 527 6.19 35.96 0.20 26.9 2005 11,081 464 2.57 61.21 2.43 24.2 1,684 289 8.28 48.22 0.17 18.3 2006 12,207 518 2.63 61.95 2.51 27.5 798 137 13.50 78.70 0.17 15.5 2007 12,419 531 2.67 62.46 2.58 27.6 249 43 14.04 81.93 0.17 6.2 2008 43,997 2,009 2.65 58.12 1.73 99.4 3,800 633 17.84 107.10 0.37 102.0 2009 41,182 1,876 2.90 63.68 1.67 104.3 3,517 583 10.82 65.26 0.45 122.1 2010 37,778 1,747 2.82 61.06 1.77 101.6 2,395 400 15.24 91.25 0.38 106.3 2011 35,892 1,686 2.92 62.24 1.78 101.1 1,959 325 19.67 118.66 0.55 108.0 2012 4,427 192 3.41 78.71 2.75 13.2 247 43 W W 0.00 11.0

January 3,452 162 2.79 59.44 1.73 83.9 NM NM NM NM 0.43 77.6 February 3,364 156 2.87 61.93 1.78 93.2 NM NM NM NM 0.38 73.4 March 3,478 161 2.90 62.65 1.64 107.7 NM NM NM NM 0.45 330.9

April 2,983 137 2.80 61.12 1.47 116.7 NM NM NM NM 0.23 81.8 May 2,820 132 2.71 58.00 1.41 111.4 NM NM NM NM 0.48 106.2 June 2,874 132 2.99 65.29 1.97 97.6 NM NM NM NM 0.42 116.2 July 2,933 132 2.83 62.64 2.07 93.4 NM NM NM NM 0.35 72.4 August 3,381 157 2.79 60.14 1.87 103.2 NM NM NM NM 0.41 58.4 September 3,045 141 2.85 61.82 1.84 105.8 NM NM NM NM 0.35 122.5 October 2,864 133 2.82 60.52 1.71 109.9 NM NM NM NM 0.31 283.6 November 3,365 155 2.86 62.19 1.75 121.1 NM NM NM NM 0.35 145.5 December 3,217 151 2.69 57.30 1.96 91.5 NM NM NM NM 0.31 89.2

January 3,297 155 2.80 59.41 1.84 82.3 NM NM NM NM 0.62 49.1 February 3,289 154 2.88 61.47 1.79 88.9 NM NM NM NM 0.63 104.3 March 3,388 161 2.79 58.87 1.74 97.7 NM NM NM NM 0.55 165.7

April 2,649 126 2.79 58.65 1.92 101.9 NM NM NM NM 0.30 160.4 May 2,730 127 3.08 66.22 1.75 102.4 NM NM NM NM 0.72 127.4 June 3,222 147 3.16 68.99 1.79 113.1 NM NM NM NM 0.65 215.3 July 2,954 137 3.04 65.63 1.90 94.3 NM NM NM NM 0.43 171.7 August 2,881 132 3.12 68.18 1.88 101.9 NM NM NM NM 0.51 126.1 September 2,710 126 3.01 64.84 1.80 102.8 NM NM NM NM 0.53 71.7 October 2,789 136 2.74 56.21 1.56 123.7 NM NM NM NM 0.52 225.0 November 2,922 140 2.82 58.95 1.72 119.0 NM NM NM NM 0.52 101.0 December 3,061 145 2.87 60.55 1.71 104.4 NM NM NM NM 0.51 163.2

January 399 17 W W 2.86 11.3 10 2 23.14 133.20 0.00 2.2 February 394 17 3.62 83.49 2.90 12.7 2 0 W W 0.00 1.7 March 416 18 3.50 81.68 2.65 14.0 2 0 W W 0.00 1.5

April 523 22 W W 1.62 21.2 14 3 W W 0.00 13.8 May 409 18 3.71 85.51 2.70 16.4 5 1 W W 0.00 3.3 June 291 13 W W 2.57 11.7 48 8 W W 0.00 30.3 July 239 10 W W 2.87 8.6 21 4 W W 0.00 6.5 August 464 21 W W 2.69 17.1 47 8 W W 0.00 24.8 September 241 11 W W 3.13 9.9 19 3 W W 0.00 16.5 October 159 7 W W 3.53 6.9 42 7 W W 0.00 31.5 November 380 17 W W 3.19 13.5 18 3 W W 0.00 10.1 December 511 22 2.94 67.86 3.21 15.7 18 3 W W 0.00 10.3 

### Table 7.9. Receipts, Average Cost, and Quality of Fossil Fuels: Commercial Sector, 2002 - 2012 Coal Petroleum Liquids Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"All Fossil Fuels Average Cost

Period (Billion Btu)(Thousand Tons) (Dollars per MMbtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Mcf) (Dollars per MMBtu) (Dollars per Mcf)Percentage of Consumption(Dollars per MMBtu)

2002 0 0

-- -- -- -- 18,671 18,256 3.44 3.52 24.7 3.03 2003 0 0

-- -- -- 0.0 18,169 17,827 4.96 5.06 30.5 4.02 2004 0 0

-- -- -- 0.0 16,176 15,804 5.93 6.07 21.9 4.58 2005 0 0

-- -- -- 0.0 17,600 17,142 8.38 8.60 25.2 6.25 2006 0 0

-- -- -- 0.0 21,369 20,819 8.33 8.55 30.7 6.42 2007 0 0

-- -- -- 0.0 23,502 22,955 7.99 8.18 32.8 6.20 2008 370 14 2.14 58.36 5.53 135.3 71,670 69,877 9.01 9.24 105.5 6.94 2009 252 9 1.65 46.54 5.11 102.8 81,134 79,308 5.18 5.30 105.0 4.58 2010 410 15 2.19 60.59 5.67 122.5 92,055 90,130 5.39 5.51 105.1 4.83 2011 268 9 W W 5.46 147.4 95,287 93,306 5.20 5.31 107.2 W 2012 0 0

-- -- -- 0.0 18,315 18,008 5.88 5.98 16.2 W

January 38 1 NM NM 5.45 100.4 7,928 7,757 6.92 7.07 107.0 5.82 February NM NM NM NM 5.45 99.4 7,189 7,040 6.55 6.69 106.3 5.51 March 41 2 NM NM 5.45 104.6 7,062 6,916 5.83 5.96 105.1 5.19

April 20 1 NM NM 5.45 81.3 6,394 6,258 5.09 5.20 104.5 4.48 May NM NM NM NM 5.45 0.0 6,102 5,980 5.10 5.21 104.2 4.55 June NM NM NM NM 5.45 0.0 6,583 6,449 5.25 5.36 104.3 4.74 July NM NM NM NM 5.83 0.0 8,579 8,397 5.24 5.36 103.5 4.83 August NM NM NM NM 5.83 98.0 9,335 9,139 5.09 5.20 103.8 4.58 September NM NM NM NM 5.83 83.1 7,936 7,765 4.65 4.75 103.8 4.30 October 42 2 NM NM 5.83 120.6 7,954 7,785 4.69 4.80 104.8 4.47 November NM NM NM NM 5.83 93.1 7,758 7,601 4.67 4.76 106.6 4.24 December 58 2 NM NM 5.83 110.3 9,235 9,043 5.63 5.75 106.9 5.09

January 42 1 W W 5.16 98.3 NM NM 6.00 6.13 107.7 W February 36 1 W W 5.29 105.1 NM NM 5.76 5.88 108.6 W March 34 1 W W 5.54 81.8 NM NM 5.46 5.58 107.0 W

April NM NM W W 5.45 0.0 NM NM 5.40 5.52 106.3 W May NM NM W W 5.83 0.0 NM NM 5.28 5.39 105.7 W June NM NM W W 5.83 0.0 NM NM 5.40 5.51 106.3 W July NM NM W W 5.83 0.0 NM NM 5.24 5.35 104.5 W August NM NM W W 5.83 0.0 NM NM 5.09 5.20 106.4 W September NM NM W W 5.83 0.0 NM NM 4.92 5.04 108.2 W October NM NM W W 5.27 0.0 NM NM 4.87 4.98 107.5 W November NM NM W W 5.34 62.8 NM NM 4.68 4.77 110.3 W December 44 2 W W 5.29 98.8 NM NM 4.61 4.70 109.0 W

January 0 0

-- -- -- 0.0 1,688 1,657 6.82 6.95 18.1 W February 0 0

-- -- -- 0.0 1,758 1,727 6.32 6.43 19.6 W March 0 0

-- -- -- 0.0 1,587 1,560 6.24 6.35 17.6 W

April 0 0

-- -- -- 0.0 1,465 1,438 5.45 5.55 16.9 W May 0 0

-- -- -- 0.0 1,230 1,208 5.51 5.61 13.7 W June 0 0

-- -- -- 0.0 1,265 1,244 5.49 5.58 12.9 W July 0 0

-- -- -- 0.0 1,530 1,507 5.30 5.39 12.4 W August 0 0

-- -- -- 0.0 1,273 1,255 5.79 5.88 11.9 W September 0 0

-- -- -- 0.0 1,495 1,477 5.25 5.32 15.9 W October 0 0

-- -- -- 0.0 1,733 1,705 5.47 5.56 19.8 W November 0 0

-- -- -- 0.0 1,593 1,565 6.41 6.52 18.9 W December 0 0

-- -- -- 0.0 1,698 1,666 6.17 6.29 20.1 W 

### Table 7.10. Receipts, Average Cost, and Quality of Fossil Fuels: Commerical Sector, 2002 - 2012 (continued)

Petroleum Coke Natural Gas Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"Period (Billion Btu)(Thousand Tons) (Dollars per MMBtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Barrels) (Dollars per MMBtu) (Dollars per Barrel)Average Sulfur Percent by WeightPercentage of Consumption

2002 294,234 13,659 1.45 31.29 1.56 52.1 29,137 4,638 3.55 22.33 1.24 26.5 2003 322,547 15,076 1.45 31.01 1.37 60.7 27,538 4,624 4.85 28.86 1.25 23.2 2004 326,495 15,324 1.63 34.79 1.43 57.6 25,491 4,107 4.98 30.93 1.38 18.5 2005 339,968 16,011 1.94 41.17 1.42 61.9 36,383 5,876 6.64 41.13 1.36 26.4 2006 320,640 15,208 2.03 42.76 1.47 60.2 19,514 3,214 7.57 45.95 1.30 21.2 2007 303,091 13,540 2.20 49.16 1.36 60.1 33,637 5,514 8.53 52.06 1.33 38.8 2008 493,724 22,044 2.72 60.96 1.28 100.7 48,822 7,958 12.50 76.69 1.01 109.0 2009 431,686 19,661 2.81 61.68 1.22 99.5 55,899 9,232 9.83 59.52 0.83 112.8 2010 468,991 21,492 2.75 60.08 1.26 87.2 33,276 5,554 13.21 79.15 0.93 125.6 2011 476,108 22,204 2.93 62.86 1.33 99.5 28,939 4,878 17.67 104.83 1.08 144.8 2012 285,172 13,206 3.02 65.24 1.33 65.8 6,739 1,095 W W 1.52 40.8

January 34,732 1,580 2.79 61.38 1.32 75.5 4,869 811 12.80 76.83 0.94 140.8 February 35,539 1,606 2.83 62.50 1.28 81.2 2,888 477 12.58 76.17 1.19 97.5 March 41,435 1,865 2.80 62.26 1.30 87.8 2,546 422 12.80 77.21 1.06 121.4

April 37,998 1,713 2.76 61.15 1.25 77.2 1,616 271 13.57 80.84 1.03 84.1 May 38,477 1,743 2.72 59.95 1.20 86.7 2,427 406 12.92 77.32 0.86 136.6 June 42,012 2,008 2.71 56.76 1.14 105.8 2,655 444 12.67 75.80 0.83 172.6 July 39,484 1,797 2.75 60.33 1.24 84.7 2,876 482 12.77 76.20 0.77 143.4 August 45,083 2,150 2.68 56.26 1.25 98.0 2,922 487 12.69 76.05 0.93 177.9 September 39,511 1,795 2.80 61.55 1.23 92.5 2,454 412 12.85 76.49 0.84 152.2 October 39,628 1,808 2.74 60.11 1.27 92.4 NM NM NM NM 0.92 99.6 November 38,003 1,732 2.74 60.17 1.31 93.4 2,347 396 14.71 87.06 0.90 107.5 December 37,089 1,694 2.74 60.05 1.36 75.4 3,487 579 14.82 89.26 0.91 112.4

January 41,774 1,929 2.88 62.38 1.31 92.7 3,443 575 15.11 90.47 1.33 124.6 February 36,699 1,689 2.89 62.91 1.34 93.8 2,346 394 15.91 94.86 1.27 114.7 March 38,893 1,813 2.86 61.26 1.36 95.8 2,408 404 17.46 104.16 1.17 129.5

April 38,978 1,827 2.93 62.47 1.28 102.3 2,648 446 17.97 106.58 0.86 173.1 May 36,984 1,731 2.97 63.47 1.27 94.3 NM NM NM NM 1.16 225.1 June 39,329 1,826 2.93 63.01 1.34 99.1 2,628 447 19.51 114.66 0.94 176.7 July 39,487 1,850 2.96 63.18 1.32 95.1 1,869 318 19.19 112.81 0.99 141.5 August 44,259 2,057 3.01 64.88 1.36 104.8 1,840 308 16.33 97.49 1.08 132.6 September 40,384 1,886 2.91 62.21 1.35 105.5 1,785 301 18.39 109.02 1.02 129.7 October 38,861 1,824 2.94 62.68 1.30 104.4 2,410 407 18.70 110.71 0.87 143.6 November 38,803 1,816 2.94 62.81 1.39 106.1 NM NM 18.91 110.85 0.99 154.1 December 41,657 1,957 2.96 62.90 1.33 101.7 1,957 329 19.58 116.55 1.15 122.4

January 26,254 1,221 W W 1.35 60.6 700 113 17.49 108.36 1.64 23.6 February 22,263 1,040 2.99 63.96 1.36 56.8 503 82 W W 1.46 37.0 March 22,967 1,071 3.06 65.58 1.23 63.6 879 147 W W 1.15 54.3

April 22,649 1,044 W W 1.37 70.5 538 87 W W 1.47 44.5 May 22,811 1,053 3.07 66.43 1.42 67.4 556 91 W W 1.40 45.8 June 22,523 1,037 W W 1.45 66.8 515 84 W W 1.52 50.8 July 24,473 1,143 W W 1.30 66.8 776 125 W W 1.63 74.9 August 26,133 1,208 W W 1.36 70.9 540 88 W W 1.62 47.6 September 23,802 1,098 W W 1.24 71.5 413 66 W W 1.71 40.5 October 24,214 1,117 W W 1.28 70.4 394 64 W W 1.58 25.8 November 23,495 1,089 W W 1.32 66.0 359 58 W W 1.54 31.5 December 23,589 1,085 3.02 65.67 1.30 61.9 565 91 W W 1.67 43.2 

### Table 7.11. Receipts, Average Cost, and Quality of Fossil Fuels: Industrial Sector, 2002 - 2012 Coal Petroleum Liquids Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Coal includes anthracite, bituminous, subbituminous, lignite, and waste coal; synthetic coal and refined coal; and beginning in 2011, coal-derived synthesis gas. Prior to 2011 coal-derived synthesis gas was included in Other Gases. Petroleum Liquids includes distillate and residual fuel oils, jet fuel, kerosene, waste oil, and beginning in 2011, propane. Prior to 2011 propane was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"All Fossil Fuels Average Cost

Period (Billion Btu)(Thousand Tons) (Dollars per MMbtu) (Dollars per Ton)Average Sulfur Percent by WeightPercentage of Consumption (Billion Btu)(Thousand Mcf) (Dollars per MMBtu) (Dollars per Mcf)Percentage of Consumption(Dollars per MMBtu)

2002 3,846 138 0.76 21.20 5.91 9.1 852,547 828,439 3.36 3.46 66.8 2.88 2003 16,383 594 1.04 28.74 5.73 47.3 823,681 798,996 5.32 5.48 69.9 4.20 2004 14,876 540 0.98 27.01 5.59 40.4 839,886 814,843 6.04 6.22 68.4 4.76 2005 16,620 594 1.21 33.75 5.44 58.2 828,882 805,132 8.00 8.24 74.3 6.18 2006 17,875 646 1.63 45.05 5.43 42.7 869,157 844,211 7.02 7.22 75.7 5.64 2007 19,700 698 1.96 55.42 5.52 43.6 896,803 871,178 6.97 7.18 82.9 5.78 2008 39,246 1,396 3.34 93.84 4.92 117.9 1,099,613 1,068,372 8.95 9.22 111.9 7.10 2009 38,924 1,381 1.80 50.82 4.51 114.2 1,117,489 1,088,880 4.27 4.38 110.0 4.02 2010 35,866 1,269 2.46 69.38 4.90 100.5 1,166,768 1,135,917 4.64 4.77 110.4 4.24 2011 37,981 1,351 W W 5.03 108.3 1,331,977 1,296,628 4.28 4.40 122.0 W 2012 23,861 858 2.62 72.96 5.86 42.2 834,245 813,288 2.97 3.05 70.8 W

January NM NM 1.98 55.72 4.49 85.0 103,441 100,700 6.06 6.23 111.9 5.43 February NM NM 1.89 53.71 4.80 53.5 92,052 89,617 5.62 5.77 112.6 4.97 March NM NM 2.28 64.61 4.83 80.7 96,305 93,754 4.89 5.02 112.3 4.38

April 3,134 110 2.31 65.60 5.05 125.6 89,012 86,651 4.19 4.31 110.1 3.85 May 2,812 99 2.36 67.00 4.99 99.2 93,846 91,314 4.37 4.49 112.0 4.02 June NM NM 2.29 64.41 4.96 84.4 95,210 92,629 4.58 4.71 109.8 4.14 July 3,445 123 2.54 71.36 4.65 112.3 103,153 100,425 4.82 4.95 109.9 4.37 August 4,313 153 2.71 76.26 4.73 133.3 106,486 103,638 4.69 4.82 109.3 4.22 September 3,742 133 2.68 75.58 5.01 130.2 96,833 94,214 4.02 4.13 108.3 3.79 October NM NM 2.66 75.62 4.87 99.7 95,174 92,702 3.92 4.03 110.4 3.71 November 2,862 101 2.47 69.84 5.18 91.0 93,589 91,184 3.74 3.84 111.3 3.62 December 3,383 120 2.71 76.42 5.17 113.3 101,666 99,087 4.65 4.77 107.5 4.36

January 3,075 110 3.16 88.56 4.70 96.3 112,015 109,254 4.54 4.65 122.0 4.31 February 2,430 86 2.99 83.98 4.66 84.3 99,431 96,876 4.55 4.67 120.3 4.28 March 2,687 95 3.24 91.51 4.75 100.0 102,958 100,259 4.08 4.19 122.8 3.96

April 2,336 83 W W 4.46 78.3 103,922 101,255 4.43 4.55 122.0 W May 2,259 81 W W 4.97 74.5 108,328 105,579 4.53 4.65 121.4 W June 2,558 91 W W 5.03 88.9 109,529 106,731 4.61 4.74 121.7 W July 4,019 141 W W 5.13 144.0 120,609 117,663 4.62 4.73 121.0 W August 3,728 132 W W 5.17 140.7 126,012 122,745 4.48 4.60 123.4 W September 3,738 132 W W 5.27 125.0 117,462 112,976 4.19 4.36 124.7 W October 3,512 126 W W 5.17 114.9 106,879 104,110 3.96 4.06 123.2 W November 3,267 117 W W 5.29 113.3 109,257 106,529 3.69 3.78 123.8 W December 4,372 156 W W 5.25 143.8 115,575 112,652 3.67 3.76 117.9 W

January 1,461 54 3.34 91.14 5.57 26.5 71,420 69,608 3.21 3.30 73.8 W February 428 16 W W 5.31 10.5 65,859 64,147 2.85 2.93 72.2 W March 1,900 68 W W 5.33 44.1 67,637 65,868 2.58 2.66 72.5 W

April 2,282 82 W W 5.64 61.4 67,492 65,641 2.34 2.41 72.7 W May 2,579 93 W W 5.53 69.1 68,198 66,297 2.38 2.46 69.8 W June 2,062 73 2.59 72.74 5.79 48.2 70,695 68,812 2.65 2.73 70.4 W July 1,419 51 2.58 71.62 6.07 29.9 73,402 71,204 2.94 3.04 66.4 W August 2,088 75 2.60 72.32 6.13 37.0 71,324 70,263 3.12 3.17 67.1 W September 2,643 95 W W 6.16 53.0 66,883 65,236 2.83 2.91 68.3 W October 1,760 63 W W 6.27 38.0 68,718 67,113 3.20 3.28 71.8 W November 2,466 88 W W 6.01 44.7 68,292 66,625 3.61 3.71 71.7 W December 2,773 100 W W 6.05 52.9 74,324 72,475 3.81 3.91 74.0 W 

### Table 7.12. Receipts, Average Cost, and Quality of Fossil Fuels: Industrial Sector, 2002 - 2012 (continued)

Petroleum Coke Natural Gas Receipts Average Cost Receipts Average Cost

Annual Totals

2010

2011

2012

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923 and predecessor forms. Totals may not equal sum of components because of independent rounding. Petroleum Coke includes petroleum coke-derived synthesis gas. Prior to 2011, petroleum coke-derived synthesis gas was included in Other Gases. See the Technical Notes for fuel conversion factors.
Sources: U.S. Energy Information Administration (EIA), Form EIA-923, "Power Plant Operations Report" and predecessor form(s) including Form EIA-423, "Monthly Cost and Quality of Fuels for Electric Plants Report" and Federal Energy Regulatory Commission (FERC), FERC Form 423, "Monthly Report of Cost and Quality of Fuels for Electric Plants"Census Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 New England 1,146 3,628 -68.0% 353 1,070 773 2,477 0 0 19 81 Connecticut 41 349 -88.0% 0 0 41 349 0 0 0 0 Maine 51 61 -16.0% 0 0 32 38 0 0 19 23 Massachusetts 700 2,147 -67.0% 0 0 700 2,089 0 0 0 58 New Hampshire 353 1,070 -67.0% 353 1,070 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 43,998 55,880 -21.0% 0 8,884 43,082 45,453 0 28 916 1,515 New Jersey 1,059 2,050 -48.0% 0 0 1,059 2,050 0 0 0 0 New York 2,218 5,367 -59.0% 0 17 1,884 4,939 0 NM 333 404 Pennsylvania 40,721 48,463 -16.0% 0 8,867 40,138 38,464 0 21 583 1,111 East North Central 182,345 213,663 -15.0% 117,309 143,301 61,732 64,427 111 527 3,193 5,409 Illinois 61,119 66,839 -8.6% 6,163 15,736 52,682 47,824 42 94 2,232 3,186 Indiana 36,672 43,919 -17.0% 33,943 38,728 2,729 4,888 0 193 0 112 Michigan 29,547 33,779 -13.0% 29,218 33,021 214 194 69 162 46 402 Ohio 35,005 45,038 -22.0% 28,628 32,975 6,108 11,521 0 NM 269 529 Wisconsin 20,003 24,087 -17.0% 19,357 22,841 0 0 0 65 646 1,181 West North Central 139,220 151,975 -8.4% 135,816 146,666 0 0 81 368 3,323 4,941 Iowa 24,436 26,839 -9.0% 22,264 23,826 0 0 0 242 2,172 2,771 Kansas 17,919 20,216 -11.0% 17,919 20,216 0 0 0 0 0 0 Minnesota 13,125 18,304 -28.0% 12,729 17,159 0 0 0 NM 396 1,121 Missouri 43,850 45,756 -4.2% 43,768 45,502 0 0 81 101 0 153 Nebraska 15,368 15,620 -1.6% 14,613 14,994 0 0 0 0 755 626 North Dakota 22,708 23,445 -3.1% 22,708 23,174 0 0 0 0 0 271 South Dakota 1,813 1,795 1.0% 1,813 1,795 0 0 0 0 0 0 South Atlantic 118,709 148,091 -20.0% 94,956 120,867 21,351 22,922 0 147 2,402 4,156 Delaware 645 562 15.0% 0 0 645 562 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 18,400 22,722 -19.0% 17,388 21,041 770 1,368 0 0 242 313 Georgia 23,258 31,251 -26.0% 22,863 30,411 0 0 0 0 395 840 Maryland 7,025 9,683 -27.0% 0 0 6,634 9,257 0 0 390 426 North Carolina 19,811 26,540 -25.0% 18,726 24,894 699 1,054 0 94 386 498 South Carolina 11,606 14,574 -20.0% 11,400 14,035 27 156 0 0 179 382 Virginia 6,528 11,020 -41.0% 5,327 8,194 728 1,564 0 53 473 1,207 West Virginia 31,436 31,740 -1.0% 19,252 22,292 11,847 8,960 0 0 337 488 East South Central 89,288 97,759 -8.7% 83,677 92,719 3,940 2,752 0 51 1,670 2,236 Alabama 24,639 27,411 -10.0% 24,544 26,947 0 51 0 0 94 413 Kentucky 39,483 41,473 -4.8% 39,483 41,473 0 0 0 0 0 0 Mississippi 6,590 6,643 -0.8% 2,651 3,942 3,940 2,701 0 0 0 0 Tennessee 18,576 22,231 -16.0% 16,999 20,358 0 0 0 51 1,576 1,822 West South Central 152,230 162,157 -6.1% 77,882 82,949 73,848 78,256 0 0 500 952 Arkansas 16,969 17,631 -3.8% 14,503 15,220 2,466 2,278 0 0 0 133 Louisiana 15,586 15,775 -1.2% 8,073 8,571 7,513 7,180 0 0 0 24 Oklahoma 19,605 19,836 -1.2% 17,871 17,970 1,233 1,341 0 0 500 525 Texas 100,071 108,916 -8.1% 37,435 41,188 62,636 67,458 0 0 0 269 Mountain 108,207 113,801 -4.9% 97,626 100,235 10,142 11,581 0 0 438 1,986 Arizona 23,238 23,218 0.1% 23,029 22,848 0 0 0 0 208 370 Colorado 18,687 19,754 -5.4% 18,687 19,510 0 244 0 0 0 0 Idaho 0 134 -100.0% 0 0 0 0 0 0 0 134 Montana 8,808 9,984 -12.0% 248 297 8,560 9,641 0 0 0 NM Nevada 2,215 3,105 -29.0% 1,580 2,376 635 729 0 0 0 0 New Mexico 14,604 16,318 -11.0% 14,604 16,318 0 0 0 0 0 0 Utah 13,834 15,214 -9.1% 13,159 14,527 445 422 0 0 230 264 Wyoming 26,821 26,075 2.9% 26,319 24,357 502 545 0 0 0 1,173 Pacific Contiguous 5,375 7,542 -29.0% 1,826 2,352 2,806 4,361 0 0 743 829 California 935 1,573 -41.0% 0 0 292 838 0 0 643 736 Oregon 1,826 2,352 -22.0% 1,826 2,352 0 0 0 0 0 0 Washington 2,615 3,617 -28.0% 0 0 2,514 3,523 0 0 100 94 Pacific Noncontiguous 667 2,040 -67.0% 0 310 667 1,065 0 564 0 100 Alaska 0 1,111 -100.0% 0 310 0 236 0 564 0 0 Hawaii 667 929 -28.0% 0 0 667 829 0 0 0 100 U.S. Total 841,183 956,538 -12.0% 609,445 699,353 218,341 233,295 192 1,686 13,206 22,204

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.13. Receipts of Coal Delivered for Electricity Generation by State, 2012 and 2011 (Thousand Tons) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 New England 560 2,334 -76.0% 20 NM 365 1,182 39 219 138 822 Connecticut 161 264 -39.0% 3 NM 158 216 0 0 0 NM Maine 151 1,334 -89.0% 0 NM 13 543 0 NM 138 780 Massachusetts 238 476 -50.0% 6 NM 193 421 39 NM 0 NM New Hampshire 9 160 -94.0% 9 NM 0 NM 0 119 0 NM Rhode Island 0 NM NM 0 NM 0 1 0 NM 0 0 Vermont 1 NM NM 1 NM 0 0 0 NM 0 0 Middle Atlantic 1,562 3,418 -54.0% 548 1,071 1,002 2,042 0 NM 11 NM New Jersey 124 516 -76.0% 0 NM 124 269 0 NM 0 NM New York 1,022 1,988 -49.0% 548 840 471 908 0 NM 4 NM Pennsylvania 415 914 -55.0% 0 NM 407 865 0 NM 8 NM East North Central 1,149 1,557 -26.0% 926 1,267 174 197 0 NM 49 67 Illinois 131 174 -25.0% 36 64 95 110 0 NM 0 NM Indiana 230 350 -34.0% 207 306 0 NM 0 NM 23 39 Michigan 215 366 -41.0% 201 335 0 0 0 NM 13 10 Ohio 518 570 -9.2% 432 479 75 83 0 NM 11 8 Wisconsin 56 97 -42.0% 51 83 4 NM 0 NM 1 NM West North Central 542 726 -25.0% 541 664 0 NM 0 NM 1 NM Iowa 187 160 17.0% 187 156 0 NM 0 NM 0 NM Kansas 73 96 -24.0% 73 96 0 0 0 0 0 0 Minnesota 27 70 -62.0% 26 43 0 7 0 NM 1 NM Missouri 158 209 -25.0% 158 206 0 NM 0 NM 0 NM Nebraska 29 63 -54.0% 29 63 0 0 0 0 0 0 North Dakota 63 109 -42.0% 63 82 0 0 0 NM 0 NM South Dakota 5 19 -74.0% 5 18 0 NM 0 NM 0 0 South Atlantic 3,217 9,843 -67.0% 1,960 6,979 371 925 5 NM 881 1,923 Delaware 34 106 -68.0% 0 NM 34 102 0 0 0 0 District of Columbia 7 215 -97.0% 0 0 7 215 0 0 0 0 Florida 948 5,266 -82.0% 699 4,684 14 NM 0 0 234 515 Georgia 398 737 -46.0% 228 301 8 NM 0 NM 162 424 Maryland 218 400 -46.0% 0 NM 142 349 0 NM 77 28 North Carolina 432 684 -37.0% 274 315 7 NM 0 NM 150 NM South Carolina 469 539 -13.0% 246 225 0 0 0 NM 223 313 Virginia 455 1,566 -71.0% 266 1,132 149 143 5 8 35 NM West Virginia 257 330 -22.0% 247 295 10 35 0 0 0 0 East South Central 471 1,311 -64.0% 466 942 1 17 0 0 4 352 Alabama 107 499 -79.0% 102 187 1 17 0 0 4 295 Kentucky 211 244 -14.0% 211 244 0 0 0 0 0 0 Mississippi 22 111 -80.0% 22 NM 0 0 0 0 0 15 Tennessee 132 456 -71.0% 132 414 0 0 0 0 0 NM West South Central 293 452 -35.0% 122 172 171 177 0 NM 0 NM Arkansas 74 91 -19.0% 47 28 26 38 0 0 0 NM Louisiana 50 116 -57.0% 17 35 33 34 0 0 0 NM Oklahoma 14 NM NM 14 NM 0 0 0 NM 0 0 Texas 156 229 -32.0% 44 92 111 106 0 NM 0 NM Mountain 396 509 -22.0% 347 439 48 61 0 NM 2 NM Arizona 77 120 -36.0% 76 114 0 0 0 NM 2 6 Colorado 10 66 -85.0% 10 65 0 0 0 NM 0 NM Idaho 0 NM NM 0 NM 0 0 0 0 0 0 Montana 36 50 -29.0% 0 8 36 42 0 0 0 0 Nevada 40 29 40.0% 30 21 10 8 0 0 0 0 New Mexico 95 56 69.0% 95 46 0 10 0 0 0 NM Utah 53 88 -40.0% 52 87 1 NM 0 0 0 0 Wyoming 85 100 -15.0% 85 98 0 0 0 0 0 NM Pacific Contiguous 96 550 -82.0% 43 81 44 NM 0 NM 9 435 California 50 NM NM 17 59 30 NM 0 NM 2 NM Oregon 14 NM NM 14 12 0 0 0 NM 0 NM Washington 33 446 -93.0% 12 9 14 17 0 NM 7 418 Pacific Noncontiguous 11,176 15,456 -28.0% 9,278 12,133 1,898 2,457 0 NM 0 850 Alaska 965 1,658 -42.0% 965 1,543 0 0 0 NM 0 103 Hawaii 10,211 13,798 -26.0% 8,313 10,590 1,898 2,457 0 NM 0 747 U.S. Total 19,464 36,158 -46.0% 14,252 23,859 4,073 7,096 43 325 1,095 4,878

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.14. Receipts of Petroleum Liquids Delivered for Electricity Generation by State, 2012 and 2011 (Thousand Barrels) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 New England 0 0

-- 0 0 0 0 0 0 0 0 Connecticut 0 0

-- 0 0 0 0 0 0 0 0 Maine 0 0

-- 0 0 0 0 0 0 0 0 Massachusetts 0 0

-- 0 0 0 0 0 0 0 0 New Hampshire 0 0

-- 0 0 0 0 0 0 0 0 Rhode Island 0 0

-- 0 0 0 0 0 0 0 0 Vermont 0 0

-- 0 0 0 0 0 0 0 0 Middle Atlantic 106 79 35.0% 0 0 0 23 0 0 106 56 New Jersey 0 NM NM 0 0 0 0 0 0 0 NM New York 0 23 -100.0% 0 0 0 23 0 0 0 0 Pennsylvania 106 50 112.0% 0 0 0 0 0 0 106 50 East North Central 893 1,416 -37.0% 248 401 507 485 0 0 138 530 Illinois 0 0

-- 0 0 0 0 0 0 0 0 Indiana 204 287 -29.0% 204 287 0 0 0 0 0 0 Michigan 36 188 -81.0% 0 0 36 32 0 0 0 156 Ohio 471 662 -29.0% 0 0 471 453 0 0 0 209 Wisconsin 182 279 -35.0% 44 114 0 0 0 0 138 165 West North Central 0 27 -100.0% 0 18 0 0 0 9 0 0 Iowa 0 25 -100.0% 0 15 0 0 0 9 0 0 Kansas 0 3 -100.0% 0 3 0 0 0 0 0 0 Minnesota 0 0

-- 0 0 0 0 0 0 0 0 Missouri 0 0

-- 0 0 0 0 0 0 0 0 Nebraska 0 0

-- 0 0 0 0 0 0 0 0 North Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Dakota 0 0

-- 0 0 0 0 0 0 0 0 South Atlantic 741 1,448 -49.0% 563 1,119 0 0 0 0 178 329 Delaware 0 0

-- 0 0 0 0 0 0 0 0 District of Columbia 0 0

-- 0 0 0 0 0 0 0 0 Florida 563 1,119 -50.0% 563 1,119 0 0 0 0 0 0 Georgia 178 329 -46.0% 0 0 0 0 0 0 178 329 Maryland 0 0

-- 0 0 0 0 0 0 0 0 North Carolina 0 0

-- 0 0 0 0 0 0 0 0 South Carolina 0 0

-- 0 0 0 0 0 0 0 0 Virginia 0 0

-- 0 0 0 0 0 0 0 0 West Virginia 0 0

-- 0 0 0 0 0 0 0 0 East South Central 532 463 15.0% 532 463 0 0 0 0 0 0 Alabama 0 0

-- 0 0 0 0 0 0 0 0 Kentucky 532 463 15.0% 532 463 0 0 0 0 0 0 Mississippi 0 0

-- 0 0 0 0 0 0 0 0 Tennessee 0 0

-- 0 0 0 0 0 0 0 0 West South Central 1,649 1,772 -6.9% 1,178 1,445 35 NM 0 0 436 315 Arkansas 0 0

-- 0 0 0 0 0 0 0 0 Louisiana 1,178 1,728 -32.0% 1,178 1,445 0 0 0 0 0 284 Oklahoma 0 5 -100.0% 0 0 0 0 0 0 0 5 Texas 471 38 NM 0 0 35 NM 0 0 436 26 Mountain 251 274 -8.2% 0 0 251 274 0 0 0 0 Arizona 0 0

-- 0 0 0 0 0 0 0 0 Colorado 0 0

-- 0 0 0 0 0 0 0 0 Idaho 0 0

-- 0 0 0 0 0 0 0 0 Montana 251 274 -8.2% 0 0 251 274 0 0 0 0 Nevada 0 0

-- 0 0 0 0 0 0 0 0 New Mexico 0 0

-- 0 0 0 0 0 0 0 0 Utah 0 0

-- 0 0 0 0 0 0 0 0 Wyoming 0 0

-- 0 0 0 0 0 0 0 0 Pacific Contiguous 8 503 -98.0% 0 0 8 381 0 0 0 121 California 8 503 -98.0% 0 0 8 381 0 0 0 121 Oregon 0 0

-- 0 0 0 0 0 0 0 0 Washington 0 0

-- 0 0 0 0 0 0 0 0 Pacific Noncontiguous 0 0

-- 0 0 0 0 0 0 0 0 Alaska 0 0

-- 0 0 0 0 0 0 0 0 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 4,180 5,980 -30.0% 2,521 3,445 801 1,175 0 9 858 1,351

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.15. Receipts of Petroleum Coke Delivered for Electricity Generation by State, 2012 and 2011 (Thousand Tons) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012Year 2011Percentage ChangeYear 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 Year 2012Year 2011 New England 440,421 484,260 -9.1% 3,652 4,226 419,062 434,504 3,636 13,156 14,072 32,373 Connecticut 112,084 116,563 -3.8% 71 738 112,012 107,121 0 3,210 0 5,494 Maine 42,374 56,230 -25.0% 0 0 28,302 33,578 0 NM 14,072 22,639 Massachusetts 175,314 198,295 -12.0% 2,789 2,393 168,890 184,156 3,636 7,872 0 3,875 New Hampshire 50,408 47,137 6.9% 754 1,046 49,655 45,725 0 0 0 NM Rhode Island 60,203 65,984 -8.8% 0 0 60,203 63,925 0 2,060 0 0 Vermont 37 49 -24.0% 37 49 0 0 0 0 0 0 Middle Atlantic 1,024,559 983,951 4.1% 109,942 128,984 912,518 809,805 0 10,433 2,099 34,729 New Jersey 200,570 218,548 -8.2% 0 0 200,570 199,866 0 2,139 0 16,542 New York 447,049 446,583 0.1% 109,942 128,934 336,374 304,592 0 7,616 734 5,440 Pennsylvania 376,940 318,821 18.0% 0 NM 375,574 305,346 0 NM 1,366 12,746 East North Central 621,882 459,563 35.0% 225,621 139,051 374,934 249,959 9,274 19,654 12,054 50,900 Illinois 78,693 67,266 17.0% 12,147 10,051 61,024 38,614 5,479 6,553 42 12,047 Indiana 117,031 101,358 15.0% 83,545 56,417 25,956 29,554 0 1,890 7,530 13,497 Michigan 175,163 124,100 41.0% 39,101 24,739 129,602 87,627 3,795 6,434 2,665 5,299 Ohio 163,870 111,716 47.0% 45,366 24,129 118,387 69,403 0 2,278 117 15,907 Wisconsin 87,126 55,124 58.0% 45,462 23,714 39,964 24,761 0 2,499 1,699 4,150 West North Central 157,891 125,986 25.0% 133,673 100,589 20,546 14,392 1,217 4,113 2,455 6,891 Iowa 18,348 10,751 71.0% 18,302 10,351 0 NM 0 313 46 86 Kansas 26,639 30,590 -13.0% 26,639 30,562 0 0 0 0 0 NM Minnesota 56,036 37,920 48.0% 44,549 22,560 9,571 7,760 0 3,033 1,916 4,568 Missouri 47,085 38,707 22.0% 34,892 31,275 10,976 6,631 1,217 730 0 NM Nebraska 8,141 5,311 53.0% 7,648 4,251 0 0 0 37 493 1,023 North Dakota 1 1,117 -100.0% 1 0 0 0 0 0 0 1,116 South Dakota 1,642 1,590 3.3% 1,642 1,590 0 0 0 0 0 0 South Atlantic 2,020,211 1,706,965 18.0% 1,562,634 1,293,449 410,674 347,656 0 2,883 46,903 62,977 Delaware 65,059 49,063 33.0% 0 174 52,550 38,818 0 0 12,508 10,071 District of Columbia 0 1,012 -100.0% 0 1,012 0 0 0 0 0 0 Florida 1,122,939 1,069,608 5.0% 1,034,639 956,933 74,051 87,907 0 NM 14,249 24,309 Georgia 328,446 208,798 57.0% 190,029 96,573 124,927 100,159 0 0 13,491 12,067 Maryland 47,231 28,079 68.0% 0 0 45,325 21,397 0 2,376 1,906 4,306 North Carolina 150,372 93,618 61.0% 126,867 71,816 23,368 18,420 0 NM 138 3,342 South Carolina 109,809 101,302 8.4% 97,550 86,739 11,902 13,143 0 NM 357 1,413 Virginia 193,993 151,657 28.0% 113,146 79,749 76,593 65,571 0 0 4,254 6,337 West Virginia 2,362 3,827 -38.0% 403 454 1,959 2,241 0 0 0 1,133 East South Central 807,339 682,990 18.0% 432,604 364,544 348,415 278,074 0 2,235 26,321 38,137 Alabama 395,377 368,618 7.3% 100,108 107,537 282,985 236,931 0 0 12,284 24,150 Kentucky 31,026 20,789 49.0% 27,812 14,023 3,214 1,578 0 0 0 5,188 Mississippi 317,211 261,588 21.0% 241,231 215,684 62,216 39,565 0 NM 13,764 5,913 Tennessee 63,726 31,994 99.0% 63,453 27,299 0 0 0 1,810 272 2,885 West South Central 2,896,365 3,043,534 -4.8% 812,628 798,424 1,445,605 1,342,974 3,881 8,485 634,252 893,651 Arkansas 128,030 111,262 15.0% 23,235 23,302 104,796 78,049 0 NM 0 9,906 Louisiana 531,471 567,240 -6.3% 223,287 226,417 96,745 67,644 0 NM 211,438 272,533 Oklahoma 313,960 284,687 10.0% 229,849 215,637 83,441 62,761 0 1,844 671 4,444 Texas 1,922,904 2,080,345 -7.6% 336,257 333,069 1,160,623 1,134,520 3,881 5,989 422,143 606,768 Mountain 611,904 578,209 5.8% 382,271 353,800 223,404 206,526 0 NM 6,229 15,439 Arizona 227,210 184,970 23.0% 111,161 83,036 115,891 101,035 0 NM 159 95 Colorado 80,575 85,134 -5.4% 46,149 68,364 34,427 16,465 0 NM 0 NM Idaho 12,738 10,177 25.0% 4,395 1,615 8,343 6,701 0 0 0 1,860 Montana 19 4,681 -100.0% 8 4,569 10 112 0 0 0 0 Nevada 177,682 165,896 7.1% 138,470 114,443 39,212 49,286 0 NM 0 1,535 New Mexico 64,840 75,416 -14.0% 43,108 45,904 21,732 28,083 0 NM 0 509 Utah 43,553 42,436 2.6% 38,681 35,545 3,776 4,762 0 NM 1,096 NM Wyoming 5,287 9,501 -44.0% 301 323 12 81 0 0 4,974 9,096 Pacific Contiguous 917,681 946,362 -3.0% 307,298 281,116 541,480 474,727 0 NM 68,903 160,680 California 793,427 838,613 -5.4% 250,913 234,353 477,250 421,165 0 NM 65,265 155,535 Oregon 81,111 64,290 26.0% 28,231 20,090 52,846 41,490 0 726 34 1,985 Washington 43,143 43,459 -0.7% 28,155 26,674 11,384 12,072 0 1,553 3,604 3,160 Pacific Noncontiguous 33,135 44,344 -25.0% 33,135 43,429 0 0 0 65 0 850 Alaska 33,135 44,344 -25.0% 33,135 43,429 0 0 0 65 0 850 Hawaii 0 0

-- 0 0 0 0 0 0 0 0 U.S. Total 9,531,389 9,056,164 5.2% 4,003,457 3,507,613 4,696,637 4,158,617 18,008 93,306 813,288 1,296,628

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.16. Receipts of Natural Gas Delivered for Electricity Generation by State, 2012 and 2011 (Million Cubic Feet) Electric Power Sector

All Sectors Electric Utilities Independent Power Producers Commercial Sector Industrial SectorCensus Division and State

Year 2012 Year 2011 Percentage Change Year 2012 Year 2011 Year 2012 Year 2011 New England 3.59 3.68 -2.4% 4.07 3.55 3.34 3.74 Connecticut W W W

-- -- W W Maine W W W

-- -- W W Massachusetts W W W

-- -- W W New Hampshire 4.07 3.55 15.0% 4.07 3.55

-- -- Rhode Island

-- -- -- -- -- -- -- Vermont

-- -- -- -- -- -- -- Middle Atlantic 2.50 2.68 -6.7%

-- 2.92 2.50 2.63 New Jersey 4.05 4.18 -3.1%

-- -- 4.05 4.18 New York 3.12 3.27 -4.6%

-- 3.88 3.12 3.27 Pennsylvania 2.43 2.55 -4.7%

-- 2.91 2.43 2.45 East North Central 2.37 2.30 3.0% 2.53 2.40 2.05 2.04 Illinois 1.93 1.72 12.0% 2.08 1.77 1.91 1.70 Indiana W W W 2.59 2.47 W W Michigan W W W 2.78 2.66 W W Ohio W 2.47 W 2.41 2.29 W 3.01 Wisconsin 2.37 2.50 -5.2% 2.37 2.50

-- -- West North Central 1.72 1.64 4.9% 1.72 1.64

-- -- Iowa 1.48 1.43 3.5% 1.48 1.43

-- -- Kansas 1.83 1.75 4.6% 1.83 1.75

-- -- Minnesota 1.98 1.93 2.6% 1.98 1.93

-- -- Missouri 1.85 1.72 7.6% 1.85 1.72

-- -- Nebraska 1.55 1.51 2.6% 1.55 1.51

-- -- North Dakota 1.49 1.34 11.0% 1.49 1.34

-- -- South Dakota 2.19 2.09 4.8% 2.19 2.09

-- -- South Atlantic 3.35 3.41 -1.8% 3.45 3.46 2.92 3.15 Delaware W W W

-- -- W W District of Columbia

-- -- -- -- -- -- -- Florida W W W 3.49 3.53 W W Georgia 3.47 3.75 -7.5% 3.47 3.75

-- -- Maryland 3.62 3.72 -2.7%

-- -- 3.62 3.72 North Carolina 3.77 3.63 3.9% 3.82 3.66 2.59 2.89 South Carolina W W W 3.97 3.84 W W Virginia W 3.55 W 3.61 3.53 W 3.66 West Virginia 2.54 2.46 3.3% 2.70 2.56 2.27 2.20 East South Central W W W 2.69 2.65 W W Alabama 3.01 W W 3.01 2.87

-- W Kentucky 2.42 2.34 3.4% 2.42 2.34

-- -- Mississippi W W W 4.45 3.87 W W Tennessee 2.61 2.82 -7.4% 2.61 2.82

-- -- West South Central 2.00 1.92 4.2% 2.12 1.96 1.87 1.87 Arkansas W W W 2.25 1.91 W W Louisiana W W W 2.87 2.66 W W Oklahoma W W W 1.97 1.76 W W Texas 1.88 1.87 0.5% 1.99 1.93 1.82 1.84 Mountain 1.84 1.78 3.4% 1.87 1.81 1.42 1.44 Arizona 2.07 1.98 4.5% 2.07 1.98

-- -- Colorado 1.84 W W 1.84 1.72

-- W Idaho

-- -- -- -- -- -- -- Montana W W W 1.61 1.48 W W Nevada W W W 2.55 2.60 W W New Mexico 2.18 2.05 6.3% 2.18 2.05

-- -- Utah 1.92 W W 1.92 1.77

-- W Wyoming W W W 1.45 1.50 W W Pacific Contiguous W 2.21 W 1.89 1.79 W 2.42 California W W W

-- -- W W Oregon 1.89 1.79 5.6% 1.89 1.79

-- -- Washington W W W

-- -- W W Pacific Noncontiguous W W W

-- 1.66 W W Alaska

-- W W

-- 1.66

-- W Hawaii W W W

-- -- W W U.S. Total 2.37 2.37 0.0% 2.43 2.40 2.21 2.28

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.17. Average Cost of Coal Delivered for Electricity Generation by State, 2012 and 2011 (Dollars per MMBtu)

Electric Power Sector Electric Utilities Independent Power ProducersCensus Division and State

Year 2012 Year 2011 Percentage Change Year 2012 Year 2011 Year 2012 Year 2011 New England 18.64 W W 21.43 21.12 18.47 W Connecticut W 21.91 W 23.87 NM W 21.93 Maine W W W

-- NM W W Massachusetts 17.17 19.76 -13.0% 17.45 NM 17.16 19.66 New Hampshire 23.23 W W 23.23 19.90

-- W Rhode Island

-- W W

-- NM

-- W Vermont 24.11 NM NM 24.11 NM

-- -- Middle Atlantic W 20.15 W 21.01 19.21 W 20.66 New Jersey 19.77 18.36 7.7%

-- NM 19.77 20.28 New York W 19.66 W 21.01 20.00 W 19.36 Pennsylvania 21.84 22.19 -1.6%

-- NM 21.84 22.19 East North Central 23.10 22.33 3.4% 22.98 22.20 23.73 23.18 Illinois W 23.72 W 24.35 23.09 W 24.09 Indiana 23.19 W W 23.19 21.83

-- W Michigan W W W 22.67 22.13 W W Ohio 23.06 22.26 3.6% 23.03 22.32 23.22 21.95 Wisconsin W W W 22.00 22.49 W W West North Central 22.37 22.53 -0.7% 22.37 22.51

-- NM Iowa 22.91 W W 22.91 22.91

-- W Kansas 22.93 22.20 3.3% 22.93 22.20

-- -- Minnesota 23.76 W W 23.76 23.48

-- W Missouri 20.42 W W 20.42 21.61

-- W Nebraska 22.96 22.77 0.8% 22.96 22.77

-- -- North Dakota 23.80 23.44 1.5% 23.80 23.44

-- -- South Dakota 20.69 W W 20.69 23.29

-- W South Atlantic W 19.11 W 21.38 18.88 W 20.94 Delaware W W W

-- NM W W District of Columbia W W W

-- -- W W Florida W 18.52 W 20.16 18.49 W NM Georgia W 22.72 W 24.24 22.74 W NM Maryland 22.67 21.30 6.4%

-- NM 22.67 21.31 North Carolina W 21.95 W 23.18 22.01 W NM South Carolina 21.36 21.34 0.1% 21.36 21.34

-- -- Virginia W 17.69 W 18.74 17.17 W 22.15 West Virginia W W W 23.34 23.12 W W East South Central W W W 22.62 21.39 W W Alabama W W W 22.81 22.05 W W Kentucky 22.92 22.93 0.0% 22.92 22.93

-- -- Mississippi 22.22 NM NM 22.22 NM

-- -- Tennessee 22.08 21.55 2.5% 22.08 21.55

-- -- West South Central 22.72 21.18 7.3% 22.88 19.96 22.59 22.39 Arkansas W W W 22.99 21.73 W W Louisiana W W W 22.37 14.49 W W Oklahoma 22.77 NM NM 22.77 NM

-- -- Texas W W W 23.00 22.00 W W Mountain 23.32 23.30 0.1% 23.86 23.50 19.01 21.74 Arizona 23.41 23.18 1.0% 23.41 23.18

-- -- Colorado W 22.96 W 16.94 22.96 W

-- Idaho

-- NM

-- -- NM

-- -- Montana W 20.92 W

-- 20.48 W 21.02 Nevada W W W 25.23 23.94 W W New Mexico 25.77 W W 25.77 25.16

-- W Utah W W W 23.55 23.47 W W Wyoming 22.40 23.65 -5.3% 22.40 23.65

-- -- Pacific Contiguous W 23.52 W 24.93 24.10 W NM California 26.89 W W 26.89 23.74

-- W Oregon 22.68 23.73 -4.4% 22.68 23.73

-- -- Washington W W W 24.73 27.02 W W Pacific Noncontiguous W W W 22.12 20.70 W W Alaska 23.40 22.95 2.0% 23.40 22.95

-- -- Hawaii W W W 21.99 20.42 W W U.S. Total 22.16 20.30 9.2% 22.11 20.30 22.34 20.30

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.18. Average Cost of Petroleum Liquids Delivered for Electricity Generation by State, 2012 and 2011 (Dollars per MMBtu)

Electric Power Sector Electric Utilities Independent Power ProducersCensus Division and State

Year 2012 Year 2011 Percentage Change Year 2012 Year 2011 Year 2012 Year 2011 New England

-- -- -- -- -- -- -- Connecticut

-- -- -- -- -- -- -- Maine

-- -- -- -- -- -- -- Massachusetts

-- -- -- -- -- -- -- New Hampshire

-- -- -- -- -- -- -- Rhode Island

-- -- -- -- -- -- -- Vermont

-- -- -- -- -- -- -- Middle Atlantic

-- W W

-- -- -- W New Jersey

-- -- -- -- -- -- -- New York

-- W W

-- -- -- W Pennsylvania

-- -- -- -- -- -- -- East North Central W W W 4.10 4.01 W W Illinois

-- -- -- -- -- -- -- Indiana 4.56 4.87 -6.4% 4.56 4.87

-- -- Michigan W W W

-- -- W W Ohio

-- W W

-- -- -- W Wisconsin 1.69 1.64 3.0% 1.69 1.64

-- -- West North Central

-- 1.63

-- -- 1.63

-- -- Iowa

-- 1.60

-- -- 1.60

-- -- Kansas

-- 1.76

-- -- 1.76

-- -- Minnesota

-- -- -- -- -- -- -- Missouri

-- -- -- -- -- -- -- Nebraska

-- -- -- -- -- -- -- North Dakota

-- -- -- -- -- -- -- South Dakota

-- -- -- -- -- -- -- South Atlantic 2.58 3.82 -32.0% 2.58 3.82

-- -- Delaware

-- -- -- -- -- -- -- District of Columbia

-- -- -- -- -- -- -- Florida 2.58 3.82 -32.0% 2.58 3.82

-- -- Georgia

-- -- -- -- -- -- -- Maryland

-- -- -- -- -- -- -- North Carolina

-- -- -- -- -- -- -- South Carolina

-- -- -- -- -- -- -- Virginia

-- -- -- -- -- -- -- West Virginia

-- -- -- -- -- -- -- East South Central 1.83 0.53 245.0% 1.83 0.53

-- -- Alabama

-- -- -- -- -- -- -- Kentucky 1.83 0.53 245.0% 1.83 0.53

-- -- Mississippi

-- -- -- -- -- -- -- Tennessee

-- -- -- -- -- -- -- West South Central W W W 1.99 3.08 W W Arkansas

-- -- -- -- -- -- -- Louisiana 1.99 3.08 -35.0% 1.99 3.08

-- -- Oklahoma

-- -- -- -- -- -- -- Texas W W W

-- -- W W Mountain W W W

-- -- W W Arizona

-- -- -- -- -- -- -- Colorado

-- -- -- -- -- -- -- Idaho

-- -- -- -- -- -- -- Montana W W W

-- -- W W Nevada

-- -- -- -- -- -- -- New Mexico

-- -- -- -- -- -- -- Utah

-- -- -- -- -- -- -- Wyoming

-- -- -- -- -- -- -- Pacific Contiguous W 2.88 W

-- -- W 2.88 California W 2.88 W

-- -- W 2.88 Oregon

-- -- -- -- -- -- -- Washington

-- -- -- -- -- -- -- Pacific Noncontiguous

-- -- -- -- -- -- -- Alaska

-- -- -- -- -- -- -- Hawaii

-- -- -- -- -- -- -- U.S. Total 2.13 2.95 -28.0% 2.30 3.08 0.82 2.54

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.19. Average Cost of Petroleum Coke Delivered for Electricity Generation by State, 2012 and 2011 (Dollars per MMBtu)

Electric Power Sector Electric Utilities Independent Power ProducersCensus Division and State

Year 2012 Year 2011 Percentage Change Year 2012 Year 2011 Year 2012 Year 2011 New England 3.69 4.94 -25.0% 4.73 5.70 3.68 4.93 Connecticut 3.88 4.97 -22.0% 6.45 NM 3.87 4.96 Maine W W W

-- -- W W Massachusetts 3.55 4.88 -27.0% 4.47 5.75 3.53 4.87 New Hampshire W W W 5.54 6.01 W W Rhode Island 3.86 5.01 -23.0%

-- -- 3.86 5.01 Vermont 4.06 5.22 -22.0% 4.06 5.22

-- -- Middle Atlantic 3.52 5.14 -32.0% 3.86 5.32 3.46 5.11 New Jersey 3.52 5.11 -31.0%

-- -- 3.52 5.11 New York 3.85 5.45 -29.0% 3.86 5.32 3.84 5.50 Pennsylvania 3.06 4.73 -35.0%

-- NM 3.06 4.73 East North Central 3.10 4.62 -33.0% 3.12 4.69 3.08 4.58 Illinois W 4.86 W 3.25 5.15 W 4.78 Indiana W 4.48 W 3.01 4.42 W 4.59 Michigan 3.16 4.69 -33.0% 3.20 4.85 3.15 4.64 Ohio 2.98 4.44 -33.0% 2.99 4.49 2.98 4.42 Wisconsin 3.20 4.85 -34.0% 3.37 5.20 2.98 4.51 West North Central W 5.18 W 3.56 5.17 W 5.22 Iowa 3.75 W W 3.75 5.44

-- W Kansas 3.21 4.70 -32.0% 3.21 4.70

-- -- Minnesota W W W 3.71 5.88 W W Missouri W W W 3.46 4.97 W W Nebraska 3.84 5.70 -33.0% 3.84 5.70

-- -- North Dakota 5.70 7.80 -27.0% 5.70 7.80

-- -- South Dakota 3.43 5.00 -31.0% 3.43 5.00

-- -- South Atlantic 4.23 5.45 -22.0% 4.42 5.57 3.13 5.00 Delaware

-- W W

-- NM

-- W District of Columbia

-- NM

-- -- NM

-- -- Florida 4.72 5.79 -18.0% 4.82 5.84 2.56 5.32 Georgia 3.35 4.64 -28.0% 3.38 4.51 3.29 4.76 Maryland W W W

-- -- W W North Carolina W W W 4.36 5.86 W W South Carolina W 4.33 W 3.62 4.26 W 4.78 Virginia 3.27 4.94 -34.0% 3.32 4.89 3.20 5.00 West Virginia 3.24 4.74 -32.0% 3.20 4.79 3.25 4.73 East South Central 2.98 4.34 -31.0% 2.99 4.40 2.96 4.26 Alabama 3.04 4.28 -29.0% 3.12 4.37 3.00 4.24 Kentucky W 5.86 W 3.52 6.00 W 4.63 Mississippi W 4.29 W 2.91 4.28 W 4.36 Tennessee 2.87 4.61 -38.0% 2.87 4.61

-- -- West South Central 2.95 4.31 -32.0% 3.01 4.39 2.90 4.27 Arkansas 3.12 4.64 -33.0% 3.86 5.61 2.95 4.34 Louisiana 2.94 4.31 -32.0% 2.98 4.35 2.83 4.16 Oklahoma 2.96 4.42 -33.0% 3.03 4.45 2.76 4.32 Texas 2.93 4.27 -31.0% 2.97 4.30 2.92 4.27 Mountain W 4.82 W 3.52 4.97 W 4.56 Arizona 3.43 4.94 -31.0% 3.69 5.52 3.09 4.46 Colorado W 4.82 W 4.01 4.82 W 4.84 Idaho W W W 4.20 6.74 W W Montana W W W 4.06 4.15 W W Nevada 3.39 4.87 -30.0% 3.41 4.96 3.28 4.65 New Mexico W W W 3.35 4.84 W W Utah 2.93 W W 2.93 4.19

-- W Wyoming W W W 5.86 6.91 W W Pacific Contiguous 3.55 4.61 -23.0% 3.92 4.87 3.27 4.46 California 3.59 4.61 -22.0% 3.97 4.86 3.32 4.48 Oregon W W W 3.09 4.04 W W Washington W W W 4.35 5.52 W W Pacific Noncontiguous 4.29 5.00 -14.0% 4.29 5.00

-- -- Alaska 4.29 5.00 -14.0% 4.29 5.00

-- -- Hawaii

-- -- -- -- -- -- -- U.S. Total 3.46 4.79 -28.0% 3.74 5.00 3.17 4.62

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values for are final. See Technical Notes for a discussion of the sample design for the Form EIA-923. Totals may not equal sum of components because of independent rounding. Percentage change is calculated before rounding.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.20. Average Cost of Natural Gas Delivered for Electricity Generation by State, 2012 and 2011 (Dollars per MMBtu)

Electric Power Sector Electric Utilities Independent Power ProducersCensus Division and State Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight New England 1,104 1.31 9.5 41 0.09 2.0 0

-- -- Connecticut 0

-- -- 41 0.09 2.0 0

-- -- Maine 51 0.75 6.9 0

-- -- 0

-- -- Massachusetts 700 0.88 10.7 0

-- -- 0

-- -- New Hampshire 353 2.20 7.7 0

-- -- 0

-- -- Rhode Island 0

-- -- 0

-- -- 0

-- -- Vermont 0

-- -- 0

-- -- 0

-- -- Middle Atlantic 35,282 2.95 11.1 860 0.30 5.4 0

-- -- New Jersey 1,046 1.49 9.3 13 0.25 5.6 0

-- -- New York 1,370 2.45 9.0 847 0.30 5.4 0

-- -- Pennsylvania 32,865 3.01 11.2 0

-- -- 0

-- -- East North Central 77,731 2.89 9.7 104,615 0.25 4.9 0

-- -- Illinois 8,042 3.05 15.2 53,077 0.22 4.8 0

-- -- Indiana 30,634 2.69 9.1 6,038 0.27 5.2 0

-- -- Michigan 3,910 1.60 8.6 25,638 0.29 4.9 0

-- -- Ohio 33,647 3.23 9.4 1,358 0.28 5.3 0

-- -- Wisconsin 1,499 1.79 7.6 18,503 0.27 5.0 0

-- -- West North Central 1,553 3.13 9.1 116,022 0.28 5.0 21,645 0.82 10.2 Iowa 452 3.47 8.0 23,984 0.29 4.9 0

-- -- Kansas 245 3.14 13.4 17,675 0.31 5.1 0

-- -- Minnesota 21 0.86 8.9 13,104 0.34 5.6 0

-- -- Missouri 835 3.01 8.4 43,014 0.24 4.9 0

-- -- Nebraska 0

-- -- 15,368 0.28 5.0 0

-- -- North Dakota 0

-- -- 1,063 0.33 4.8 21,645 0.82 10.2 South Dakota 0

-- -- 1,813 0.37 5.7 0

-- -- South Atlantic 105,134 1.89 10.5 12,613 0.30 4.7 0

-- -- Delaware 645 1.76 8.2 0

-- -- 0

-- -- District of Columbia 0

-- -- 0

-- -- 0

-- -- Florida 18,400 2.18 9.3 0

-- -- 0

-- -- Georgia 11,052 1.25 9.6 12,206 0.30 4.7 0

-- -- Maryland 6,617 1.77 10.2 360 0.23 4.7 0

-- -- North Carolina 19,811 1.23 10.6 0

-- -- 0

-- -- South Carolina 11,606 1.55 9.5 0

-- -- 0

-- -- Virginia 6,528 1.14 12.6 0

-- -- 0

-- -- West Virginia 30,474 2.70 11.6 47 0.26 4.6 0

-- -- East South Central 63,264 2.38 10.0 22,959 0.28 5.2 3,065 0.50 15.1 Alabama 12,886 1.64 10.4 11,753 0.27 5.1 0

-- -- Kentucky 37,224 2.84 10.3 2,259 0.28 5.4 0

-- -- Mississippi 3,431 1.66 9.6 94 0.24 5.4 3,065 0.50 15.1 Tennessee 9,723 1.94 8.7 8,853 0.29 5.2 0

-- -- West South Central 817 1.93 20.4 104,523 0.29 5.1 46,890 1.00 16.6 Arkansas 0

-- -- 16,969 0.27 5.1 0

-- -- Louisiana 338 3.11 8.9 11,381 0.31 5.1 3,867 0.68 16.7 Oklahoma 479 0.93 30.1 19,126 0.26 4.9 0

-- -- Texas 0

-- -- 57,048 0.30 5.1 43,023 1.03 16.6 Mountain 30,912 0.59 13.5 76,601 0.53 9.5 248 0.51 9.3 Arizona 7,798 0.60 10.6 15,439 0.69 10.1 0

-- -- Colorado 3,628 0.48 10.6 15,059 0.32 5.7 0

-- -- Idaho 0

-- -- 0

-- -- 0

-- -- Montana 0

-- -- 8,560 0.68 8.9 248 0.51 9.3 Nevada 926 0.44 11.0 1,289 0.38 6.5 0

-- -- New Mexico 5,740 0.75 23.1 8,864 0.70 23.2 0

-- -- Utah 12,820 0.58 12.4 569 1.07 8.7 0

-- -- Wyoming 0

-- -- 26,821 0.46 7.2 0

-- -- Pacific Contiguous 935 0.61 11.3 4,440 0.37 7.1 0

-- -- California 935 0.61 11.3 0

-- -- 0

-- -- Oregon 0

-- -- 1,826 0.41 5.1 0

-- -- Washington 0

-- -- 2,615 0.34 8.6 0

-- -- Pacific Noncontiguous 667 0.67 8.3 0

-- -- 0

-- -- Alaska 0

-- -- 0

-- -- 0

-- -- Hawaii 667 0.67 8.3 0

-- -- 0

-- -- U.S. Total 317,398 2.23 10.6 442,674 0.32 5.8 71,848 0.93 14.6

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.21. Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Total (All Sectors) by State, 2012

Bituminous Subbituminous LigniteCensus Division and State Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight New England 353 2.20 7.7 0

-- -- 0

-- -- Connecticut 0

-- -- 0

-- -- 0

-- -- Maine 0

-- -- 0

-- -- 0

-- -- Massachusetts 0

-- -- 0

-- -- 0

-- -- New Hampshire 353 2.20 7.7 0

-- -- 0

-- -- Rhode Island 0

-- -- 0

-- -- 0

-- -- Vermont 0

-- -- 0

-- -- 0

-- -- Middle Atlantic 0

-- -- 0

-- -- 0

-- -- New Jersey 0

-- -- 0

-- -- 0

-- -- New York 0

-- -- 0

-- -- 0

-- -- Pennsylvania 0

-- -- 0

-- -- 0

-- -- East North Central 63,760 2.92 9.3 53,549 0.28 4.9 0

-- -- Illinois 2,453 3.27 11.8 3,709 0.23 4.9 0

-- -- Indiana 27,905 2.66 8.9 6,038 0.27 5.2 0

-- -- Michigan 3,661 1.62 8.6 25,557 0.29 4.9 0

-- -- Ohio 28,618 3.36 9.5 10 0.26 4.3 0

-- -- Wisconsin 1,122 1.70 7.5 18,235 0.27 5.0 0

-- -- West North Central 1,020 2.98 9.6 113,151 0.28 5.0 21,645 0.82 10.2 Iowa 0

-- -- 22,264 0.30 4.9 0

-- -- Kansas 245 3.14 13.4 17,675 0.31 5.1 0

-- -- Minnesota 21 0.86 8.9 12,708 0.34 5.6 0

-- -- Missouri 754 2.99 8.4 43,014 0.24 4.9 0

-- -- Nebraska 0

-- -- 14,613 0.28 5.0 0

-- -- North Dakota 0

-- -- 1,063 0.33 4.8 21,645 0.82 10.2 South Dakota 0

-- -- 1,813 0.37 5.7 0

-- -- South Atlantic 82,703 1.76 10.4 12,253 0.30 4.7 0

-- -- Delaware 0

-- -- 0

-- -- 0

-- -- District of Columbia 0

-- -- 0

-- -- 0

-- -- Florida 17,388 2.25 9.1 0

-- -- 0

-- -- Georgia 10,657 1.26 9.6 12,206 0.30 4.7 0

-- -- Maryland 0

-- -- 0

-- -- 0

-- -- North Carolina 18,726 1.24 10.8 0

-- -- 0

-- -- South Carolina 11,400 1.56 9.5 0

-- -- 0

-- -- Virginia 5,327 1.09 13.4 0

-- -- 0

-- -- West Virginia 19,205 2.39 11.4 47 0.26 4.6 0

-- -- East South Central 60,719 2.42 10.1 22,959 0.28 5.2 0

-- -- Alabama 12,792 1.65 10.4 11,753 0.27 5.1 0

-- -- Kentucky 37,224 2.84 10.3 2,259 0.28 5.4 0

-- -- Mississippi 2,556 1.24 10.0 94 0.24 5.4 0

-- -- Tennessee 8,147 2.16 8.9 8,853 0.29 5.2 0

-- -- West South Central 338 3.11 8.9 66,949 0.27 5.0 10,595 1.19 18.8 Arkansas 0

-- -- 14,503 0.27 5.1 0

-- -- Louisiana 338 3.11 8.9 3,868 0.30 5.4 3,867 0.68 16.7 Oklahoma 0 0.48 9.7 17,871 0.27 4.9 0

-- -- Texas 0

-- -- 30,707 0.27 5.0 6,728 1.52 20.2 Mountain 30,682 0.60 13.5 66,696 0.52 9.7 248 0.51 9.3 Arizona 7,798 0.60 10.6 15,231 0.68 10.1 0

-- -- Colorado 3,628 0.48 10.6 15,059 0.32 5.7 0

-- -- Idaho 0

-- -- 0

-- -- 0

-- -- Montana 0

-- -- 0

-- -- 248 0.51 9.3 Nevada 926 0.44 11.0 654 0.41 7.4 0

-- -- New Mexico 5,740 0.75 23.1 8,864 0.70 23.2 0

-- -- Utah 12,590 0.58 12.4 569 1.07 8.7 0

-- -- Wyoming 0

-- -- 26,319 0.46 7.2 0

-- -- Pacific Contiguous 0

-- -- 1,826 0.41 5.1 0

-- -- California 0

-- -- 0

-- -- 0

-- -- Oregon 0

-- -- 1,826 0.41 5.1 0

-- -- Washington 0

-- -- 0

-- -- 0

-- -- Pacific Noncontiguous 0

-- -- 0

-- -- 0

-- -- Alaska 0

-- -- 0

-- -- 0

-- -- Hawaii 0

-- -- 0

-- -- 0

-- -- U.S. Total 239,576 2.10 10.4 337,382 0.33 5.9 32,488 0.94 12.9

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.22. Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Electric Utilties by State, 2012

Bituminous Subbituminous LigniteCensus Division and State Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight New England 732 0.87 10.5 41 0.09 2.0 0

-- -- Connecticut 0

-- -- 41 0.09 2.0 0

-- -- Maine 32 0.80 7.0 0

-- -- 0

-- -- Massachusetts 700 0.88 10.7 0

-- -- 0

-- -- New Hampshire 0

-- -- 0

-- -- 0

-- -- Rhode Island 0

-- -- 0

-- -- 0

-- -- Vermont 0

-- -- 0

-- -- 0

-- -- Middle Atlantic 34,584 2.97 11.1 860 0.30 5.4 0

-- -- New Jersey 1,046 1.49 9.3 13 0.25 5.6 0

-- -- New York 1,037 2.70 8.6 847 0.30 5.4 0

-- -- Pennsylvania 32,500 3.03 11.3 0

-- -- 0

-- -- East North Central 11,511 2.68 12.6 50,221 0.22 4.8 0

-- -- Illinois 3,889 2.74 20.6 48,793 0.22 4.8 0

-- -- Indiana 2,729 3.09 11.2 0

-- -- 0

-- -- Michigan 133 1.13 8.4 81 0.22 4.7 0

-- -- Ohio 4,760 2.49 8.5 1,348 0.28 5.3 0

-- -- Wisconsin 0

-- -- 0

-- -- 0

-- -- West North Central 0

-- -- 0

-- -- 0

-- -- Iowa 0

-- -- 0

-- -- 0

-- -- Kansas 0

-- -- 0

-- -- 0

-- -- Minnesota 0

-- -- 0

-- -- 0

-- -- Missouri 0

-- -- 0

-- -- 0

-- -- Nebraska 0

-- -- 0

-- -- 0

-- -- North Dakota 0

-- -- 0

-- -- 0

-- -- South Dakota 0

-- -- 0

-- -- 0

-- -- South Atlantic 20,029 2.49 10.8 360 0.23 4.7 0

-- -- Delaware 645 1.76 8.2 0

-- -- 0

-- -- District of Columbia 0

-- -- 0

-- -- 0

-- -- Florida 770 1.01 11.7 0

-- -- 0

-- -- Georgia 0

-- -- 0

-- -- 0

-- -- Maryland 6,227 1.75 9.5 360 0.23 4.7 0

-- -- North Carolina 699 1.07 7.8 0

-- -- 0

-- -- South Carolina 27 1.52 8.6 0

-- -- 0

-- -- Virginia 728 0.97 9.3 0

-- -- 0

-- -- West Virginia 10,932 3.30 12.0 0

-- -- 0

-- -- East South Central 874 2.93 8.5 0

-- -- 3,065 0.50 15.1 Alabama 0

-- -- 0

-- -- 0

-- -- Kentucky 0

-- -- 0

-- -- 0

-- -- Mississippi 874 2.93 8.5 0

-- -- 3,065 0.50 15.1 Tennessee 0

-- -- 0

-- -- 0

-- -- West South Central 479 0.93 30.1 37,074 0.33 5.1 36,295 0.95 16.0 Arkansas 0

-- -- 2,466 0.28 5.3 0

-- -- Louisiana 0

-- -- 7,513 0.32 4.9 0

-- -- Oklahoma 479 0.93 30.1 755 0.21 4.6 0

-- -- Texas 0

-- -- 26,341 0.34 5.2 36,295 0.95 16.0 Mountain 0

-- -- 9,697 0.64 8.5 0

-- -- Arizona 0

-- -- 0

-- -- 0

-- -- Colorado 0

-- -- 0

-- -- 0

-- -- Idaho 0

-- -- 0

-- -- 0

-- -- Montana 0

-- -- 8,560 0.68 8.9 0

-- -- Nevada 0

-- -- 635 0.35 5.6 0

-- -- New Mexico 0

-- -- 0

-- -- 0

-- -- Utah 0

-- -- 0

-- -- 0

-- -- Wyoming 0

-- -- 502 0.39 5.8 0

-- -- Pacific Contiguous 292 1.01 12.4 2,514 0.34 8.8 0

-- -- California 292 1.01 12.4 0

-- -- 0

-- -- Oregon 0

-- -- 0

-- -- 0

-- -- Washington 0

-- -- 2,514 0.34 8.8 0

-- -- Pacific Noncontiguous 667 0.67 8.3 0

-- -- 0

-- -- Alaska 0

-- -- 0

-- -- 0

-- -- Hawaii 667 0.67 8.3 0

-- -- 0

-- -- U.S. Total 69,167 2.72 11.3 100,769 0.30 5.4 39,360 0.92 15.9

Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.23. Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Independent Power Producers by State, 2012

Bituminous Subbituminous LigniteCensus Division and State Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight New England 0

-- -- 0

-- -- 0

-- -- Connecticut 0

-- -- 0

-- -- 0

-- -- Maine 0

-- -- 0

-- -- 0

-- -- Massachusetts 0

-- -- 0

-- -- 0

-- -- New Hampshire 0

-- -- 0

-- -- 0

-- -- Rhode Island 0

-- -- 0

-- -- 0

-- -- Vermont 0

-- -- 0

-- -- 0

-- -- Middle Atlantic 0

-- -- 0

-- -- 0

-- -- New Jersey 0

-- -- 0

-- -- 0

-- -- New York 0

-- -- 0

-- -- 0

-- -- Pennsylvania 0

-- -- 0

-- -- 0

-- -- East North Central 111 2.44 9.2 0

-- -- 0

-- -- Illinois 42 3.10 8.8 0

-- -- 0

-- -- Indiana 0

-- -- 0

-- -- 0

-- -- Michigan 69 2.05 9.4 0

-- -- 0

-- -- Ohio 0

-- -- 0

-- -- 0

-- -- Wisconsin 0

-- -- 0

-- -- 0

-- -- West North Central 81 3.19 9.2 0

-- -- 0

-- -- Iowa 0

-- -- 0

-- -- 0

-- -- Kansas 0

-- -- 0

-- -- 0

-- -- Minnesota 0

-- -- 0

-- -- 0

-- -- Missouri 81 3.19 9.2 0

-- -- 0

-- -- Nebraska 0

-- -- 0

-- -- 0

-- -- North Dakota 0

-- -- 0

-- -- 0

-- -- South Dakota 0

-- -- 0

-- -- 0

-- -- South Atlantic 0

-- -- 0

-- -- 0

-- -- Delaware 0

-- -- 0

-- -- 0

-- -- District of Columbia 0

-- -- 0

-- -- 0

-- -- Florida 0

-- -- 0

-- -- 0

-- -- Georgia 0

-- -- 0

-- -- 0

-- -- Maryland 0

-- -- 0

-- -- 0

-- -- North Carolina 0

-- -- 0

-- -- 0

-- -- South Carolina 0

-- -- 0

-- -- 0

-- -- Virginia 0

-- -- 0

-- -- 0

-- -- West Virginia 0

-- -- 0

-- -- 0

-- -- East South Central 0

-- -- 0

-- -- 0

-- -- Alabama 0

-- -- 0

-- -- 0

-- -- Kentucky 0

-- -- 0

-- -- 0

-- -- Mississippi 0

-- -- 0

-- -- 0

-- -- Tennessee 0

-- -- 0

-- -- 0

-- -- West South Central 0

-- -- 0

-- -- 0

-- -- Arkansas 0

-- -- 0

-- -- 0

-- -- Louisiana 0

-- -- 0

-- -- 0

-- -- Oklahoma 0

-- -- 0

-- -- 0

-- -- Texas 0

-- -- 0

-- -- 0

-- -- Mountain 0

-- -- 0

-- -- 0

-- -- Arizona 0

-- -- 0

-- -- 0

-- -- Colorado 0

-- -- 0

-- -- 0

-- -- Idaho 0

-- -- 0

-- -- 0

-- -- Montana 0

-- -- 0

-- -- 0

-- -- Nevada 0

-- -- 0

-- -- 0

-- -- New Mexico 0

-- -- 0

-- -- 0

-- -- Utah 0

-- -- 0

-- -- 0

-- -- Wyoming 0

-- -- 0

-- -- 0

-- -- Pacific Contiguous 0

-- -- 0

-- -- 0

-- -- California 0

-- -- 0

-- -- 0

-- -- Oregon 0

-- -- 0

-- -- 0

-- -- Washington 0

-- -- 0

-- -- 0

-- -- Pacific Noncontiguous 0

-- -- 0

-- -- 0

-- -- Alaska 0

-- -- 0

-- -- 0

-- -- Hawaii 0

-- -- 0

-- -- 0

-- -- U.S. Total 192 2.75 9.2 0

-- -- 0

-- --
Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.24. Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Commercial Sector by State, 2012 Bituminous Subbituminous LigniteCensus Division and State Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight Receipts (Thousand Tons)Average Sulfur Percent by WeightAverage Ash Percent by Weight New England 19 0.66 6.9 0

-- -- 0

-- -- Connecticut 0

-- -- 0

-- -- 0

-- -- Maine 19 0.66 6.9 0

-- -- 0

-- -- Massachusetts 0

-- -- 0

-- -- 0

-- -- New Hampshire 0

-- -- 0

-- -- 0

-- -- Rhode Island 0

-- -- 0

-- -- 0

-- -- Vermont 0

-- -- 0

-- -- 0

-- -- Middle Atlantic 698 1.80 9.6 0

-- -- 0

-- -- New Jersey 0

-- -- 0

-- -- 0

-- -- New York 333 1.68 10.2 0

-- -- 0

-- -- Pennsylvania 365 1.91 9.0 0

-- -- 0

-- -- East North Central 2,350 3.10 9.0 844 0.51 6.0 0

-- -- Illinois 1,657 3.36 9.0 575 0.62 6.5 0

-- -- Indiana 0

-- -- 0

-- -- 0

-- -- Michigan 46 0.46 6.6 0

-- -- 0

-- -- Ohio 269 3.59 11.3 0

-- -- 0

-- -- Wisconsin 377 2.07 7.8 269 0.28 5.0 0

-- -- West North Central 452 3.47 8.0 2,871 0.22 4.5 0

-- -- Iowa 452 3.47 8.0 1,720 0.22 4.4 0

-- -- Kansas 0

-- -- 0

-- -- 0

-- -- Minnesota 0

-- -- 396 0.25 5.2 0

-- -- Missouri 0

-- -- 0

-- -- 0

-- -- Nebraska 0

-- -- 755 0.20 4.4 0

-- -- North Dakota 0

-- -- 0

-- -- 0

-- -- South Dakota 0

-- -- 0

-- -- 0

-- -- South Atlantic 2,402 1.31 11.3 0

-- -- 0

-- -- Delaware 0

-- -- 0

-- -- 0

-- -- District of Columbia 0

-- -- 0

-- -- 0

-- -- Florida 242 0.75 9.8 0

-- -- 0

-- -- Georgia 395 1.03 10.4 0

-- -- 0

-- -- Maryland 390 2.13 22.6 0

-- -- 0

-- -- North Carolina 386 1.00 7.0 0

-- -- 0

-- -- South Carolina 179 0.80 8.8 0

-- -- 0

-- -- Virginia 473 1.84 9.0 0

-- -- 0

-- -- West Virginia 337 1.04 11.7 0

-- -- 0

-- -- East South Central 1,670 0.89 7.9 0

-- -- 0

-- -- Alabama 94 0.80 5.9 0

-- -- 0

-- -- Kentucky 0

-- -- 0

-- -- 0

-- -- Mississippi 0

-- -- 0

-- -- 0

-- -- Tennessee 1,576 0.89 8.0 0

-- -- 0

-- -- West South Central 0

-- -- 500 0.24 5.2 0

-- -- Arkansas 0

-- -- 0

-- -- 0

-- -- Louisiana 0

-- -- 0

-- -- 0

-- -- Oklahoma 0

-- -- 500 0.24 5.2 0

-- -- Texas 0

-- -- 0

-- -- 0

-- -- Mountain 230 0.33 9.4 208 0.96 14.5 0

-- -- Arizona 0

-- -- 208 0.96 14.5 0

-- -- Colorado 0

-- -- 0

-- -- 0

-- -- Idaho 0

-- -- 0

-- -- 0

-- -- Montana 0

-- -- 0

-- -- 0

-- -- Nevada 0

-- -- 0

-- -- 0

-- -- New Mexico 0

-- -- 0

-- -- 0

-- -- Utah 230 0.33 9.4 0

-- -- 0

-- -- Wyoming 0

-- -- 0

-- -- 0

-- -- Pacific Contiguous 643 0.42 10.8 100 0.33 4.1 0

-- -- California 643 0.42 10.8 0

-- -- 0

-- -- Oregon 0

-- -- 0

-- -- 0

-- -- Washington 0

-- -- 100 0.33 4.1 0

-- -- Pacific Noncontiguous 0

-- -- 0

-- -- 0

-- -- Alaska 0

-- -- 0

-- -- 0

-- -- Hawaii 0

-- -- 0

-- -- 0

-- -- U.S. Total 8,464 1.74 9.6 4,524 0.31 5.4 0

-- --
Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. NM = Not meaningful due to large relative standard error or excessive percentage change. W = Withheld to avoid disclosure of individual company data.

Notes: Starting in January 2013, there may be a shift in the continuity of Chapter 4 Tables, due to changes in the sample design of Form EIA-923 and the imputation process. See the Instrument Design History section of the Form EIA-923 Technical Notes for a more detailed explanation of these changes. See Glossary for definitions. Values are final. See Technical Notes for a discussion of the sample design for the Form EIA-923.
Source: U.S. Energy Information Administration, Form EIA-923, Power Plant Operations Report. 

### Table 7.25. Receipts and Quality of Coal by Rank Delivered for Electricity Generation: Industrial Sector by State, 2012 Bituminous Subbituminous Lignite

# Chapter 8
Electric Power System Characteristics and PerformanceYear Coal Petroleum Natural Gas Nuclear 2002 10,314 10,641 9,533 10,442 2003 10,297 10,610 9,207 10,422 2004 10,331 10,571 8,647 10,428 2005 10,373 10,631 8,551 10,436 2006 10,351 10,809 8,471 10,435 2007 10,375 10,794 8,403 10,489 2008 10,378 11,015 8,305 10,452 2009 10,414 10,923 8,159 10,459 2010 10,415 10,984 8,185 10,452 2011 10,444 10,829 8,152 10,464 2012 10,498 10,991 8,039 10,479 

### Table 8.1. Average Operating Heat Rate for Selected Energy Sources, 2002 through 2012 (Btu per Kilowatthour)

Coal includes anthracite, bituminous, subbituminous and lignite coal. Waste coal and synthetic coal are included starting in 2002. Petroleum includes distillate fuel oil (all diesel and No. 1 and No. 2 fuel oils), residual fuel oil (No. 5 and No. 6 fuel oils and bunker C fuel oil, jet fuel, kerosene, petroleum coke, and waste oil.

Notes: Included in the calculation for coal, petroleum, and natural gas average operating heat rate are electric power plants in the utility and independent power producer sectors. Combined heat and power plants, and all plants in the commercial and industrial sectors are excluded from the calculations. The nuclear average heat rate is the weighted average tested heat rate for nuclear units as reported on the Form EIA-860.
Sources: U.S. Energy Information Administration, Form EIA-923, "Power Plant Operations Report," and predecessor form(s) including U.S. Energy Information Administration, Form EIA-906, "Power Plant Report;" and Form EIA-920, "Combined Heat and Power Plant Report;" Form EIA-860, "Annual Electric Generator Report."Prime Mover Coal Petroluem Natural Gas Nuclear

Steam Generator 10,158 10,398 10,440 10,489 Gas Turbine

-- 13,217 11,632

-- Internal Combustion

-- 10,447 10,175

-- Combined Cycle W 10,970 7,577

--

Steam Generator 10,138 10,356 10,377 10,452 Gas Turbine

-- 13,311 11,576

-- Internal Combustion

-- 10,427 9,975

-- Combined Cycle W 10,985 7,642

--

Steam Generator 10,150 10,349 10,427 10,459 Gas Turbine

-- 13,326 11,560

-- Internal Combustion

-- 10,428 9,958

-- Combined Cycle W 10,715 7,605

--

Steam Generator 10,142 10,249 10,416 10,452 Gas Turbine

-- 13,386 11,590

-- Internal Combustion

-- 10,429 9,917

-- Combined Cycle W 10,474 7,619

--

Steam Generator 10,128 10,414 10,414 10,464 Gas Turbine

-- 13,637 11,569

-- Internal Combustion

-- 10,428 9,923

-- Combined Cycle W 10,650 7,603

--

Steam Generator 10,107 10,359 10,385 10,479 Gas Turbine

-- 13,622 11,499

-- Internal Combustion

-- 10,416 9,991

-- Combined Cycle W 10,195 7,615

-- 2011

2012

Notes: W = Withheld to avoid disclosure of individual company data.
Heat rate is reported at full load conditions for electric utilities and independent power producers. The average heat rates above are weighted by Net Summer Capacity. Coal Combined Cycle represents integrated gasification units.
Source: U.S. Energy Information Administration, Form EIA-860, 'Annual Electric Generator Report.' 

### Table 8.2. Average Tested Heat Rates by Prime Mover and Energy Source, 2007 - 2012 (Btu per Kilowatthour)

2007

2008

2009

2010Description 2002 2003 2004 2005 2006 2007 Utility Operating Revenues 219,609 230,151 238,759 265,652 275,501 270,964 ......Electric Utility 200,360 206,268 213,012 234,909 246,736 240,864 ......Other Utility 19,250 23,883 25,747 30,743 28,765 30,100 Utility Operating Expenses 189,062 201,057 206,960 236,786 245,589 241,198 ......Electric Utility 171,604 179,044 183,121 207,830 218,445 213,076 ............Operation 116,660 125,436 131,560 150,645 158,893 153,885 ..................Production 90,715 98,305 103,871 120,586 127,494 121,700 ........................Cost of Fuel 24,149 26,871 28,544 36,106 37,945 39,548 ........................Purchased Power 58,810 63,749 67,126 77,902 79,205 74,112 ........................Other 7,776 7,709 8,226 6,599 10,371 8,058 ..................Transmission 3,560 3,653 4,531 5,664 6,179 6,051 ..................Distribution 3,117 3,214 3,287 3,502 3,640 3,765 ..................Customer Accounts 4,168 4,262 4,077 4,229 4,409 4,652 ..................Customer Service 1,820 1,902 2,013 2,291 2,536 2,939 ..................Sales 264 238 237 219 240 239 ..................Administrative and General 13,018 13,863 13,537 14,130 14,580 14,346 ............Maintenance 10,861 11,340 11,743 12,033 12,838 13,181 ............Depreciation 16,199 15,981 16,322 17,123 17,373 17,936 ............Taxes and Other 26,716 25,027 22,190 26,805 28,149 27,000 ......Other Utility 17,457 22,013 23,839 28,956 27,143 28,122 Net Utility Operating Income 30,548 29,094 31,799 28,866 29,912 29,766

Description 2008 2009 2010 2011 2012 Utility Operating Revenues 298,962 276,124 285,512 280,520 270,912 ......Electric Utility 266,124 249,303 260,119 255,573 249,166 ......Other Utility 32,838 26,822 25,393 24,946 21,745 Utility Operating Expenses 267,263 244,243 253,022 247,118 235,694 ......Electric Utility 236,572 219,544 234,173 228,873 220,722 ............Operation 175,887 154,925 166,922 161,460 152,379 ..................Production 140,974 118,816 128,831 122,520 111,714 ........................Cost of Fuel 47,337 40,242 44,138 42,779 38,998 ........................Purchased Power 84,724 67,630 67,284 61,447 54,570 ........................Other 8,937 10,970 17,409 18,294 18,146 ..................Transmission 6,950 6,742 6,948 6,876 7,183 ..................Distribution 3,997 3,947 4,007 4,044 4,181 ..................Customer Accounts 5,286 5,203 5,091 5,180 5,086 ..................Customer Service 3,567 3,857 4,741 5,311 5,640 ..................Sales 225 178 185 185 221 ..................Administrative and General 14,718 15,991 17,120 17,343 18,353 ............Maintenance 14,192 14,092 14,957 15,772 15,489 ............Depreciation 19,049 20,095 20,951 22,555 23,677 ............Taxes and Other 26,202 29,081 31,343 29,086 29,177 ......Other Utility 30,692 24,698 18,849 18,245 14,972 Net Utility Operating Income 31,699 31,881 32,490 33,402 35,218 

### Table 8.3. Revenue and Expense Statistics for Major U.S. Investor-Owned Electric Utilities, 2002 through 2012 (Million Dollars)

Notes: 2007 financial data does not include information on Entergy Gulf State Louisiana LLC and Entergy Texas Inc. as both were not reported on the FERC Form for that year. Missing or erroneous respondent data may result in slight imbalances in some of the expense account subtotals. Total may not equal sum of components due to independent rounding. Sources: Federal Energy Regulatory Commission, FERC Form 1, "Annual Report of Major Electric Utilities, Licensees and Others via Ventyx Global Energy Velocity Suite.Year NuclearFossil Steam HydroelectricGas Turbine and Small Scale NuclearFossil Steam HydroelectricGas Turbine and Small Scale 2002 9.00 2.59 3.71 3.26 5.04 2.67 2.62 2.38 2003 9.12 2.74 3.47 3.50 5.23 2.72 2.32 2.26 2004 8.97 3.13 3.83 4.27 5.38 2.96 2.76 2.14 2005 8.26 3.21 3.95 3.69 5.27 2.98 2.73 1.89 2006 9.03 3.57 3.76 3.51 5.69 3.19 2.70 2.16 2007 9.54 3.63 5.44 3.26 5.79 3.37 3.87 2.42 2008 9.89 3.72 5.78 3.77 6.20 3.59 3.89 2.72 2009 10.00 4.23 4.88 3.05 6.34 3.96 3.50 2.58 2010 10.50 4.04 5.33 2.79 6.80 3.99 3.81 2.73 2011 10.89 4.02 5.13 2.81 6.80 3.99 3.74 2.93 2012 11.60 3.73 6.71 2.46 6.80 3.99 4.63 2.76

Year NuclearFossil Steam HydroelectricGas Turbine and Small Scale NuclearFossil Steam HydroelectricGas Turbine and Small Scale 2002 4.60 16.09

-- 31.84 18.65 21.36 6.33 37.47 2003 4.60 17.29

-- 43.89 18.95 22.75 5.79 49.66 2004 4.58 18.21

-- 45.18 18.93 24.31 6.60 51.59 2005 4.63 21.69

-- 55.52 18.15 27.88 6.68 61.10 2006 4.85 23.09

-- 53.89 19.57 29.85 6.46 59.56 2007 4.99 23.88

-- 58.75 20.32 30.88 9.32 64.43 2008 5.29 28.43

-- 64.23 21.37 35.75 9.67 70.72 2009 5.35 32.30

-- 51.93 21.69 40.48 8.38 57.55 2010 6.68 27.73

-- 43.21 23.98 35.76 9.15 48.74 2011 7.01 27.08

-- 38.80 24.70 35.09 8.88 44.54 2012 7.08 24.17

-- 30.45 25.48 31.89 11.34 35.67 Fuel Total

Hydroelectric category consists of both conventional hydroelectric and pumped storage. Gas Turbine and Small Scale category consists of gas turbine, internal combustion, photovoltaic, and wind plants. Notes: Expenses are average expenses weighted by net generation. A mill is a monetary cost and billing unit equal to 1/1000 of the U.S. dollar (equivalent to 1/10 of one cent). Total may not equal sum of components due to independent rounding. Sources: Federal Energy Regulatory Commission, FERC Form 1, "Annual Report of Major Electric Utilities, Licensees and Others via Ventyx Global Energy Velocity Suite. 

### Table 8.4. Average Power Plant Operating Expenses for Major U.S. Investor-Owned Electric Utilities, 2002 through 2012 (Mills per Kilowatthour)

Operation MaintenanceERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 40,696 56,012 442,535102,99655,56956,396

-- --29,119

-- --158,76739,688 56,248 119,074 714,565 2003 40,475 55,018 431,34998,48753,56656,988

-- --28,831

-- --153,11040,367 59,996 122,537 709,375 2004 42,383 52,549 427,86095,30052,04953,439

-- --29,351

-- --157,61540,106 58,531 123,136 704,459 2005 46,396 58,960 462,550

-- -- -- -- --39,918

--190,200190,70541,727 60,210 130,760 758,876 2006 45,751 63,241 476,048

-- -- -- -- --42,194

--191,920199,05242,882 62,339 142,096 789,475 2007 46,676 58,314 475,660

-- -- -- -- --41,684

--181,700209,10943,167 62,188 139,389 782,227 2008 44,836 58,543 452,087

-- -- -- -- --39,677

--169,155199,77943,476 62,174 134,829 752,470 2009 46,550 55,944 431,701

-- -- -- -- --37,963

--161,241191,03241,465 63,518 128,245 725,958 2010 45,722 60,554 466,543

-- -- --4,598108,346

--136,465

--164,05853,077 65,776 129,352 767,948 2011 44,968 63,390 486,131

-- -- --4,726102,819

--158,043

--164,72655,817 68,416 119,565 782,469 2012 44,338 58,319 468,092

-- -- --5,05196,769

--154,339

--161,68750,246 66,548 130,465 767,762

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 / 2003 45,635 46,009 371,97787,30046,55142,412

-- --23,645

-- --141,88230,187 45,414 95,951 604,986 2003 / 2004 36,841 48,079 364,23286,33245,62541,719

-- --24,134

-- --137,97228,450 42,702 102,020 593,874 2004 / 2005 44,839 48,176 378,98791,80045,90542,929

-- --24,526

-- --144,33729,490 44,010 102,689 618,701 2005 / 2006 42,657 46,828 381,246

-- -- -- -- --33,748

--151,600164,63831,260 48,141 107,493 626,365 2006 / 2007 42,526 46,697 390,263

-- -- -- -- --34,677

--149,631175,16330,792 50,402 111,093 640,981 2007 / 2008 41,701 46,795 386,301

-- -- -- -- --33,191

--141,900179,88831,322 50,408 112,700 637,905 2008 / 2009 45,275 46,043 390,829

-- -- -- -- --36,029

--142,395179,59632,809 47,806 113,605 643,557 2009 / 2010 53,022 44,864 405,176

-- -- -- -- --35,351

--143,827193,13532,863 56,191 109,565 668,818 2010 / 2011 46,135 45,712 400,589

-- -- --5,06986,728

--115,535

--152,03041,226 57,315 101,668 651,418 2011 / 2012 40,117 45,234 404,280

-- -- --4,80386,844

--122,563

--150,85039,220 50,100 108,459 648,190 2012 / 2013 36,409 45,545 390,818

-- -- --5,16874,430

--122,566

--153,73834,916 46,909 101,706 621,387 Winter Peak Load (Megawatts)

Eastern Interconnection

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Peak load represents an hour of a day during the associated peak period. The Summer peak period begins on June 1 and extends through September 30. The Winter peak period begins October 1 and extends through May 31. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. N/A - Not Available Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.6.A. Noncoincident Peak Load by North American Electric Reliability Corporation Assessment Area, 2002 - 2012, Actual

Summer Peak Load (Megawatts)

Eastern InterconnectionERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 44,338 58,319 468,0925,05196,769154,339161,68750,246 66,548 130,465 767,762 Projected 2013 45,668 59,969 469,8575,10996,192155,553159,03253,971 67,998 133,523 777,015 Projected 2014 46,338 60,654 475,0055,24996,879158,717159,45754,703 69,289 132,731 784,017 Projected 2015 47,053 61,428 484,6375,36097,565162,216164,15055,346 71,423 134,183 798,724 Projected 2016 47,650 62,386 491,8805,63298,251165,128166,81356,056 73,410 138,215 813,540 Projected 2017 48,285 62,871 497,6485,69598,938167,211169,03956,765 74,492 140,843 824,139

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 / 2013 36,409 45,545 390,8185,16874,430122,566153,73834,916 46,909 101,706 621,387 Projected 2013 / 2014 46,456 46,008 407,7175,72677,364132,229151,09741,301 54,390 109,058 663,629 Projected 2014 / 2015 47,161 46,090 414,2485,85279,813134,742152,01041,831 55,439 111,293 674,231 Projected 2015 / 2016 47,722 46,184 419,5285,92180,619137,338153,31042,339 57,090 112,709 683,233 Projected 2016 / 2017 48,251 46,546 424,2296,25680,931139,296154,79142,955 58,370 114,073 691,468 Projected 2017 / 2018 48,773 46,522 429,5216,30281,605140,430157,61343,571 59,087 115,658 699,561 Winter Peak Load (Megawatts)

Eastern Interconnection

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Projected data are updated annually. Peak load represents an hour of a day during the associated peak period. The Summer peak period begins on June 1 and extends through September 30. The Winter peak period begins October 1 and extends through May 31. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.6.B. Noncoincident Peak Load by North American Electric Reliability Corporation Assessment Area, 2012 Actual, 2013-2017 Projected

Summer Peak Load (Megawatts)

Eastern InterconnectionERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMRO PJM RFCSERC SPP TRE WECCContiguous U.S. 2002 211,116 286,1992,301,321567,897273,907279,264

-- --150,058

-- --835,319194,876 280,269 666,696 3,745,601 2003 219,021 288,7912,255,233545,109276,600267,068

-- --153,918

-- --826,964185,574 283,868 664,754 3,711,667 2004 220,335 292,7252,313,180553,236283,646274,760

-- --152,975

-- --856,734191,829 289,146 682,053 3,797,439 2005 226,544 303,6072,385,461

-- -- -- -- --216,633

--1,005,226962,054201,548 299,225 685,624 3,900,461 2006 230,115 294,3192,361,721

-- -- -- -- --222,748

--926,2791,011,173201,521 305,672 720,087 3,911,914 2007 232,405 301,7662,432,475

-- -- -- -- --217,602

--954,7001,049,298210,875 307,064 739,018 4,012,728 2008 226,874 297,3622,406,730

-- -- -- -- --227,536

--936,2011,035,390207,603 312,401 745,691 3,989,058 2009 225,966 285,6252,293,617

-- -- -- -- --213,797

--880,377997,142202,301 308,278 718,694 3,832,180 2010 233,034 294,2762,456,553

-- -- --30,691585,274

--712,731

--870,367257,491 319,097 713,177 4,016,137 2011 224,064 292,4822,401,810

-- -- --29,233521,692

--739,754

--852,843258,288 335,000 727,793 3,981,149 2012 220,943 290,9142,391,745

-- -- --29,362497,906

--781,247

--824,640258,590 324,860 726,862 3,955,323

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Net Energy for Load represents net Balancing Authority Area generation, plus energy received from other Balancing Authority Areas, less energy delivered to other Balancing Authority Areas through interchange. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. N/A - Not Available Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.7.A. Net Energy for Load by North American Electric Reliability Corporation Assessment Area, 2002 - 2012, Actual

Net Energy (Thousands of Megawatthours)

Eastern InterconnectionERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 220,943 290,9142,391,74529,362497,906781,247824,640258,590 324,860 726,862 3,955,323 Projected 2013 225,384 294,2642,498,32435,149548,976822,208828,189263,802 331,877 734,994 4,084,843 Projected 2014 229,771 295,6892,521,24136,158551,810843,697819,994269,582 340,369 746,821 4,133,891 Projected 2015 233,937 297,4022,559,76136,928554,704863,161838,690266,278 351,281 767,899 4,210,280 Projected 2016 237,569 300,0782,599,81437,853558,956882,669851,001269,334 362,282 778,039 4,277,781 Projected 2017 240,276 300,4742,626,64039,074561,645892,369861,713271,838 367,931 787,088 4,322,409

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Projected data are updated annually. Net Energy for Load represents net Balancing Authority Area generation, plus energy received from other Balancing Authority Areas, less energy delivered to other Balancing Authority Areas through interchange. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.7.B. Net Energy for Load by North American Electric Reliability Corporation Assessment Area, 2012 Actual, 2013-2017 Projected

Net Energy (Thousands of Megawatthours)

Eastern InterconnectionERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 37,951 55,164 430,396101,25154,29653,267

-- --28,825

-- --154,45938,298 55,833 117,032 696,376 2003 40,387 53,936 422,25398,48753,56653,617

-- --28,775

-- --148,38039,428 59,282 120,894 696,752 2004 42,243 51,580 419,34995,30052,04950,499

-- --29,094

-- --153,02439,383 58,531 121,205 692,908 2005 45,950 57,402 455,594

-- -- -- -- --38,266

--190,200186,04941,079 59,060 128,464 746,470 2006 45,345 60,879 469,639

-- -- -- -- --40,661

--190,800196,19641,982 61,214 139,402 776,479 2007 46,434 58,221 465,229

-- -- -- -- --40,249

--177,200205,32142,459 61,063 135,839 766,786 2008 44,660 59,896 447,629

-- -- -- -- --38,857

--169,155196,71142,906 61,049 130,916 744,151 2009 46,263 55,730 424,714

-- -- -- -- --35,849

--161,241186,50741,117 63,518 122,881 713,106 2010 45,522 56,232 453,436

-- -- --4,493100,963

--135,142

--160,89651,942 64,378 126,944 746,513 2011 44,798 62,313 466,360

-- -- --4,64198,290

--146,443

--161,99554,991 68,416 117,755 759,642 2012 44,338 58,319 469,273

-- -- --4,96796,769

--156,319

--158,04153,177 66,548 130,465 768,943

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 43,342 66,208 504,357119,73663,61967,025

-- --34,259

-- --172,48547,233 76,849 142,624 833,380 2003 46,806 70,902 513,382123,75565,89767,410

-- --33,287

-- --177,23145,802 74,764 150,277 856,131 2004 48,579 71,532 526,454127,91966,16765,677

-- --35,830

-- --182,86148,000 73,850 155,455 875,870 2005 50,200 72,258 532,917

-- -- -- -- --46,792

--220,000219,74946,376 66,724 160,026 882,125 2006 50,909 73,095 534,270

-- -- -- -- --50,116

--214,693223,63045,831 70,664 162,288 891,226 2007 53,027 73,771 543,608

-- -- -- -- --47,259

--213,544234,23248,573 75,912 168,080 914,397 2008 51,541 75,894 539,936

-- -- -- -- --48,180

--215,477228,16948,110 74,274 167,860 909,504 2009 49,239 78,639 559,823

-- -- -- -- --47,529

--215,700247,40049,194 76,280 152,467 916,449 2010 53,370 67,569 570,396

-- -- --7,210131,691

--167,647

--200,51163,337 73,857 158,407 923,599 2011 54,340 72,277 549,067

-- -- --5,244110,611

--170,066

--201,10362,044 69,595 147,147 892,426 2012 53,475 76,525 576,314

-- -- --5,981112,085

--187,305

--198,14072,802 73,219 147,527 927,060

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 12.4% 16.7% 14.7%15.4%14.7%20.5%

-- --15.9%

-- --10.5%18.9% 27.3% 17.9% 16.4% 2003 13.7% 23.9% 17.8%20.4%18.7%20.5%

-- --13.6%

-- --16.3%13.9% 20.7% 19.6% 18.6% 2004 13.0% 27.9% 20.3%25.5%21.3%23.1%

-- --18.8%

-- --16.3%18.0% 20.7% 22.0% 20.9% 2005 8.5% 20.6% 14.5%

-- -- -- -- --18.2%

--13.5%15.3%11.4% 11.5% 19.7% 15.4% 2006 10.9% 16.7% 12.1%

-- -- -- -- --18.9%

--11.1%12.3%8.4% 13.4% 14.1% 12.9% 2007 12.4% 21.1% 14.4%

-- -- -- -- --14.8%

--17.0%12.3%12.6% 19.6% 19.2% 16.1% 2008 13.4% 21.1% 17.1%

-- -- -- -- --19.3%

--21.5%13.8%10.8% 17.8% 22.0% 18.2% 2009 6.0% 29.1% 24.1%

-- -- -- -- --24.6%

--25.2%24.6%16.4% 16.7% 19.4% 22.2% 2010 14.7% 16.8% 20.5%

-- -- --37.7%23.3%

--19.4%

--19.8%18.0% 12.8% 19.9% 19.2% 2011 17.6% 13.8% 15.1%

-- -- --11.5%11.1%

--13.9%

--19.4%11.4% 1.7% 20.0% 14.9% 2012 17.1% 23.8% 18.6%

-- -- --17.0%13.7%

--16.5%

--20.2%27.0% 9.1% 11.6% 17.1%

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Net Internal Demand represent the system demand that is planned for by the electric power industry`s reliability authority and is equal to Internal Demand less Direct Control Load Management and Interruptible Demand. Capacity Resources: Utility and nonutility-owned generating capacity that is existing or in various stages of planning or construction, less inoperable capacity, plus planned capacity purchases from other resources, less planned capacity sales. Capacity Margin is the amount of unused available capability of an electric power system at peak load as a percentage of capacity resources. The Summer peak period begins on June 1 and extends through September 30. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. N/A - Not Available Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.8.A. Summer Net Internal Demand, Capacity Resources, and Capacity Margins by North American Electric Reliability Assessment Area, 2002 - 2012, Actual

Net Internal Demand (Megawatts) -- Summer

Eastern Interconnection

Capacity Resources (Megawatts) -- Summer

Eastern Interconnection

Capacity Margin (Percent) -- Summer

Eastern InterconnectionERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 44,338 58,319 469,2734,96796,769156,319158,04153,177 66,548 130,465 768,943 Projected 2013 42,532 59,969 447,1715,02291,644144,378152,94953,177 65,901 129,278 744,851 Projected 2014 43,142 60,654 448,9125,16192,331144,497152,84354,080 67,592 128,200 748,499 Projected 2015 43,812 61,428 457,8655,27093,017147,568157,28754,722 69,679 129,553 762,336 Projected 2016 44,355 62,386 464,8405,54093,703150,480159,68455,433 71,613 133,150 776,343 Projected 2017 44,907 62,871 470,4765,60194,390152,563161,70256,220 72,637 135,740 786,631

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 53,475 76,525 576,3145,981112,085187,305198,14072,802 73,219 147,527 927,060 Projected 2013 51,613 72,050 556,9596,412104,194176,356196,66073,337 72,681 155,044 908,348 Projected 2014 51,923 76,127 558,1576,570104,663177,039197,11672,768 75,182 172,443 933,830 Projected 2015 52,825 75,413 545,6406,71799,750171,655194,44773,071 76,010 174,960 924,848 Projected 2016 53,613 75,443 543,7866,79795,712173,523194,83072,924 77,220 175,673 925,736 Projected 2017 53,413 73,956 546,4716,75095,781174,971195,82073,150 78,383 177,344 929,567

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 17.1% 23.8% 18.6%17.0%13.7%16.5%20.2%27.0% 9.1% 11.6% 17.1% Projected 2013 17.6% 16.8% 19.7%21.7%12.0%18.1%22.2%27.5% 9.3% 16.6% 18.0% Projected 2014 16.9% 20.3% 19.6%21.4%11.8%18.4%22.5%25.7% 10.1% 25.7% 19.8% Projected 2015 17.1% 18.5% 16.1%21.5%6.8%14.0%19.1%25.1% 8.3% 26.0% 17.6% Projected 2016 17.3% 17.3% 14.5%18.5%2.1%13.3%18.0%24.0% 7.3% 24.2% 16.1% Projected 2017 15.9% 15.0% 13.9%17.0%1.5%12.8%17.4%23.1% 7.3% 23.5% 15.4%

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Net Internal Demand represent the system demand that is planned for by the electric power industry`s reliability authority and is equal to Internal Demand less Direct Control Load Management and Interruptible Demand. Capacity Resources: Utility and nonutility-owned generating capacity that is existing or in various stages of planning or construction, less inoperable capacity, plus planned capacity purchases from other resources, less planned capacity sales. Capacity Margin is the amount of unused available capability of an electric power system at peak load as a percentage of capacity resources. The Summer peak period begins on June 1 and extends through September 30. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.8.B. Summer Net Internal Demand, Capacity Resources, and Capacity Margins by North American Electric Reliability Corporation Assessment Area, 2012 Actual, 2013-2017 Projected

Net Internal Demand (Megawatts) -- Summer

Eastern Interconnection

Capacity Resources (Megawatts) -- Summer

Eastern Interconnection

Capacity Margin (Percent) -- Summer

Eastern InterconnectionERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 / 2003 42,001 45,980 360,74884,84446,15939,974

-- --23,090

-- --137,54129,140 44,719 94,554 588,002 2003 / 2004 36,229 47,850 357,02686,33245,62539,955

-- --24,042

-- --133,24427,828 41,988 100,337 583,430 2004 / 2005 41,449 47,859 371,01191,80045,56540,618

-- --24,446

-- --139,48629,096 44,010 101,002 605,331 2005 / 2006 42,493 46,328 375,365

-- -- -- -- --32,854

--151,600160,05430,857 46,991 105,670 616,847 2006 / 2007 45,993 48,394 385,887

-- -- -- -- --34,582

--147,800173,03630,469 46,038 107,586 633,898 2007 / 2008 46,093 46,185 383,779

-- -- -- -- --34,358

--141,200176,76631,455 46,068 113,504 635,629 2008 / 2009 45,042 47,151 384,495

-- -- -- -- --34,539

--142,395175,19932,362 46,747 110,977 634,412 2009 / 2010 51,703 44,864 399,204

-- -- -- -- --33,983

--143,827188,65332,741 56,191 106,256 658,219 2010 / 2011 45,954 44,172 389,351

-- -- --4,87780,311

--115,535

--148,06240,566 55,917 99,515 634,909 2011 / 2012 39,924 43,806 385,428

-- -- --4,44383,946

--110,963

--147,45438,622 50,100 107,568 626,826 2012 / 2013 36,409 45,545 386,359

-- -- --4,92574,430

--122,566

--149,35935,079 46,909 101,706 616,927

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 / 2003 46,219 68,884 511,642123,82366,14366,694

-- --33,224

-- --174,92546,833 73,335 132,278 832,358 2003 / 2004 50,010 73,123 524,995129,35168,13468,942

-- --32,769

-- --179,81045,989 77,111 152,158 877,397 2004 / 2005 51,196 74,277 538,041131,18769,60466,414

-- --34,371

-- --186,78449,681 71,902 149,360 884,776 2005 / 2006 49,066 76,076 545,850

-- -- -- -- --44,620

--229,000224,65247,578 61,003 152,211 884,206 2006 / 2007 56,896 76,110 547,005

-- -- -- -- --46,959

--220,930231,91747,199 71,451 166,362 917,824 2007 / 2008 57,510 75,772 537,094

-- -- -- -- --44,987

--212,257229,62750,223 75,504 167,770 913,650 2008 / 2009 53,278 79,394 545,843

-- -- -- -- --47,343

--215,477234,79748,226 73,910 167,312 919,736 2009 / 2010 52,751 78,992 567,746

-- -- -- -- --46,422

--215,700255,52750,097 69,490 151,022 920,002 2010 / 2011 57,358 70,557 573,274

-- -- --6,941129,241

--167,647

--207,55861,888 77,660 156,413 935,262 2011 / 2012 56,466 72,741 544,706

-- -- --4,96098,329

--170,077

--212,06359,276 69,202 150,091 893,206 2012 / 2013 57,431 79,173 576,569

-- -- --6,220110,600

--184,185

--205,37670,188 74,107 154,380 941,660

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionECARMAACMAINMAPPMISOMROPJMRFCSERCSPP TRE WECCContiguous U.S. 2002 / 2003 9.1% 33.3% 29.5%31.5%30.2%40.1%

-- --30.5%

-- --21.4%37.8% 39.0% 28.5% 29.4% 2003 / 2004 27.6% 34.6% 32.0%33.3%33.0%42.0%

-- --26.6%

-- --25.9%39.5% 45.5% 34.1% 33.5% 2004 / 2005 19.0% 35.6% 31.0%30.0%34.5%38.8%

-- --28.9%

-- --25.3%41.4% 38.8% 32.4% 31.6% 2005 / 2006 13.4% 39.1% 31.2%

-- -- -- -- --26.4%

--33.8%28.8%35.1% 23.0% 30.6% 30.2% 2006 / 2007 19.2% 36.4% 29.5%

-- -- -- -- --26.4%

--33.1%25.4%35.4% 35.6% 35.3% 30.9% 2007 / 2008 19.9% 39.0% 28.5%

-- -- -- -- --23.6%

--33.5%23.0%37.4% 39.0% 32.3% 30.4% 2008 / 2009 15.5% 40.6% 29.6%

-- -- -- -- --27.0%

--33.9%25.4%32.9% 36.8% 33.7% 31.0% 2009 / 2010 2.0% 43.2% 29.7%

-- -- -- -- --26.8%

--33.3%26.2%34.6% 19.1% 29.6% 28.5% 2010 / 2011 19.9% 37.4% 32.1%

-- -- --29.7%37.9%

--31.1%

--28.7%34.5% 28.0% 36.4% 32.1% 2011 / 2012 29.3% 39.8% 29.2%

-- -- --10.4%14.6%

--34.8%

--30.5%34.8% 27.6% 28.3% 29.8% 2012 / 2013 36.6% 42.5% 33.0%

-- -- --20.8%32.7%

--33.5%

--27.3%50.0% 36.7% 34.1% 34.5%

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Net Internal Demand represent the system demand that is planned for by the electric power industry`s reliability authority and is equal to Internal Demand less Direct Control Load Management and Interruptible Demand. Capacity Resources: Utility and nonutility-owned generating capacity that is existing or in various stages of planning or construction, less inoperable capacity, plus planned capacity purchases from other resources, less planned capacity sales. Capacity Margin is the amount of unused available capability of an electric power system at peak load as a percentage of capacity resources. The Winter peak period begins October 1 and extends through May 31. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. N/A - Not Available Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.9.A. Winter Net Internal Demand, Capacity Resources, and Capacity Margins by North American Electric Reliability Assessment Area, 2002 - 2012, Actual

Net Internal Demand (Megawatts) -- Winter

Eastern Interconnection

Capacity Resources (Megawatts) -- Winter

Eastern Interconnection

Capacity Margin (Percent) -- Winter

Eastern InterconnectionERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 / 2013 36,409 45,545 386,3594,92574,430122,566149,35935,079 46,909 101,706 616,927 Projected 2013 / 2014 43,384 46,008 399,1495,38575,320132,229145,65740,558 51,435 107,341 647,317 Projected 2014 / 2015 44,060 46,090 403,8835,50076,252134,742146,13041,259 53,742 109,418 657,192 Projected 2015 / 2016 44,596 46,184 408,9275,56377,058137,338147,20141,767 55,346 110,814 665,866 Projected 2016 / 2017 45,074 46,546 413,3565,88977,370139,296148,41842,383 56,573 112,143 673,691 Projected 2017 / 2018 45,543 46,522 418,4585,93378,044140,430151,05242,999 57,232 113,694 681,450

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 / 2013 57,431 79,173 576,5696,220110,600184,185205,37670,188 74,107 154,380 941,660 Projected 2013 / 2014 54,993 77,145 565,8357,207134,573188,684170,28465,086 72,145 151,849 921,966 Projected 2014 / 2015 57,184 80,211 583,7277,011105,650191,384205,79873,883 77,626 154,705 953,453 Projected 2015 / 2016 56,209 80,002 574,6347,195100,738187,909204,60174,192 78,134 155,690 944,669 Projected 2016 / 2017 58,187 80,132 570,9117,02796,699189,099204,08474,002 80,481 155,873 945,585 Projected 2017 / 2018 56,331 78,646 571,9936,92496,768189,171204,98574,145 80,424 156,342 943,736

ERCOT Western Interconnection All Interconnections

Period FRCC NPCCBalance of Eastern RegionMAPPMISOPJMSERCSPP TRE WECCContiguous U.S. Actual 2012 / 2013 36.6% 42.5% 33.0%20.8%32.7%33.5%27.3%50.0% 36.7% 34.1% 34.5% Projected 2013 / 2014 21.1% 40.4% 29.5%25.3%44.0%29.9%14.5%37.7% 28.7% 29.3% 29.8% Projected 2014 / 2015 23.0% 42.5% 30.8%21.6%27.8%29.6%29.0%44.2% 30.8% 29.3% 31.1% Projected 2015 / 2016 20.7% 42.3% 28.8%22.7%23.5%26.9%28.1%43.7% 29.2% 28.8% 29.5% Projected 2016 / 2017 22.5% 41.9% 27.6%16.2%20.0%26.3%27.3%42.7% 29.7% 28.1% 28.8% Projected 2017 / 2018 19.2% 40.8% 26.8%14.3%19.3%25.8%26.3%42.0% 28.8% 27.3% 27.8%

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Net Internal Demand represent the system demand that is planned for by the electric power industry`s reliability authority and is equal to Internal Demand less Direct Control Load Management and Interruptible Demand. Capacity Resources: Utility and nonutility-owned generating capacity that is existing or in various stages of planning or construction, less inoperable capacity, plus planned capacity purchases from other resources, less planned capacity sales. Capacity Margin is the amount of unused available capability of an electric power system at peak load as a percentage of capacity resources. The Winter peak period begins October 1 and extends through May 31. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. The historical data series for these regions have not been adjusted. Instead, the Balance of Eastern Region category was introduced to provide a consistent trend of the Eastern interconnection. ECAR, MAAC, and MAIN dissolved at the end of 2005. Many of the former utility members joined RFC. Reliability First Corporation (RFC) came into existence on January 1, 2006. RFC submitted a consolidated filing covering the historical NERC regions of ECAR, MAAC, and MAIN. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.9.B. Winter Net Internal Demand, Capacity Resources, and Capacity Margins by North American Electric Reliability Corporation Assessment Area, 2012 Actual, 2013-2017 Projected

Net Internal Demand (Megawatts) -- Winter

Eastern Interconnection

Capacity Resources (Megawatts) -- Winter

Eastern Interconnection

Capacity Margin (Percent) -- Winter

Eastern InterconnectionType Operating (kV) FRCC MRO NPCC RFC SERC SPP TRE WECCContiguous U.S. AC 100-199

-- -- -- -- -- -- -- -- -- AC 200-299 6,018 7,813 1,538 6,933 21,757 2,948

-- 38,410 85,416 AC 300-399

-- 7,362 5,850 13,429 3,650 5,303 9,529 10,913 56,036 AC 400-599 1,201 543

-- 2,618 8,876 94

-- 12,794 26,125 AC 600-799

-- -- 190 2,226

-- -- -- -- 2,416 AC Multi-Circuit Structure 200-299 1,198 686 36 2,008 4,156 9

-- -- 8,092 AC Multi-Circuit Structure 300-399

-- 372 274 3,706 313 153 2,747

-- 7,564 AC Multi-Circuit Structure 400-599

-- -- -- 90 857

-- -- -- 947 AC Multi-Circuit Structure 600-799

-- -- -- -- -- -- -- -- -- AC Multi-Circuit Structure Mixed

-- 57 28 9 35

-- -- -- 128 AC Total US Total 8,416 16,832 7,915 31,018 39,643 8,507 12,276 62,117 186,724 DC 100-199

-- -- -- -- -- -- -- -- -- DC 200-299

-- 930

-- -- -- -- -- 53 983 DC 300-399

-- -- -- -- -- -- -- -- -- DC 400-499

-- 872

-- -- -- -- -- -- 872 DC 500-599

-- -- -- 66

-- -- -- 2,137 2,203 DC 600-799

-- -- -- -- -- -- -- -- -- DC Total US Total
-- 1,802
-- 66
-- -- -- 2,190 4,058 Grand Total Grand Total 8,416 18,634 7,915 31,084 39,643 8,507 12,276 64,307 190,782

Type Operating (kV) FRCC MRO NPCC RFC SERC SPP TRE WECCContiguous U.S. AC 100-199

-- -- -- -- -- -- -- -- -- AC 200-299 411 191 62 577 1,297 133

-- 1,526 4,197 AC 300-399

-- 195 254 488 118 120 305 145 1,626 AC 400-599 19 3

-- 76 235 1

-- 231 565 AC 600-799

-- -- 2 32

-- -- -- -- 34 AC Multi-Circuit Structure 200-299

-- -- -- -- -- -- -- -- -- AC Multi-Circuit Structure 300-399

-- -- -- -- -- -- -- -- -- AC Multi-Circuit Structure 400-599

-- -- -- -- -- -- -- -- -- AC Multi-Circuit Structure 600-799

-- -- -- -- -- -- -- -- -- AC Multi-Circuit Structure Mixed

-- -- -- -- -- -- -- -- -- AC Total US Total 430 389 318 1,173 1,651 255 305 1,902 6,422 DC 100-199

-- -- -- -- -- -- -- -- -- DC 200-299

-- 2

-- -- -- -- -- 1 3 DC 300-399

-- -- -- -- -- -- -- -- -- DC 400-499

-- 2

-- -- -- -- -- -- 2 DC 500-599

-- -- -- 1

-- -- -- 4 5 DC 600-799

-- -- -- -- -- -- -- -- -- DC Total US Total
-- 4
-- 1
-- -- -- 5 10 Grand Total Grand Total 430 393 318 1,174 1,651 255 305 1,907 6,432

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Circuit miles do not equal physical miles on the ground; the reference terminology for that concept is structural mile. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.10.A. Existing Transmission Capacity by High-Voltage Size, 2012

Voltage Circuit Miles

Voltage Circuit CountsType Operating (kV)Year 2013Year 2014Year 2015Year 2016Year 2017Year 2018Year 2019All Years AC 100-199 954 1,222 992 1,047 392 382 176 5,165 AC 200-299 1,003 792 1,398 319 539 427 118 4,596 AC 300-399 4,779 839 1,532 1,527 502 1,650 349 11,178 AC 400-599 399 708 669 643 660 1,151 334 4,564 AC 600+

-- -- 14

-- -- 69

-- 83 AC Total 7,134 3,562 4,606 3,536 2,092 3,679 978 25,586 DC 100-199 2 11 5

-- -- 7

-- 25 DC 200-299

-- -- -- -- -- -- -- -- DC 300-399

-- -- -- -- 333

-- -- 333 DC 400-599

-- -- 10

-- -- -- -- 10 DC 600+

-- -- -- -- -- -- -- -- DC Total 2 11 15
-- 333 7
-- 368 Grand Total 7,136 3,573 4,621 3,536 2,425 3,687 978 25,955

Notes: NERC region and reliability assessment area maps are provided on EIA's Electricity Reliability web page: http://www.eia.gov/cneaf/electricity/page/eia411/eia411.html Circuit miles do not equal physical miles on the ground; the reference terminology for that concept is structural mile. Some structures were designed and then built to carry future transmission circuits in order to handle expected growth in new capability requirements. Lines are taken out of service for a variety of reasons including intentional changes to the right-of-way to better useavailable land for different levels of voltage and types of poles and towers. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply and Demand Program Report." 

### Table 8.10.B. Proposed Transmission Capacity Additions by High-Voltage Size, 2013 - 2019 (Circuit Miles of Transmission)

Voltage Circuit MilesOutage Type FRCC MRO NPCC RFC SERC SPP TRE WECCContiguous U.S.

Automatic Outages (Sustained) 151 163 127 272 374 105 80 796 2,068 Non-Automatic Outages (Operational) 77 44 97 230 192 27 45 337 1,049 Non-Automatic Outages (Planned) 2,650 453 512 2,050 2,450 369 472 2,744 11,700

Automatic Outages (Sustained) 2,852 1,313 14,245 19,857 7,124 1,510 683 24,239 71,822 Non-Automatic Outages (Operational) 187 27 68 186 427 3 14 68 979 Non-Automatic Outages (Planned) 873 710 1,222 1,095 503 357 105 1,105 5,972

Automatic Outages (Sustained) 17.94 8.75 16.05 8.75 9.43 12.34 6.52 12.38 10.84 Non-Automatic Outages (Operational) 9.15 2.36 12.25 7.40 4.84 3.17 3.67 5.24 5.50 Non-Automatic Outages (Planned) 314.87 24.31 64.69 65.95 61.80 43.38 38.45 42.67 61.33

Automatic Outages (Sustained) 18.89 8.06 112.16 73.00 19.05 14.38 8.53 30.45 34.73 Non-Automatic Outages (Operational) 2.43 0.62 0.70 0.81 2.22 0.12 0.31 0.20 0.93 Non-Automatic Outages (Planned) 0.33 1.57 2.39 0.53 0.21 0.97 0.22 0.40 0.51

Notes: Circuit Miles for each region is displayed in Table 8.10.A. An Automatic Outage is an outage which results from the automatic operation of a switching device, causing an Element to change from an In-Service State to a not In-Service State. A Sustained Outage is an automatic outage with an outage duration of a minute or greater. A Non-Automatic Outage is an outage which results from the manual operation (including supervisory control) of a switching device, causing an element to change from an In-Service State to a not In-Service State. An Operational Outage is a Non-Automatic Outage for the purpose of avoiding an emergency (i.e., risk to human life, damage to equipment, damage to property) or to maintain the system within operational limits and that cannot be deferred. A Planned Outage is a Non-Automatic Outage with advance notice for the purpose of maintenance, construction, inspection, testing, or planned activities by third parties that may be deferred. Detailed information on the Transmission Availability Data System outage definitions is available at: http://www.nerc.com/docs/pc/tadswg/Appendix%207%2020101202a%20clean.pdf
Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report." 

### Table 8.11.A. U.S. Transmission Circuit Outages by Type and NERC region, 2012

Circuit Outage Counts

Circuit Outage Hours

Circuit Outage Counts per 1,000 Circuit Miles

Circuit Outage Hours per Outage IncidentOutage Type Eastern Interconnection TRE WECC Contiguous U.S.

Automatic Outages (Sustained) 16

-- 16 32 Non-Automatic Outages (Operational) 48

-- 73 121 Non-Automatic Outages (Planned) 291

-- 290 581

Automatic Outages (Sustained) 3,224

-- 302 3,526 Non-Automatic Outages (Operational) 514

-- 10 524 Non-Automatic Outages (Planned) 2,383

-- 770 3,153

Automatic Outages (Sustained) 201.51

-- 18.86 110.19 Non-Automatic Outages (Operational) 10.71

-- 0.14 4.33 Non-Automatic Outages (Planned) 8.19

-- 2.65 5.43

Notes: An Automatic Outage is an outage which results from the automatic operation of a switching device, causing an Element to change from an In-Service State to a not In-Service State. A Sustained Outage is an automatic outage with an outage duration of a minute or greater. A Non-Automatic Outage is an outage which results from the manual operation (including supervisory control) of a switching device, causing an element to change from an In-Service State to a not In-Service State. An Operational Outage is a Non-Automatic Outage for the purpose of avoiding an emergency (i.e., risk to human life, damage to equipment, damage to property) or to maintain the system within operational limits and that cannot be deferred. A Planned Outage is a Non-Automatic Outage with advance notice for the purpose of maintenance, construction, inspection, testing, or planned activities by third parties that may be deferred. Detailed information on the Transmission Availability Data System outage definitions is available at: http://www.nerc.com/docs/pc/tadswg/Appendix%207%2020101202a%20clean.pdf
Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report." 

### Table 8.11.B. U.S. Transformer Outages by Type and NERC region, 2012

Circuit Outage Counts

Circuit Outage Hours

Circuit Outage Hours per Outage IncidentType Operating (kV) FRCC MRO NPCC RFC SERC SPP TRE WECCContiguous U.S. AC 200-299 142 49 14 141 242 49

-- 484 1,121 AC 300-399

-- 88 107 95 46 56 80 165 637 AC 400-599 9 3

-- 22 86

-- -- 125 245 AC 600+

-- -- 6 9

-- -- -- -- 15 AC Total 151 140 127 267 374 105 80 774 2,018 DC 100-199

-- -- -- -- -- -- -- -- -- DC 200-299

-- 18

-- -- -- -- -- 5 23 DC 300-399

-- -- -- -- -- -- -- -- -- DC 400-499

-- 5

-- -- -- -- -- -- 5 DC 500-599

-- -- -- 5

-- -- -- 17 22 DC 600+

-- -- -- -- -- -- -- -- -- DC Total
-- 23
-- 5
-- -- -- 22 50 Grand Total 151 163 127 272 374 105 80 796 2,068

FRCC MRO NPCC RFC SERC SPP TRE WECCContiguous U.S. Rate 21.08 7.54 18.90 10.69 11.01 13.03 8.29 12.63 11.77

Type Operating (kV) FRCC MRO NPCC RFC SERC SPP TRE WECCContiguous U.S. AC 200-299 823 256 7,832 10,033 4,672 494

-- 13,264 37,374 AC 300-399

-- 835 6,386 5,892 1,080 1,016 683 578 16,468 AC 400-599 2,030 15

-- 1,825 1,372

-- -- 10,087 15,328 AC 600+

-- -- 28 2,089

-- -- -- -- 2,117 AC Total 2,852 1,106 14,245 19,839 7,124 1,510 683 23,930 71,287 DC 100-199

-- -- -- -- -- -- -- -- -- DC 200-299

-- 127

-- -- -- -- -- 44 171 DC 300-399

-- -- -- -- -- -- -- -- -- DC 400-499

-- 80

-- -- -- -- -- -- 80 DC 500-599

-- -- -- 19

-- -- -- 264 283 DC 600+

-- -- -- -- -- -- -- -- -- DC Total
-- 207
-- 19
-- -- -- 308 534 Grand Total 2,852 1,313 14,245 19,857 7,124 1,510 683 24,239 71,822

FRCC MRO NPCC RFC SERC SPP TRE WECCContiguous U.S. Rate 18.89 8.06 112.16 73.00 19.05 14.38 8.53 30.45 34.73 

### Table 8.12.A. U.S. Transmission Circuit Sustained Automatic Outage Counts and Hours by High-Voltage Size and NERC Region, 2012

Sustained Automatic Outage Counts Voltage Region

Total Outages per 1,000 Circuit Miles Region

Notes: * = Value is less than half of the smallest unit of measure. (e.g., for values with no decimals, the smallest unit is 1 then values under 0.5 are shown as *.) Circuit Miles for each region is displayed in Table 8.10.A.An Automatic Outage is an outage which results from the automatic operation of a switching device, causing an Element to change from an In-Service State to a not InService State. A Sustained Outage is an automatic outage with an outage duration of a minute or greater. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report." Sustained Automatic Outage Hours Voltage Region

Outage Hours per Outage Incident RegionHigh-Side Voltage (kV) Eastern Interconnection TRE WECC Contiguous U.S. 100-199

-- -- -- -- 200-299

-- -- 1 1 300-399 2

-- 4 6 400-599 14

-- 11 25

600+

-- -- -- -- Grand Total 16
-- 16 32

High-Side Voltage (kV) Eastern Interconnection TRE WECC Contiguous U.S. 100-199

-- -- -- -- 200-299

-- -- 28 28 300-399 153

-- 16 169 400-599 3,071

-- 258 3,329

600+

-- -- -- -- Grand Total 3,224
-- 302 3,526

Eastern Interconnection TRE WECC Contiguous U.S. Rate 201.51
-- 18.86 110.19 Outage Hours per Outage Incident

Notes: * = Value is less than half of the smallest unit of measure. (e.g., for values with no decimals, the smallest unit is 1 then values under 0.5 are shown as *.) Eastern NERC Regions are aggregated to preserve confidentiality. An Automatic Outage is an outage which results from the automatic operation of a switching device, causing an Element to change from an In-Service State to a not In-Service State. A Sustained Outage is an automatic outage with an outage duration of a minute or greater. Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report." 

### Table 8.12.B. U.S. Transformer Sustained Automatic Outage Counts and Hours by High-Voltage Size and NERC Region, 2012

Sustained Automatic Outage Counts

Sustained Automatic Outage HoursSustained Outage Causes FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning 6 27 3 30 63 12

-- 69 210 Lightning 5 10 8 5 31 16 13 57 145 Environmental

-- 1 1 5

-- 1

-- -- 8 Contamination 14

-- -- -- 22 3 6 7 52 Foreign Interference 34 3

-- 4 13 1 2 14 71 Fire

-- 2

-- 1 6 3 1 85 98 Vandalism, Terrorism, or Malicious Acts

-- -- -- -- 2

-- -- 1 3 Failed AC Substation Equipment 18 16 35 63 57 16 15 65 285 Failed AC/DC Terminal Equipment

-- 14

-- 4

-- -- -- 6 24 Failed Protection System Equipment 16 10 25 42 35 7 11 53 199 Failed AC Circuit Equipment 26 12 25 34 47 14 6 79 243 Failed DC Circuit Equipment

-- 1

-- -- -- -- -- 3 4 Vegetation 2

-- 3 7 17

-- -- 10 39 Power System Condition 1 7

-- 17 2 3 5 42 77 Human Error 8 36 10 38 43 6 18 104 263 Unknown 14 14 6 8 22 13 1 124 202 Other 7 10 11 14 14 10 2 77 145 TOTAL 151 163 127 272 374 105 80 796 2,068

Sustained Outage Causes FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning 4.0%16.6%2.4%11.0%16.8%11.4%0.0%8.7% 10.2% Lightning 3.3%6.1%6.3%1.8%8.3%15.2%16.3%7.2% 7.0% Environmental 0.0%0.6%0.8%1.8%0.0%1.0%0.0%0.0% 0.4% Contamination 9.3%0.0%0.0%0.0%5.9%2.9%7.5%0.9% 2.5% Foreign Interference 22.5%1.8%0.0%1.5%3.5%1.0%2.5%1.8% 3.4% Fire 0.0%1.2%0.0%0.4%1.6%2.9%1.3%10.7% 4.7% Vandalism, Terrorism, or Malicious Acts 0.0%0.0%0.0%0.0%0.5%0.0%0.0%0.1% 0.2% Failed AC Substation Equipment 11.9%9.8%27.6%23.2%15.2%15.2%18.8%8.2% 13.8% Failed AC/DC Terminal Equipment 0.0%8.6%0.0%1.5%0.0%0.0%0.0%0.8% 1.2% Failed Protection System Equipment 10.6%6.1%19.7%15.4%9.4%6.7%13.8%6.7% 9.6% Failed AC Circuit Equipment 17.2%7.4%19.7%12.5%12.6%13.3%7.5%9.9% 11.8% Failed DC Circuit Equipment 0.0%0.6%0.0%0.0%0.0%0.0%0.0%0.4% 0.2% Vegetation 1.3%0.0%2.4%2.6%4.6%0.0%0.0%1.3% 1.9% Power System Condition 0.7%4.3%0.0%6.3%0.5%2.9%6.3%5.3% 3.7% Human Error 5.3%22.1%7.9%14.0%11.5%5.7%22.5%13.1% 12.7% Unknown 9.3%8.6%4.7%2.9%5.9%12.4%1.3%15.6% 9.8% Other 4.6%6.1%8.7%5.2%3.7%9.5%2.5%9.7% 7.0% TOTAL 100.0%100.0%100.0%100.0%100.0%100.0%100.0%100.0% 100.0% Percentage of Total AC & DC Circuit Outage Counts 

### Table 8.13.A. U.S. Transmission Circuit Sustained Automatic Outage Counts and Hours by Cause Code and by NERC Region, 2012 (Page 1)

AC & DC Circuit Outage Counts

Notes: Detailed information on the Transmission Availability Data System outage causes is available at: http://www.nerc.com/docs/pc/tadswg/Appendix%207%2020101202a%20clean.pdf Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report."Sustained Outage Causes FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning 24 193 1817,7372,294 322

-- 616 11,368 Lightning 27 3 17 8 57 89 42 73 315 Environmental

-- 8 932,954

-- 1

-- -- 3,056 Contamination 128

-- -- -- 396 4 0 13 540 Foreign Interference 98 13

-- 22 139 0 1 88 362 Fire

-- 1

-- 10 31 29 191,987 2,077 Vandalism, Terrorism, or Malicious Acts

-- -- -- -- 28

-- -- 0 28 Failed AC Substation Equipment 2,072 27410,3124,773 601 249 317 642 19,239 Failed AC/DC Terminal Equipment

-- 119

-- 18

-- -- -- 22 159 Failed Protection System Equipment 125 77 746 235 184 15 20 470 1,871 Failed AC Circuit Equipment 304 2772,5043,5972,662 337 11010,406 20,199 Failed DC Circuit Equipment

-- 78

-- -- -- -- -- 29 107 Vegetation 23

-- 53 180 172

-- -- 87 516 Power System Condition 0 97

-- 85 12 24 1464,891 5,255 Human Error 17 32 21 179 157 7 274,261 4,701 Unknown 27 11 63 10 132 69 0 486 799 Other 7 130 253 48 261 364 0 168 1,232 TOTAL 2,8521,31314,24519,8577,1241,510 68324,239 71,822

Sustained Outage Causes FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning 0.8%14.7%1.3%39.0%32.2%21.3%0.0%2.5% 15.8% Lightning 0.9%0.2%0.1%0.0%0.8%5.9%6.1%0.3% 0.4% Environmental 0.0%0.6%0.7%14.9%0.0%0.0%0.0%0.0% 4.3% Contamination 4.5%0.0%0.0%0.0%5.6%0.2%0.0%0.1% 0.8% Foreign Interference 3.4%1.0%0.0%0.1%2.0%0.0%0.2%0.4% 0.5% Fire 0.0%0.1%0.0%0.1%0.4%1.9%2.8%8.2% 2.9% Vandalism, Terrorism, or Malicious Acts 0.0%0.0%0.0%0.0%0.4%0.0%0.0%0.0% 0.0% Failed AC Substation Equipment 72.6%20.8%72.4%24.0%8.4%16.5%46.4%2.7% 26.8% Failed AC/DC Terminal Equipment 0.0%9.1%0.0%0.1%0.0%0.0%0.0%0.1% 0.2% Failed Protection System Equipment 4.4%5.9%5.2%1.2%2.6%1.0%2.9%1.9% 2.6% Failed AC Circuit Equipment 10.7%21.1%17.6%18.1%37.4%22.3%16.2%42.9% 28.1% Failed DC Circuit Equipment 0.0%6.0%0.0%0.0%0.0%0.0%0.0%0.1% 0.2% Vegetation 0.8%0.0%0.4%0.9%2.4%0.0%0.0%0.4% 0.7% Power System Condition 0.0%7.4%0.0%0.4%0.2%1.6%21.3%20.2% 7.3% Human Error 0.6%2.4%0.2%0.9%2.2%0.5%4.0%17.6% 6.6% Unknown 1.0%0.9%0.4%0.1%1.9%4.6%0.1%2.0% 1.1% Other 0.2%9.9%1.8%0.2%3.7%24.1%0.1%0.7% 1.7% TOTAL 100.0%100.0%100.0%100.0%100.0%100.0%100.0%100.0% 100.0% Percentage of Total AC & DC Circuit Outage Hours

Notes: Detailed information on the Transmission Availability Data System outage causes is available at: http://www.nerc.com/docs/pc/tadswg/Appendix%207%2020101202a%20clean.pdf Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report." 

### Table 8.13.A. U.S. Transmission Circuit Sustained Automatic Outage Counts and Hours by Cause Code and by NERC Region, 2012 (Page 2)

AC & DC Circuit Outage HoursSustained Outage Causes FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning

-- -- -- -- 1

-- -- -- 1 Lightning

-- -- -- -- -- -- -- -- -- Environmental

-- -- -- -- -- -- -- -- -- Contamination 1

-- -- -- -- -- -- -- 1 Foreign Interference

-- -- -- -- -- -- -- -- -- Fire

-- -- -- -- -- -- -- -- -- Vandalism, Terrorism, or Malicious Acts

-- -- -- -- -- -- -- -- -- Failed AC Substation Equipment 3 1

-- 1 5

-- -- 4 14 Failed AC/DC Terminal Equipment

-- -- -- -- -- -- -- -- -- Failed Protection System Equipment

-- 1

-- -- 3

-- -- -- 4 Failed AC Circuit Equipment

-- -- -- -- -- -- -- -- -- Failed DC Circuit Equipment

-- -- -- -- -- -- -- -- -- Vegetation

-- -- -- -- -- -- -- -- -- Power System Condition

-- -- -- -- -- -- -- 1 1 Human Error

-- -- -- -- -- -- -- 2 2 Unknown

-- -- -- -- -- -- -- 6 6 Other

-- -- -- -- -- -- -- 3 3 TOTAL 4 2
-- 1 9
-- -- 16 32

Sustained Outage Causes FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning 0.0%0.0%

--0.0%11.1%

-- --0.0% 3.1% Lightning 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Environmental 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Contamination 25.0%0.0%

--0.0%0.0%

-- --0.0% 3.1% Foreign Interference 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Fire 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Vandalism, Terrorism, or Malicious Acts 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Failed AC Substation Equipment 75.0%50.0%

--100.0%55.6%

-- --25.0% 43.8% Failed AC/DC Terminal Equipment 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Failed Protection System Equipment 0.0%50.0%

--0.0%33.3%

-- --0.0% 12.5% Failed AC Circuit Equipment 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Failed DC Circuit Equipment 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Vegetation 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Power System Condition 0.0%0.0%

--0.0%0.0%

-- --6.3% 3.1% Human Error 0.0%0.0%

--0.0%0.0%

-- --12.5% 6.3% Unknown 0.0%0.0%

--0.0%0.0%

-- --37.5% 18.8% Other 0.0%0.0%

--0.0%0.0%

-- --18.8% 9.4% TOTAL 100.0%100.0%
--100.0%100.0%
-- --100.0% 100.0% Percentage of Total Transformer Outage Counts 

### Table 8.13.B. U.S. Transformer Sustained Automatic Outage Counts and Hours by Cause Code and by NERC Region, 2012 (Page 1)

Transformer Outage Counts

Notes: Detailed information on the Transmission Availability Data System outage causes is available at: http://www.nerc.com/docs/pc/tadswg/Appendix%207%2020101202a%20clean.pdf Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report."Sustained Outage Causes FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning

-- -- -- -- 2

-- -- -- 2 Lightning

-- -- -- -- -- -- -- -- -- Environmental

-- -- -- -- -- -- -- -- -- Contamination 22

-- -- -- -- -- -- -- 22 Foreign Interference

-- -- -- -- -- -- -- -- -- Fire

-- -- -- -- -- -- -- -- -- Vandalism, Terrorism, or Malicious Acts

-- -- -- -- -- -- -- -- -- Failed AC Substation Equipment 2,683 132

-- 48 104

-- -- 44 3,012 Failed AC/DC Terminal Equipment

-- -- -- -- -- -- -- -- -- Failed Protection System Equipment

-- 21

-- -- 212

-- -- -- 233 Failed AC Circuit Equipment

-- -- -- -- -- -- -- -- -- Failed DC Circuit Equipment

-- -- -- -- -- -- -- -- -- Vegetation

-- -- -- -- -- -- -- -- -- Power System Condition

-- -- -- -- -- -- -- 1 1 Human Error

-- -- -- -- -- -- -- 0 0 Unknown

-- -- -- -- -- -- -- 255 255 Other

-- -- -- -- -- -- -- 0 0 TOTAL 2,705 153
-- 48 318
-- -- 302 3,526

OUTAGE_CAUSE FRCCMRONPCCRFCSERCSPPTREWECCContiguous U.S. Weather, excluding lightning 0.0%0.0%

--0.0%0.7%

-- --0.0% 0.1% Lightning 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Environmental 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Contamination 0.8%0.0%

--0.0%0.0%

-- --0.0% 0.6% Foreign Interference 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Fire 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Vandalism, Terrorism, or Malicious Acts 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Failed AC Substation Equipment 99.2%86.5%

--100.0%32.8%

-- --14.7% 85.4% Failed AC/DC Terminal Equipment 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Failed Protection System Equipment 0.0%13.6%

--0.0%66.5%

-- --0.0% 6.6% Failed AC Circuit Equipment 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Failed DC Circuit Equipment 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Vegetation 0.0%0.0%

--0.0%0.0%

-- --0.0% 0.0% Power System Condition 0.0%0.0%

--0.0%0.0%

-- --0.4% 0.0% Human Error 0.0%0.0%

--0.0%0.0%

-- --0.1% 0.0% Unknown 0.0%0.0%

--0.0%0.0%

-- --84.6% 7.2% Other 0.0%0.0%

--0.0%0.0%

-- --0.1% 0.0% TOTAL 100.0%100.0%
--100.0%100.0%
-- --100.0% 100.0% Percentage of Total Transformer Outage Hours

Notes: Detailed information on the Transmission Availability Data System outage causes is available at: http://www.nerc.com/docs/pc/tadswg/Appendix%207%2020101202a%20clean.pdf Source: U.S. Energy Information Administration, Form EIA-411, "Coordinated Bulk Power Supply Program Report." 

### Table 8.13.B. U.S. Transformer Sustained Automatic Outage Counts and Hours by Cause Code and by NERC Region, 2012 (Page 2)

Transformer Outage Hours

# Chapter 9

Environmental DataYear Carbon Dioxide (CO2) Sulfur Dioxide (SO2) Nitrogen Oxides (NOx) 2002 2,423,963 10,881 5,194 2003 2,445,094 10,646 4,532 2004 2,486,982 10,309 4,143 2005 2,543,838 10,340 3,961 2006 2,488,918 9,524 3,799 2007 2,547,032 9,042 3,650 2008 2,484,012 7,830 3,330 2009 2,269,508 5,970 2,395 2010 2,388,596 5,400 2,491 2011 2,287,071 4,845 2,406 2012 2,156,875 3,704 2,148 

### Table 9.1. Emissions from Energy Consumption at Conventional Power Plants and Combined-Heat-and-Power Plants 2002 through 2012 (Thousand Metric Tons)

Notes: The emissions data presented include total emissions from both electricity generation and the production of useful thermal output. See Appendix A, Technical Notes, for a description of the sources and methodology used to develop the emissions estimates. Source: Calculations made by the Office of Electricity, Renewables, and Uranium Statistics, U.S. Energy Information Administration.Year Average Operation and Maintenance Costs (Mills per Kilowatthour) Average Installed Capital Costs (Dollars per Kilowatt) 2007 1.51 135.41 2008 1.55 150.77 2009 1.61 186.73 2010 1.61 206.27 2011 1.94 240.34 2012 2.07 252.48 

### Table 9.4. Average Costs of Existing Flue Gas Desulfurization Units, 2007 - 2012

Source: U.S. Energy Information Administration, Form EIA-860, "Annual Electric Generator Report"Census Division and State

Year 2012Year 2011Year 2012Year 2011Year 2012Year 2011 New England 34,766 37,698 33 58 39 37 Connecticut 8,987 8,196 7 1 12 6 Maine 3,722 4,351 8 12 7 8 Massachusetts 14,346 16,404 15 22 14 14 New Hampshire 4,295 5,127 2 23 4 5 Rhode Island 3,403 3,595 0 0 2 3 Vermont 12 24 0 0 1 1 Middle Atlantic 161,786 171,603 275 370 187 203 New Jersey 16,120 16,917 4 5 14 13 New York 35,669 37,256 31 52 40 43 Pennsylvania 109,997 117,430 240 313 133 147 East North Central 398,780 438,218 1,099 1,533 379 442 Illinois 94,411 100,731 172 207 61 73 Indiana 99,773 109,608 260 347 107 120 Michigan 67,877 69,301 215 235 81 82 Ohio 95,523 112,320 355 616 91 121 Wisconsin 41,196 46,257 98 128 39 46 West North Central 237,669 253,061 443 543 262 286 Iowa 41,267 43,879 96 101 42 44 Kansas 31,693 35,119 30 36 33 41 Minnesota 28,494 32,618 33 52 36 41 Missouri 75,545 81,428 136 190 66 61 Nebraska 26,467 27,251 58 68 29 41 North Dakota 30,934 29,855 79 86 46 48 South Dakota 3,269 2,911 12 10 11 9 South Atlantic 384,603 419,896 570 771 318 367 Delaware 4,981 3,928 2 8 3 4 District of Columbia 66 175 0 1 0 0 Florida 111,236 114,441 101 113 84 83 Georgia 59,035 71,368 149 237 50 75 Maryland 20,697 23,625 40 49 22 25 North Carolina 57,924 62,797 74 91 53 50 South Carolina 34,238 38,720 65 87 22 30 Virginia 29,223 32,637 56 86 36 44 West Virginia 67,203 72,203 83 98 48 55 East South Central 220,815 237,905 450 608 175 205 Alabama 69,107 76,413 148 195 51 65 Kentucky 85,683 92,694 171 226 75 85 Mississippi 24,285 23,326 43 48 23 26 Tennessee 41,741 45,472 88 138 25 29 West South Central 399,292 417,434 616 693 370 410 Arkansas 36,234 35,926 84 80 38 41 Louisiana 60,182 62,680 108 118 75 78 Oklahoma 49,186 51,364 74 90 63 77 Texas 253,689 267,464 350 405 194 214 Mountain 233,511 235,951 161 216 277 313 Arizona 52,350 53,536 19 30 46 53 Colorado 39,926 39,509 39 43 45 51 Idaho 1,172 825 5 5 4 3 Montana 16,024 17,029 15 18 16 17 Nevada 14,929 14,748 4 5 12 12 New Mexico 29,163 31,164 15 16 55 57 Utah 32,484 33,943 20 23 49 58 Wyoming 47,463 45,197 44 78 49 62 Pacific Contiguous 73,724 62,858 39 34 105 105 California 59,369 47,908 6 3 84 81 Oregon 7,365 6,721 13 14 9 9 Washington 6,990 8,229 20 18 12 15 Pacific Noncontiguous 11,930 12,447 17 20 36 37 Alaska 4,305 4,347 3 3 17 17 Hawaii 7,625 8,100 15 17 19 20 U.S. Total 2,156,8752,287,071 3,704 4,845 2,148 2,406

Notes: The emissions data presented include total emissions from both electricity generation and the production of useful thermal output. See Appendix A, Technical Notes, for a description of the sources and methodology used to develop the emissions estimates. Displayed values of zero may represent small values that round to zero. The Excel version of this table provides additional precision which may be accessed by selecting individual cells. Source: Calculations made by the Office of Electricity, Renewables, and Uranium Statistics, U.S. Energy Information Administration. 

### Table 9.5. Emissions from Energy Consumption at Conventional Power Plants and Combined-Heat-and-Power Plants, by State, 2011 and 2012 (Thousand Metric Tons)
Carbon Dioxide (CO2) Sulfur Dioxide (SO2) Nitrogen Oxides (NOx)

# Chapter 10

Demand

-Side Management and Advanced MeteringYearEnergy Savings (Thousand MWh)Actual Peak Load Reduction (MW)Energy Savings (Thousand MWh)Potential Peak Load Reduction (MW)Actual Peak Load Reduction (MW)Energy Savings (Thousand MWh)Actual Peak Load Reduction (MW) 2002 50,328 13,457 1,700 26,471 9,256 52,029 22,713 2003 48,254 13,585 1,935 25,261 9,298 50,189 22,883 2004 52,663 14,272 1,966 20,997 9,263 54,629 23,535 2005 59,000 15,394 930 21,259 10,341 59,930 25,735 2006 63,076 16,006 790 21,254 11,268 63,866 27,274 2007 67,278 17,773 1,859 23,091 12,545 69,137 30,318 2008 74,871 19,708 1,822 26,318 12,064 76,693 31,772 2009 76,912 19,761 1,027 26,310 11,972 77,939 31,732 2010 86,914 20,828 447 26,100 12,536 87,361 33,364 2011 120,659 26,314 556 26,596 12,126 121,214 38,439 2012 138,525 28,924 712 28,503 13,200 139,237 42,124 Previously, annual effects were reported for large respondents only. Now the annual effects include large and small respondents, combined. Non-Utility DSM Administrators are included in the 2011 data. See technical notes for list. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." 

### Table 10.1. Demand-Side Management Program Annual Effects by Program Category, 2002 through 2012Energy Efficiency Load Management TotalYear Residential Commercial Industrial Transportation Total

2002 15,284 24,803 10,242

-- 50,328 2003 12,914 24,758 10,031 551 48,254 2004 17,185 24,290 11,137 50 52,663 2005 18,894 28,073 11,986 47 59,000 2006 21,150 28,720 13,155 50 63,076 2007 22,772 30,359 14,038 108 67,278 2008 25,396 34,634 14,766 75 74,871 2009 27,395 34,831 14,610 76 76,912 2010 32,150 37,416 17,259 89 86,914 2011 46,790 50,732 23,061 76 120,659 2012 54,516 58,894 25,023 92 138,525

2002 5,300 5,389 2,768

-- 13,457 2003 5,909 4,911 2,671 94 13,585 2004 5,868 5,541 2,858 5 14,272 2005 6,057 6,395 2,935 7 15,394 2006 6,900 6,067 3,032 7 16,006 2007 8,275 6,241 3,250 7 17,773 2008 8,764 7,838 2,991 114 19,708 2009 8,724 7,954 3,074 9 19,761 2010 9,404 8,046 3,368 10 20,828 2011 11,391 10,422 4,490 11 26,314 2012 12,821 11,743 4,348 12 28,924

2002 531 153 1,016

-- 1,700 2003 559 335 1,041

-- 1,935 2004 578 334 1,055

-- 1,966 2005 408 383 138

-- 930 2006 321 331 138 1 790 2007 953 463 442

-- 1,859 2008 1,151 239 431

-- 1,822 2009 436 197 394

-- 1,027 2010 215 113 118

-- 447 2011 237 194 125

-- 556 2012 257 368 87

-- 712

2002 6,877 4,065 15,529

-- 26,471 2003 6,618 4,033 14,599 11 25,261 2004 6,112 4,082 10,794 9 20,997 2005 6,075 3,832 11,297 55 21,259 2006 6,176 3,957 11,064 57 21,254 2007 7,022 3,984 12,030 55 23,091 2008 8,097 6,029 12,137 55 26,318 2009 7,308 6,460 12,462 81 26,310 2010 7,998 6,080 11,750 272 26,100 2011 7,882 6,023 12,380 311 26,596 2012 8,600 6,462 13,261 180 28,503

2002 3,942 1,606 3,708

-- 9,256 2003 3,524 1,864 3,899 11 9,298 2004 3,014 1,652 4,588 9 9,263 2005 3,407 1,544 5,388 2 10,341 2006 3,863 1,730 5,643 32 11,268 2007 4,949 1,837 5,749 10 12,545 2008 4,158 3,270 4,625 12 12,064 2009 3,899 3,464 4,606 3 11,972 2010 4,726 2,854 4,819 137 12,536 2011 4,105 2,808 5,108 105 12,126 2012 4,152 3,208 5,732 108 13,200 Load Management - Actual Peak Load Reduction (MW)

Transportation data is not available before 2003. Previously, annual data included only large respondents. Now it includes large and small respondents, combined. Non-Utility DSM Administrators are included in the 2011 data. See technical notes for list. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." 

### Table 10.2. Demand-Side Management Program Annual Effects by Program Category, by Sector, 2002 through 2012

Energy Efficiency - Energy Savings (Thousand MWh)

Energy Efficiency - Actual Peak Load Reduction (MW)

Load Management - Energy Savings (Thousand MWh)

Load Management - Potential Peak Load Reduction (MW)YearEnergy Savings (Thousand MWh)Actual Peak Load Reduction (MW)Energy Savings (Thousand MWh)Potential Peak Load Reduction (MW)Actual Peak Load Reduction (MW)Energy Savings (Thousand MWh)Actual Peak Load Reduction (MW) 2002 3,625 1,103 66 2,730 1,213 3,690 2,316 2003 2,948 1,035 33 2,112 1,165 2,981 2,200 2004 4,532 1,727 36 3,064 1,163 4,569 2,890 2005 5,879 1,705 137 2,223 1,162 6,016 2,867 2006 5,394 1,268 99 2,817 1,690 5,492 2,958 2007 7,680 1,998 137 4,765 2,392 7,817 4,390 2008 10,428 6,327 168 7,253 3,292 10,596 9,619 2009 12,907 3,721 65 6,042 2,224 12,972 5,945 2010 13,592 3,215 46 5,234 2,709 13,639 5,923 2011 21,421 3,974 135 4,043 2,062 21,556 6,036 2012 21,478 3,764 41 5,357 2,671 21,520 6,435 Previously, large and small respondents were published separately, now they are combined. Non-Utility DSM Administrators are included in the 2011 data. See technical notes for list. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." 

### Table 10.3. Demand-Side Management Program Incremental Effects by Program Category, 2002 through 2012Energy Efficiency Load Management TotalYear Residential Commercial Industrial Transportation Total

2002 1,205 1,720 700

-- 3,625 2003 855 1,352 729 12 2,948 2004 1,827 1,812 894

-- 4,532 2005 2,249 2,559 1,071

-- 5,879 2006 2,127 2,281 986

-- 5,394 2007 3,659 2,830 1,178 13 7,680 2008 4,568 4,383 1,477 1 10,428 2009 5,030 4,959 2,918 1 12,907 2010 6,492 5,325 1,771 5 13,592 2011 9,989 8,166 3,261 6 21,421 2012 9,531 8,924 3,019 4 21,478

2002 576 395 118 14 1,103 2003 511 351 171 2 1,035 2004 1,138 393 196

-- 1,727 2005 913 562 230

-- 1,705 2006 665 433 170

-- 1,268 2007 994 763 240 1 1,998 2008 4,543 1,168 614 1 6,327 2009 1,849 1,044 827 1 3,721 2010 1,378 1,053 783 1 3,215 2011 1,628 1,545 800 1 3,974 2012 1,775 1,562 426 1 3,764

2002 43 10 6 6 66 2003 19 10 3

-- 33 2004 21 10 5

-- 36 2005 34 84 19

-- 137 2006 23 62 14

-- 99 2007 13 98 26

-- 137 2008 32 62 74

-- 168 2009 34 21 10

-- 65 2010 13 21 12

-- 46 2011 29 86 21

-- 135 2012 20 14 7

-- 41

2002 799 399 1,402 130 2,730 2003 357 324 1,412 19 2,112 2004 945 664 1,455

-- 3,064 2005 765 636 822

-- 2,223 2006 905 776 1,136

-- 2,817 2007 2,342 1,324 1,045 54 4,765 2008 3,013 2,156 2,083 1 7,253 2009 1,922 1,971 2,127 22 6,042 2010 1,976 1,171 2,087

-- 5,234 2011 1,324 1,327 1,392

-- 4,043 2012 1,369 1,155 2,833 1 5,357

2002 367 173 573 100 1,213 2003 217 235 703 10 1,165 2004 509 300 354

-- 1,163 2005 378 224 560

-- 1,162 2006 478 389 823

-- 1,690 2007 1,221 562 567 42 2,392 2008 1,179 1,445 667 1 3,292 2009 793 781 648 3 2,224 2010 666 948 1,095

-- 2,709 2011 817 619 625

-- 2,062 2012 686 737 1,248 * 2,671 Load Management - Actual Peak Load Reduction (MW)

Transportation data is not available before 2003. Previously, large and small respondents were published separately, now they are combined. Non-Utility DSM Administrators are included in the 2011 data. See technical notes for list. Totals may not equal sum of components because of independent rounding. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." 

### Table 10.4. Demand-Side Management Program Incremental Effects by Program Category, by Sector, 2004 through 2012

Energy Efficiency - Energy Savings (Thousand MWh)

Energy Efficiency - Actual Peak Load Reduction (MW)

Load Management - Energy Savings (Thousand MWh)

Load Management - Potential Peak Load Reduction (MW)YearEnergy EfficiencyLoad Management Direct Cost Indirect Cost Total Cost 2002 1,032,911 410,323 1,443,234 206,169 1,649,403 2003 807,403 352,137 1,159,540 137,670 1,340,686 2004 910,816 510,281 1,421,097 132,295 1,560,578 2005 1,180,576 622,287 1,802,863 127,925 1,939,115 2006 1,270,602 663,980 1,934,582 128,886 2,072,962 2007 1,677,969 700,362 2,378,331 160,326 2,604,711 2008 2,137,452 836,359 2,973,811 181,843 3,186,742 2009 2,221,480 944,261 3,165,741 394,193 3,607,076 2010 2,906,906 1,048,356 3,955,262 275,158 4,230,420 2011 4,002,672 1,213,102 5,215,774 328,622 5,544,396 2012 4,397,635 1,270,391 5,668,026 332,440 6,000,466 

### Table 10.5. Demand-Side Management Program Direct and Indirect Costs, 2002 through 2012 (Thousand Dollars)

Direct Costs reflect electric utility costs incurred during the year that are identified with Energy Efficiency and Load Management. Total Costs are the sum of Direct and Indirect Costs. Previously, this table included only large respondents. Now it includes large and small respondents, combined. For the total cost data, prior to 2010, both large and small respondents reported total costs, however small respondents did not break out the costs into direct and indirect. The direct and indirect costs were reported for large respondents only. Therefore, prior to 2010 the total cost does not equal the sum of the direct and indirect costs. Totals may not equal sum of components because of independent rounding. Non-Utility DSM Administrators are included in the 2011 data. See technical notes for list. Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report."Year Residential Commercial Industrial Transportation Total

2007 25,785,782 2,322,329 44,015 109 28,152,235 2008 36,425,943 3,529,985 77,122 13 40,033,063 2009 41,462,111 4,239,531 107,033 11 45,808,686 2010 43,913,225 4,611,877 159,315 626 48,685,043 2011 41,451,888 4,341,105 172,692 77 45,965,762 2012 43,455,437 4,691,018 185,862 125 48,330,822

2007 2,202,222 262,159 9,106 2 2,473,489 2008 4,190,244 444,003 12,757 12 4,647,016 2009 8,712,297 876,419 22,675 10 9,611,401 2010 18,369,908 1,904,983 59,567 67 20,334,525 2011 33,453,548 3,682,159 154,659 7 37,290,373 2012 38,524,639 4,461,350 179,159 35 43,165,183 

### Table 10.6. Advanced Metering Count by Technology Type, 2007 through 2012

Automated Meter Reading (AMR)

Advanced Metering Infrastructure (AMI)

Prior to 2010, the count was the number of customers, not number of meters.Source: U.S. Energy Information Administration, Form EIA-861, "Annual Electric Power Industry Report." Form EIA861S, "Annual Electric Power Industry Report (Short Form)."

# AppendixU.S. EnergyInformation Administration | Electric Power Annual



# Technical Notes
This appendix describes how the U.S. Energy Information Administration collects, estimates, and reports electric power data in the Electric Power Annual. 

## Data Qualityand Submission The Electric Power Annual (EPA) is prepared by the Office of Electricity, Renewables, and Uranium Statistics (ERUS), U.S. Energy Information Administration (EIA), U.S. Department of Energy (DOE). ERUS performs routine reviews of the data collection respondent frames, survey forms, and reviews the quality of the data received.
Data are entered directly by respondents into the ERUS Internet Data Collection (IDC) system. A small number of hard copy forms are keyed into the system by ERUS personnel. All data are subject to review via interactive edits built into the IDC system, internal quality assurance reports, and review by ERUS subject matter experts. Questionable data values are verified through contacts with respondents, and survey non
-respondents are identified and contacted.
IDC edits include both deterministic checks, in which records are checked for the presence of data in required fields, and statistical checks, in which the data are checked against a range of values based on historical data values and for logical or mathematical consistency with data elements reported in the survey. Discrepancies found in the data, as a result of these checks, must either be corrected by the respondent or the respondent must enter an explanation as towhy the data are correct. If these explanations are unsatisfactory the respondent is contacted by EIA for clarification or corrected data.
Those respondents unable to use the electronic reporting method provide the data in hard copy, typically via fax andemail. These data are manually entered into the computerized database and are subjected to the same data edits as those performed during e

-filing by the respondent. 

## Reliability ofData Annual survey data have non

-sampling errors. Non

-sampling errors can be attributed to many sources: (1) inability to obtain complete information about all cases (i.e., non

-response); (2) response errors; (3) definitional difficulties; (4) differences in the interpretation of questions; (5) mistakes in recording or coding thedata; and (6) other errors of collection, response, coverage, and estimation for missing data.
Although no direct measurement of the biases due to non

-sampling errors can be obtained, precautionary steps were taken in all phases of the frame developmentand data collection, processing, and tabulation processes to minimize their influence.
Imputation:If the reported values appear to be in error and the data issue cannot be resolved with the respondent, or if the facility is a non

-respondent, a regressionmethodology is used to impute for the facility. The regression methodology relies on other data to make estimates for erroneous or missing responses. The basis for the current methodology involves a 'borrowing of strength' technique for small domains.1U.S. EnergyInformation Administration | Electric Power Annual



## DataRevisionProcedure The EPA presents the most current and complete data available to the EIA. The statistics may differ from those published previously in EIA publications due to corrections, revisions, or other adjustments to the data subsequent to its original release.
After data are disseminated as final, revisions will be considered if a correction would make a difference of 1 percent or greater at the national level. Revisions for differences that do not meet the 1 percent or greater threshold willbe determined by the Office Director. In either case, the proposed revision will be subject to the EIA revision policy concerning how it affects other EIA products.
Sensitive Data (Formerly Identified as Data Confidentiality):Most of the data collected on the electric power surveys are not considered business sensitive. However, the data that are classified as sensitive are handled by ERUS consistent with EIA's “Policy on the Disclosure of Individually Identifiable Energy Information in the Possession ofthe EIA” (45 Federal Register 59812 (1980)). 

## Rounding and Percent Change Calculations RoundingRules forData:To round a number to n digits (decimal places), add one unit to the nth digit if the (n+1) digit is 5 or larger and keep the nth digit unchanged if the (n+1) digit is less than 5. The symbol for a number rounded to zero is (*).

PercentChange:The following formula is used to calculate percentchanges:

PercentChange=
wherex (t1

### )andx (t2



### )denote the quantity atperiodt1

### and subsequentperiodt2

### . 

## Data Sources for Electric Power Annual
Datapublished in the EPA are compiled from forms filed annually or aggregated to an annual basis from monthly forms (see figure on EIA Electric Industry Data Collection in Appendix A). The respondents to these forms include electric utilities, other generators and sellers of electricity, and North American Electric Reliability Corporation (NERC) reliability entities. The EIA forms used are:

Form EIA

-411, “Coordinated Bulk Power Supply Program Report;”

Form EIA

-826, “Monthly Electric Utility Sales and Revenues with State Distributions Report;”

Form EIA

-860, “Annual Electric Generator Report;”

Form EIA

-861, “Annual Electric Power Industry Report;”

Form EIA

-861S, “Annual Electric Power Industry Report(Short Form);”

Form EIA

-923, "Power Plant Operations Report."

These forms can be found on the EIA Internet website at: http://www.eia.gov/cneaf/electricity/page/forms.html.
Survey data from other Federal sources are also utilized for this publication.They include:U.S. EnergyInformation Administration | Electric Power Annual 

### FERC Form 1, “Annual Report of Major ElectricUtilities, Licensees, and Others;”

U. S. Department of Agriculture (USDA) Rural Utility Service Form 7, “Financial and Statistical Report;” and

USDA Rural Utility Service Form 12, “Operating Report

–Financial.”

In addition to the above

-named forms, thehistorical data published in the EPA are compiled from the following inactive forms:

Form EIA

-412, “Annual Electric Industry Financial Report,” FERC Form 423, “Cost and Quality of Fuels for Electric Plants,”

Form EIA

-423, “Monthly Cost and Quality of Fuels for Electric Plants Report;”

Form EIA

-759, “Monthly Power Plant Report,”

Form EIA

-767, “Steam

-Electric Plant Operation and Design Report;”

Form EIA

-860A, “Annual Electric Generator Report

–Utility,”

Form EIA

-860B, “Annual Electric Generator Report

–Nonutility,”

Form EIA

-867, “Annual Nonutility Power Producer Report,”

Form EIA

-900, “Monthly Nonutility Power Report,”

Form EIA

-906, “Power Plant Report;” and

Form EIA

-920, “Combined Heat and Power Plant Report.”
Additionally, some data reported in this publication were acquired from public reports of the National Energy Board of Canada on electricity imports and exports.
Meanings ofSymbolsAppearing inTables: The following symbols have the meaningdescribed below:

*The value reported is less than half of the smallest unit of measure, but is greater than zero.

PIndicates a preliminary value.

WWithheld to avoid disclosure of individual company data.

NMData value is not meaningful, either (1) whencompared to the same value for the previous time period, or (2) when a data value is not meaningful due to having a high Relative Standard Error (RSE).
(*)Usage of this symbol indicates a number rounded to zero.


## Form EIA

-411 The information reported on the mandatory Form EIA

-411 includes: (1) actual energy and peak demand for the preceding year and five additional years; (2) existing and future generating capacity and capacity reserve margins; (3) scheduled capacity transfers; (4) projections of capacity,demand, purchases, sales, and scheduled maintenance; (5) power flow cases; and (6) bulk power system maps. The data is collected for EIA by NERC from NERC regional reliability entities, which in turn aggregate reports from regional members. Non

-member data is also included. The compiled data is reviewed and edited by NERC and submitted to EIA annually on July 15. The data undergoes additional review by EIA. EIA resolves any quality issues with NERC.U.S. EnergyInformation Administration | Electric Power Annual



### Instrument andDesignHistory:The Form EIA

-411 program was initiated under the Federal Power Commission (FPC) Docket R

-362, Reliability and Adequacy of Electric Service, and Orders 383

-2, 383

-3, and 383

-4. The DOE, established in October 1977, assumed the responsibility for this activity. The responsibility for collecting these data was delegated to the Office of Emergency Planning and Operations within the DOE and was transferred to EIA for the reporting year 1996. Until 2008, this form was voluntary

.The dataarecollected under the authority of the Federal Power Act (Public Law 88

-280), the Federal Energy Administration Act of 1974 (Public Law 93

-275), and the DOE Organization Act (Public Law 95

-91)

. Issues within Historical Data Series:The Florida Reliability Coordinating Council (FRCC) separated itself from the Southeastern Electric Reliability Council (SERC) in the mid

-1990s and all time series data have been adjusted. In 1998, several utilities realigned from Southwest Power Pool (SPP) to SERC. Adjustments were made to the information to account for the separation and to address the tracking of shared reserve capacity that was under long

-term contracts with multiple members. Name changes altered the Mid

-Continent Area Power Pool (MAPP) to the Midwest Reliability Organization (MRO) and the WesternSystems Coordinating Council (WSCC) to the Western Electricity Coordinating Council (WECC). The MRO membership boundaries have altered over time, but WECC membership boundaries have not. The utilities in the associated regional entity identified as the Alaska System Coordination Council (ASCC) dropped their formal participation in NERC. (Alaska and, obviously, Hawaii arenot electrically interconnected with the coterminous 48States)

. At the close of calendar year 2005, the following reliability regionalcouncils were dissolved: East Central Area Reliability Coordination Agreement (ECAR), Mid

-Atlantic Area Council (MAAC), and Mid

America Interconnected Network (MAIN). On January 1, 2006, the ReliabilityFirst Corporation (RFC) came into existence as a new regional reliability council. Individual utility membership in the former ECAR, MAAC, and MAIN councils mostly shifted to RFC. However, adjustments in membership, as utilities joined or left various reliability councils, impacted MRO, SERC, and SPP. The Texas Regional Entity (TRE) was formed to handle the regional reliability responsibilities of the Electric Reliability Council of Texas (ERCOT). The revised delegation agreements covering all the regions were approved by the FERC on March 21, 2008. Reliability Councils that are unchanged include: Florida Reliability Coordinating Council (FRCC), Northeast Power Coordinating Council (NPCC), and the Western Electricity Coordinating Council (WECC). The historical time series have not been adjusted to account for individual membership shifts.
The current NERC regional entity names are as follows:

Florida Reliability Coordinating Council (FRCC),

Midwest Reliability Organization (MRO),

Northeast Power Coordinating Council (NPCC),

ReliabilityFirst Corporation (RFC),

Southeastern Electric Reliability Council (SERC),

Southwest Power Pool (SPP),

Texas Regional Entity (TRE), and

Western Energy Coordinating Council (WECC).U.S. EnergyInformation Administration | Electric Power Annual



### Changes Introduced in 2011:Starting in 2011, NERC modifiedthe bulk power system reporting regions (in contrast to regional reliability entity organizational boundaries) to align them with electric market operations. Consequently, reliability data will be reported for the PJM and MISO regional transmission organization areas and the MAPP area rather than for the MRO and RFC regional areas

.This new framework, along with the other NERC regions, now forms the bulk power system reliability assessment

areas. Historically the MRO, RFC, SERC, and SPP regional boundaries were altered as utilities changed reliability organizations. In published EIA reports the historical data series for these regions have not been adjusted. Instead, starting in 2011, EIA has introduced the Balance of Eastern Region category to providea consistent trend for the Eastern interconnection

. Concept of Demand within the EIA

-411:The EIA

-411 uses the following categorization of electricity demand:

Net Internal Demand:Internal Demand less Direct Control Load Management and

InterruptibleDemand.

Internal Demand:To collect these data, NERC develops a Total Internal Demand that is the sum of the metered (net) outputs of all generators within the system and the metered line flows into the system, less the metered line flows out of the system. The demand of station service or auxiliary needs (such as fan motors, pump motors, and other equipment essential to the operation of the generating units) is not included nor are any requirement customer (utility) load or capacity found behindthe linemeters on the system

.
Direct Control Load Management:Demand

-Side Management that is under the direct control of the system operator. DCLM may control the electric supply to individual appliances or equipment on customer premises; it does not included Interruptible Demand

.
Interruptible Demand:The magnitude of customer demand that, in accordance with contractual arrangements, can be interrupted at the time of the Regional Council’s seasonal peak by direct control of the System Operator or by action of thecustomer at the directrequest of the System Operator

. For additional information on demand, refer to the NERC’s Long

-Term Reliability Assessments at http://www.nerc.com/page.php?cid=4|61

.
SensitiveData:Power flow cases and maps areconsidered business sensitive

. 

## Form EIA

-412 (Terminated) The Form EIA

-412 was used annually to collect accounting, financial, and operating data from publicly owned electric utilities engaged in the generation, transmission, or distribution of electricity which had 150,000 megawatthours of sales to ultimate consumers and/or 150,000 megawatthours of sales for resale for the two previous years. Data was collected annually.U.S. EnergyInformation Administration | Electric Power Annual



### Beginning with the 2001 data collection, the plantstatistics reported on Schedule 9 were also collected from unregulated entities that own plants with a nameplate capacity of 10 megawatts or greater. Beginning with the 2003 collection, the transmission data reported in Schedules 10 and 11 were collectedfrom each generation and transmission cooperative owning transmission lines having a nominal voltage of 132 kilovolts or greater.
Instrument and Design History:The FPC created the FPC Form 1M in 1961 as a mandatory survey. It became the responsibility of the EIA in October 1977 when the FPC was merged with DOE and renamed the Federal Energy Regulatory Commission (FERC). In 1979, the FPC Form 1M was superseded by the Economic Regulatory Administration (ERA) Form ERA

-412 and in January 1980 by the Form EIA

-412.
The criteria used to select the respondents for this survey fit approximately 500 publicly owned electric utilities. Federal electric utilities were required to file the Form EIA

-412. The financial data for the U.S. Army Corps of Engineers (except for Saint Mary's Falls at Sault Ste. Marie, Michigan); the U.S. Department of Interior, Bureau of Reclamation; and the U.S. International Boundary and Water Commission were collected on the Form EIA

-412 from the Federal power marketing administrations. Theform was terminated after the 2003 data year

. Issues within Historical Data Series:For 2001

-2003, the California Department of Water Resources (CDWR) Electric Energy Fund data were included in the EIA

-412 data tables. In response to the energy shortfall in California, in 2001 the California State legislature authorized the CDWR, using its undamaged borrowing capability, to enter the wholesale markets on behalf of the California retail customers effective on January 17, 2001 and for the period endingDecember 31, 2002. Their 2001 revenue collected was $5,501,000,000 with purchased power costs of $12,055,000,000. Their 2002 revenue collected was $4,210,000,000 with purchased power costs of $3,827,749,811. Their 2003 revenue collected was $4,627,000,000 with purchased power costs of $4,732,000,000. The California Public Utility Commission was required by statute to establish the procedures for retail revenue recovery mechanisms for their purchase power costs in the future

.
SensitiveData:The nonutility data collected on Schedule 9 “Electric Generating Plant Statistics” for “Cost of Plant” and “Production Expenses,” are considered business sensitive.

.



## Form EIA

-423 (Replaced in 2008 by the Form EIA

-923) The Form EIA

-423, “Monthly Cost and Quality ofFuels for Electric Plants Report,” collected the cost and quality of fossil fuels delivered to nonutility plants to produce electricity. These plants included independent power producers (including those facilities that formerly reported on the FERC Form 423) and commercial and industrial combined heat and power (CHP) producers whose total fossil

-fueled nameplate generating capacity was 50 or more megawatts (MW). (CHP plants are sometimes referred to as co

-generators. They produce heat, such as steam foruse in a manufacturing process, along with electricity)

. Instrument andDesign History:The Form EIA

-4232

### was implemented in January 2002 to collect monthly cost and quality data for fossil fuel receipts from owners or operators of nonutility electricityU.S. EnergyInformation Administration | Electric Power Annual



### generating plants. It was terminated on January 1, 2008, and replaced by the Form EIA

-923, "Power Plant Operations Report."

Issues within Historical Data Series:Natural gas values do not include blast furnace gas or other gas

.
SensitiveData:Plant fuel cost data collected on the survey are considered business sensitive. State

-and national

-level aggregations are published if sufficient data are available to avoid disclosure of individual company and plant level costs

. 

## FERC Form 423 (Replaced in 2008by Form EIA

-923) The FERC Form 423, “Monthly Report of Cost and Quality of Fuels for Electric Plants,” was administered by FERC. The data were downloaded from the Commission’s website into an EIA database. The Form was filed by approximately 600 regulatedplants. To meet the criteria for filing, a plant must have had a total steam turbine electric generating capacity and/or combined

-cycle (gas turbine with associated steam turbine) generating capacity of 50 or more megawatts. Only fuel delivered for use insteam

turbine and combined

-cycle units was reported. Fuel received for use in gas

-turbine or internal

combustion units that was not associated with a combined

-cycle operation was not reported. The FERC Form 423 was replacedafter 2007 by the Form EIA

-923

. Instrument andDesignHistory:On July 7, 1972, the FPC issued Order Number 453 enacting the New Code of Federal Regulations, Section 141.61, creating the FPC Form 423. Originally, the form was used to collect data only on fossil steam plants, but was amended in 1974 to include data on internal

combustion and combustion

-turbine units. When DOE was formed in 1977, most of FPC became FERC. The FERC Form 423 replaced the FPC Form 423 in January 1983. The FERC Form 423 dropped stand

alone combustion turbines. In addition, the generator nameplate capacity threshold was changed from 25 megawatts to 50 megawatts. This reduction in coverage eliminated approximately 50 utilities and 250 plants. All historical FPC Form 423 data in this publication were revised to reflect the new generator

-nameplate

-capacity threshold of 50 or more megawatts reported on the FERC Form 423. In January 1991, the collection of data on the FERC Form 423 was extended to include combined cycle units. Historical data have not been revised toinclude these units. On January 1, 2008, EIA assumed responsibility for collection of these data and both the utility and nonutility plants began to report their cost and quality of fuels information on Schedule 2 of Form EIA

-923, "Power Plant OperationsReport."

. Issues within Historical Data Series:These data were collected by FERC for regulatory rather than statistical and publication purposes. EIA did not attempt to resolve any late filing issues in the FERC Form 423 survey. The data were quality reviewed by EIA and when possible quality issues were resolved with FERC.
Natural gas values for 2001 forward do not include blast furnace gas or other gas.
Due to the estimation procedure described below in the discussion of the Form EIA

-923, 2003 and later data cannot be directly compared to previous years’ data

.
SensitiveData:Data collected on FERC Form 423 are not business sensitive.U.S. EnergyInformation Administration | Electric Power Annual



## Form EIA

-767 (Replaced by Forms EIA

-860 and EIA

-923) The Form EIA

-767 was used to collect data annually on plant operations and equipment design, including boiler, generator, cooling system, air pollution control equipment, and stack characteristics. Data were collected from a mandatory restricted

-universe census of all electric power plants with a total existing or planned organic

-fueled or combustible renewable steam

-electric generator nameplate rating of 10 or more megawatts. The entire form was filed by approximately 800 power plants with a nameplate capacity of 100 or more megawatts. An additional 600 power plants with a nameplate capacity under 100 megawatts submitted information only on fuel consumption and quality, boiler and generator configuration, and nitrogen oxides, mercury, particulate matter, and sulfur dioxide controls.
Instrument and Design History:The Federal Energy Administration Act of 1974 (Public Law 93

-275) defines the legislative authority to collect these data. The predecessor form, FPC

-67, “Steam

-Electric Plant Air and Water Quality Control Data,” was used to collect data from 1969 to 1980,when the form number was changed to Form EIA

-767. In 1982, the form was completely redesigned and re

-titled Form EIA

-767, “Steam

-Electric Plant Operation and Design Report.” In 1986, the respondent universe of 700 plants was increased to 900 plants to include plants with nameplate capacity from 10 megawatts to 100 megawatts. In 2002, the respondent universe was increased by almost 1,370 plants with the addition of nonutility plants.
Collection of data via the form was suspended for the 2006 data year. Starting with the collection of 2007 calendar year data, most of the Form EIA

-767 information is now collected on either the revised Form EIA

-860, "Annual Electric Generator Report" or the new Form EIA

-923, "Power Plant Operations Report."

Estimation of EIA

-767 Data:No estimation of Form EIA

-767 data was performed. Normally the survey had no non

-response.
Issues within Historical Data Series:As noted above, no data were collected for calendar year 2006

.
Sensitive Data:Latitude and longitude datacollected on the Form EIA

-767 were considered business sensitive.


## Form EIA

-826 The Form EIA 826, “Monthly Electric Utility Sales and Revenues with State Distributions Report,” is a monthly collection of data from a sample of approximately 520 of the largest electric utilities (primarily investor and publicly owned) as well as a census of energy service providers with retail sales in deregulated States. Form EIA

-861(see below), with approximately 3,300 respondents, serves as a frame from which the Form 826sample is drawn. Based on this sample, a model is used to estimate for the entire universe of U.S. electric utilitieson a monthly basis

. Instrument anddesignhistory:The collection of electric power sales data and related information began in the early 1940’s and was established as FPC Form 5 by FPC Order 141 in 1947. In 1980, the report was revised with only selected income items remaining and became the FERC Form 5. The Form EIA 826, “Electric Utility Company Monthly Statement,” replaced the FERCForm 5 in January 1983. In January 1987, the “Electric Utility Company Monthly Statement” was changed to the “Monthly ElectricU.S. EnergyInformation Administration | Electric Power Annual



### Utility Sales and Revenue Report with State Distributions.” The title was changed again in January 2002 to “Monthly Electric Utility Sales and Revenues with State Distributions Report” to become consistent with other EIA report titles. The Form EIA 826 was revised in January 1990, and some data elements were eliminated.
In 1993, EIA for the first time used a model sample for theForm EIA 826. A stratified random sample, employing auxiliary data, was used for each of the four previous years. The sample for the Form EIA 826 was designed to obtain estimates of electricity sales and average retail price of electricity at the State level by end use sector.
Starting with data for January 2001, the restructuring of the electric power industry was taken into account by forming three schedules on the Form EIA

-826. Schedule 1, Part A is for full service utilities that operate as in the past. Schedule 1, Part B is for electric service providers only, and Schedule 1, Part C is for those utilities providing distribution service for those on Schedule 1, Part B. In addition, Schedule 1 Part D is for those retail energy providers or power marketers that provide bundled service. Also, the Form EIA

-826 frame was modified to include all investor

-owned electric utilities and a sample of companies from other ownership classes. A new method of estimation was implemented at this same time. (See ElectricPowerMonthly,April 2001, p.1.)

With the October 2004 issue of the ElectricPowerMonthly (EPM),EIA published for the first time preliminary electricity sales data for the Transportation Sector. These data are for electricity delivered to and consumed by local, regional, and metropolitan transportation systems. The data being published for the first time in the October EPM included July 2004 data as well as year

-to

-date. EIA’s efforts to develop these new data have identified anomalies in severalStates and the District of Columbia. Some of these anomalies are caused by issues such as: 1) Some respondents have classified themselves as outside the realm of the survey. The Form EIA

-826 collects retail data from those respondents providing electricity and other services to the ultimate end users. EIA has experienced specific situations where, although the respondents’ customers are the ultimate end users, particular end users qualify under wholesale rate schedules. 2) The Form EIA

-826 is a cutoffsample and not intended to be a census.

Dataprocessing anddatasystemediting:Monthly Form EIA

-826 submission is available via an Internet Data Collection (IDC) system. The completed data are due to EIA by the last calendar day of the month followingthe reporting month. Nonrespondents are contacted to obtain the data. The data are edited and additional checks are completed. Following verification, imputation is run, and tables and text of the aggregated data are produced for inclusion in the EPM.
Imputation:Regression prediction, or imputation, is done for entities not in the monthly sample and for any nonrespondents. Regressor data for Schedule 1, Part A is the average monthly sales or revenue from the most recent finalized data from survey Form EIA

-861. Beginning with January 2008 data and the finalized 2007 data, the regressor data for Schedule 1 Parts B and C is the prior month’s data.

Formulas andmethodologies:The Form EIA 826 data are collected by end

-use sector (residential, commercial, industrial, and transportation) and State. Form EIA 861(see below)data are used as the frame from which the sample is selected and in some instances also as regressor data. Updates are made to the frame to reflect mergers that affect data processing.U.S. EnergyInformation Administration | Electric Power Annual



### With the revised definitions for the commercial and industrial sectors to include all data previously reported as ‘other’ data except transportation, and a separate transportation sector, all responses that would formerly have been reported under the “other” sector are now to be reported under one of the sectors that currently exist. This means there is probably a lower correlation, in general, between, say, commercial Form EIA

-826 data for 2004 and commercial Form EIA

-861 data for 2003 than there was between commercial Form EIA

-826 data for 2003 and commercial Form EIA

-861 data for 2002 or earlier years, although commercial and industrial definitions have always been somewhat nebulous due to power companies not having complete information on all customers. Data submitted for January 2004 represent the first time respondents were to provide data specifically for the transportation end

-use sector.
During 2003 transportation data were collected annually through Form EIA

-861. Beginning in 2004 the transportation data were collected on a monthly basis via Form EIA

-826. In order to develop an estimate of the monthly transportation data for 2003, values for both retail sales of electricity to ultimate customers and revenue from retail sales of electricity to ultimate customers were estimated using the 2004 monthly profile for the sales and revenues from the data collected via Form EIA

-826. All monthly non

-transportation data for 2003 (i.e. street lighting, etc.), which were previously reported in the “other” end

-use sector on the Form EIA

-826 have been prorated into the Commercial and Industrial end

-use sectors based on the 2003 Form EIA

-861 profile.
A monthly distribution factor was developed for the monthly data collected in 2004 (for the months of January through November). The transportation sales and revenues for December 2004 were assumed to be equivalent to the transportation sales and revenuesfor November 2004. The monthly distribution factors for January through November were applied to the annual values for transportation sales and revenues collected via Form EIA

-861 to develop corresponding 2003 monthly values. The eleven month estimatedtotals from January through November 2003 were subtracted from the annual values obtained from Form EIA

-861 in order to obtain the December 2003 values.

Data from the Form EIA

-826 are used to determine estimates by sector at the State, Census division, and national level. State level sales and revenues estimates are first calculated. Then the ratio of revenue divided by sales is calculated to estimate retail price of electricity at the State level. The estimates are accumulated separately to produce theCensus division and U.S. level estimates3



### . Some electric utilities provide service in more than one State. To facilitate the estimation, the State service area is actually used as the sampling unit. For each State served by each utility, there is a utility State part, or “State service area.” This approach allows for an explicit calculation of estimates for sales, revenue, and average retail price of electricity by end use sector at State, Census division, and national level. Estimation procedures includeimputation to account for nonresponse. Non

-sampling error must also be considered. The non

-sampling error is not estimated directly, although attempts are made to minimize the non

-sampling error.
Average retail price of electricity represents the cost perunit of electricity sold and is calculated by dividing retail electric revenue by the corresponding sales of electricity. The average retail price of electricity is calculated for all consumers and for each end

-use sector.U.S. EnergyInformation Administration | Electric Power Annual



### The electric revenue used to calculate the average retail price of electricity is the operating revenue reported by the electric utility. Operating revenue includes energy charges, demand charges, consumer service charges, environmental surcharges, fuel adjustments, and other miscellaneous charges. Electric utility operating revenues also include State and Federal income taxes and taxes other than income taxes paid by the utility.
The average retail price of electricity reported in this publication by sector represents a weighted

average of consumer revenue and sales within sectors and across sectors for all consumers, and does not reflect the per kWh rate charged by the electric utility to the individual consumers. Electric utilities typically employ a number of rate schedules within a single sector. These alternative rate schedules reflect the varying consumption levels and patterns of consumers and their associated impact on the costs to the electric utility for providing electrical service.

Adjusting monthly data to annual data:As a final adjustment based on our most complete data, use is made of final Form EIA

-861 data, when available. The annual totals for Form EIA

-826 data by State and end

-use sector are compared to the corresponding Form EIA

-861 values for sales and revenue. The ratio of these two values in each case is then used to adjust each corresponding monthly value.

Sensitivedata:Most of the data collected on the Form EIA

-826 are not considered business sensitive. However,monthlyrevenue, sales, and customer data collected from energy service providers (Schedule 1, Part B), which do not also provide energy delivery, are considered business sensitive and must adhere to EIA's “Policy on the Disclosure of Individually Identifiable Energy Information in the Possession of the EIA” (45Federal Register 59812 (1980)).


## Form EIA

-860 The Form EIA

-860 is a mandatory annual census of all existing and planned electric generating facilities in the United States with a total generator nameplate capacity of 1 or more megawatts. The survey is used to collect data on existing power plants and 10 year plans for constructing new plants, as well as generating unit additions, modifications, and retirements in existing plants. Data on the survey are collected at the individual generator level. Certain power plant environmental

-related data are collected at the boiler level. These data include environmental equipment design parameters and boiler air emission standards and boiler emission controls.

Instrument and Design History:The Form EIA

-860 was originally implemented in January 1985 to collect plant data on electric utilities as of year

-end 1984. It was preceded by several Federal Power Commission (FPC) forms including the FPC Form 4, Form 12 and 12E,Form 67, and Form 411. In January 1999, the Form EIA

-860 was renamed the Form EIA

-860A and was implemented to collect data as of January 1, 1999.
In 1989, the Form EIA

-867, "Annual Nonutility Power Producer Report," was initiated to collect plant data onunregulated entities with a total generator nameplate capacity of 5 or more megawatts. In 1992, the reporting threshold of the Form EIA

-867 was lowered to include all facilities with a combined nameplate capacity of 1 or more megawatts. Previously, data were collected every 3 years from facilities with a nameplate capacity between 1 and 5 megawatts. In 1998, the Form EIA

-867, was renamed Form EIA

-860B, "Annual Electric Generator Report

–Nonutility." The Form EIA

-860B was a mandatory surveyU.S. EnergyInformation Administration | Electric Power Annual



### of all existingand planned nonutility electric generating facilities in the United States with a total generator nameplate capacity of 1 or more megawatts.
Beginning with data collected for the year 2001, the infrastructure data collected on the Form EIA

-860A and the Form EIA

-860B were combined into the new Form EIA

-860 and the monthly and annual versions of the Form EIA

-906. The Federal Energy Administration Act of 1974 (Public Law 93

-275) defines the legislative authority to collect these data.
Starting with 2007, design parameters data formerly collected on Form EIA

-767 were collected on Form EIA

-860. These include design parameters associated with certain steam

-electric plants’ boilers, cooling systems, flue gas particulate collectors, flue gas desulfurization units, and stacks and flues

. Estimation of EIA

-860 Data:Noimputation was requiredfor EIA

-860 data

. Issues within Historical Data Series Regarding Categorization of Capacity by Business Sector:There are a small number of electric utility CHP plants, as well as a small number of industrial and commercial generating facilities that are not CHP. For the purposes of this report the data for these plants are included, respectively, in the following categories: “Electricity Generators, Electric Utilities,” “Combined Heat and Power, Industrial,” and “Combined Heat and Power, Commercial.”
Some capacity in 2001 through 2004 is classified based on the operating company's classification as an electric utility or an independent power producer. Starting in the EPA 2006, capacity by producer type was determined at the power plant level for 2005 and all subsequent data collections. This change required revisions to the original published 2005 data.
Issues within Historical Data Series Regarding Planned Capacity:Delaysand cancellations may have occurred subsequent to respondent data reporting as of December 31 of the data year.
Issues within Historical Data Series Regarding Capacity by Energy Source:Prior to the EPA 2005, the capacity for generators for which natural gas or petroleum was the most predominant energy source was presented in the following three categories: petroleum only, natural gas only, and dual

-fired. The dual

-fired category, which was EIA’s effort to infer which generators could fuel

-switch between natural gas and fuel oil, included only the capacity of generators for which the most predominant energy source and second most predominant energy source were reported as natural gas or petroleum. Beginning in 2005, capacity is assigned to energy source based solely on the most predominant (primary) energy source reported for a generator. The “dual

-fired” category was eliminated. Separately, summaries of capacity associated with generators with fuel

-switching capability are presented for 2005 and later years. These summaries are based on data collected from new questions added to the Form EIA

-860 survey that directly address the ability of generators to switch fuels and co

-fire fuels.
In the EPA 2005, certain petroleum

-fired capacity was misclassifiedas natural gas

-fired capacity for 1995

–2003. This was corrected in the EPA 2006. Corrections were noted as revised data.U.S. EnergyInformation Administration | Electric Power Annual



### Prime Movers:The Form EIA

-860 sometimes represents a generator’s prime mover by using the abbreviationsin the table below.

Prime Mover CodePrime Mover Description BA Energy Storage, Battery CE Energy Storage, Compressed Air CP Energy Storage, Concentrated Solar Power FW Energy Storage, Flywheel PS Energy Storage, Reversible Hydraulic Turbine (Pumped Storage) ES EnergyStorage, Other
ST Steam Turbine, including nuclear, geothermal and solar steam

(does not include combined cycle) GT Combustion (Gas) Turbine (includingjet engine design) IC Internal Combustion Engine (diesel, piston, reciprocating) CA Combined CycleSteam Part CT Combined Cycle Combustion Turbine Part CS Combined Cycle Single Shaft CC Combined Cycle Total Unit HA Hydrokinetic, Axial Flow Turbine HB Hydrokinetic, Wave Buoy HK Hydrokinetic, Other
HY HydroelectricTurbine (includingturbines associated with

delivery of water by pipeline)

BT Turbines Used in a Binary Cycle (including those used for

geothermal applications) PV Photovoltaic WT Wind Turbine, Onshore WS Wind Turbine, Offshore FC Fuel Cell OT OtherU.S. EnergyInformation Administration | Electric Power Annual



### Energy Sources:The Form EIA

-860 sometimes representstheenergy sourcesassociated with generators byusing the abbreviations and/or groupingsin the tablebelow.

Energy Source Grouping Energy Source CodeEnergy Source Description

Coal ANT Anthracite Coal BIT Bituminous Coal LIG Lignite Coal SUB Subbituminous Coal SGC Coal

-Derived Synthesis Gas
WC Waste/Other Coal (including anthracite culm, bituminous gob,

fine coal, lignite waste, waste coal)

Petroleum Products DFO DistillateFuel Oil (including diesel, No. 1, No. 2, and No. 4 fuel oils) JF Jet Fuel KER Kerosene PC Petroleum Coke PG Gaseous Propane
RFO Residual Fuel Oil (including No. 5, and No. 6 fuel oils, and bunker

C fuel oil) SG Synthesis Gas from PetroleumCoke

WO Waste/Other Oil (including crude oil, liquid butane, liquid

propane, naphtha, oil waste, re

-refined motor oil, sludge oil, tar oil, or other petroleum

-based liquid wastes)

Natural Gas and Other Gases BFG Blast Furnace Gas NG Natural Gas OG Other Gas Nuclear NUC Nuclear (including Uranium, Plutonium, and Thorium)

Hydroelectric Conventional WAT (Prime Mover = HY)Water at a Conventional

Hydroelectric Turbine, and water used in Wave Buoy Hydrokinetic Technology, Current HydrokineticTechnology, and Tidal Hydrokinetic Technology Hydroelectric Pumped Storage WAT (Prime Mover = PS)Pumping Energy for Reversible (Pumped Storage) Hydroelectric

Turbine

Wood and Wood

-Derived Fuels WDS Wood/Wood Waste Solids (including paper pellets,railroad ties, utility poles, wood chips, bark, and wood waste solids) WDL Wood Waste Liquids (excluding Black Liquor but including red

liquor, sludge wood, spent sulfite liquor, and other wood

-based liquids) BLQ Black Liquor

Other Biomass AB Agricultural By

-Products MSW Municipal Solid Waste OBG Other Biomass Gas (including digester gas, methane, and other

biomass gases) OBL Other Biomass Liquids OBS Other Biomass Solids LFG Landfill Gas SLW Sludge Waste
Other Renewable EnergySources SUN Solar (including solar thermal) WND Wind GEO Geothermal

Other Energy Sources PUR Purchased Steam WH Waste heat not directly attributed to a fuel source TDF Tire

-Derived Fuels MWH Electricity used for energy storage OTH OtherU.S. EnergyInformation Administration | Electric Power Annual



### Sensitive Data:The tested heat rate data collected on the Form EIA

-860 are considered business sensitive.


## Form EIA

-861 The Form EIA

-861 is a mandatory annual census of electric power industry participants in the United States.Prior to data year 2012, the survey wasused to collect information on power sales and revenue data from approximately 3,300 respondents. About 3,100 are electric utilities, and the remainders are nontraditional entities such as energy service providers or the unregulated subsidiaries of electric utilities and power marketers.
For data year 2012 and forward,EIA

### modified the frame of the Form EIA

-861,“Annual Electric Power Industry Report,”

### from a census to a sample, andEIA isusing model

-based methods to estimate the sales, revenues, and customer counts by sector and state for those respondents that have been removed from the frame.EIAcreated a new Form EIA

-861S,“Annual Electric Power Industry Report (Short Form),”

### for the respondents that have been removed from the Form EIA

-861 frame. The form collects limited data such as total sales, revenues, and customer counts by state. Transportation Sector:Prior to 2003, sales of electric power for transportation (e.g., city subway systems) were included in the Other Sector, along with sales to customers for public buildings, traffic signals, public street lighting, and sales to irrigation consumers. Beginning with the 2003 data collection, sales to the Transportation Sector were collected separately. The balance of the Other Sector was reclassified as Commercial Sector sales except that sales to irrigation customers, where separately identified, were reclassified to the Industrial Sector.

On the Form EIA

-861, the Transportation Sector is defined as electrified rail, primarily urban transit, light rail, automated guideway, and other rail systems whose primary propulsive energy source is electricity. Electricity sales to Transportation Sector consumers whose primary propulsive energysource is not electricity (i.e., gasoline, diesel fuel, etc.) are not included.
Benchmark statistics were reviewed from outside surveys, most notably the U.S. Department of Transportation (DOT) Federal Transit Administration’s National Transportation Database, a source previously used by EIA to estimate electricity transportation consumption. The DOT survey indicated the State and City locations of expected respondents. The Form EIA

-861 survey methodology assumed that sales, revenue, and customer counts associated with these mass transit systems would be provided by the incumbent utilities in these areas, relying on information drawn routinely from rate schedules and classifications designed to serve the sector separately and distinctly. In 2010, 64 respondents reported transportation data in 28 States.

Data Reconciliation:The ElectricPowerAnnualreports total retail sales volumes (megawatthours) and customer counts in States with deregulated markets as the sum of bundled sales reported by full

-service providers and delivery reported by transmission and distribution utilities. ERUS has concluded that the retail sales data reported by delivery utilities are more reliable than data reported by power marketers and Energy Service Providers (ESPs).U.S. EnergyInformation Administration | Electric Power Annual



### The reporting methodology change uses sales volumes and a customer count reported by distribution utilities, and modifies only an incremental revenue value, representing revenue associated with misreported sales assumed to be attributable to the ESPs that were under

-represented in the survey frame.
Instrument and Design History:The Form EIA

-861 was implemented in January 1985 for collection of data as of year

-end 1984. The Federal Energy Administration Act of 1974 (Public Law 93

-275) defines the legislative authority to collect these data.
Average Retail Price of Electricity: This value represents theaveragecost per unit of electricity sold and is calculated by dividing retail electric revenue by the corresponding sales of electricity. The average retail price of electricity is calculated for all consumers and for each end

-use sector. The electric revenue used to calculate the average retail price of electricity is the operating revenue reported by the electric power industry participant. Operating revenue includes energy charges, demand charges, consumer service charges, environmental surcharges, fuel adjustments, and other miscellaneous charges. Electric power industry participant operating revenues also include ratepayer reimbursements for State and Federal income taxes and other taxes paid by the utility.
This computed average retail price of electricity reported in this publication by is a weighted average of consumer revenue and sales and does not equal the per kWh rate charged by the electric power industry participant to the individual consumers. Electric utilities typically employ a number of rate schedules within a single sector. These alternative rate schedules reflect the varying consumption levels and patterns of consumers and their associated impact on the costs of the electric power industry participant for providing electrical service.

Issues within Historical Data Series:Changes from year to year in consumer counts, sales and revenues, particularly involving the commercial and industrial consumer sectors, may result from respondent implementation of changes in the definitions of consumers, and reclassifications. Utilities and energy service providers may classify commercial and industrial customers based on either NAICS codes or demands or usage falling within specified limits by rate schedule. The number of ultimate customers is an average of the number of customers at the close of each month. Also see the discussion of the Transportation Sector, above.

Net

-Metering:This section was expanded in 2011. Previously, customer count by sector was the only datacollected andpublished. In 2010, the EIA

-861 started collecting the capacity of the net

-metered installations by sector and technology. The technology types are: photovoltaic (PV), wind andother.

Demand

-Side Management (DSM):Prior to 2011, DSM data was separated into two categories, large and small utilities. Some tables contained data for just large utilities and others contained both categories, published separately. Starting in 2011, there is no longer a division in the data. All tables now include all DSM data fromutilities;this change is also reflected in the historical data.U.S. EnergyInformation Administration | Electric Power Annual



### Starting in 2011, a new category of respondents were added to the EIA

-861, non

-utility DSM administrators:Efficiency Maine Trust, Energy trust of Oregon, Focus on Energy, NYSERDA and Vermont Energy Investment Corporation.
The following definitions are supplied to assist in interpreting DSM data. Utility costs reflect the total cash expenditures for the year, in nominal dollars, that used to support DSM programs.

Actual Peak Load Reductionis the actual reduction in annual peak load achieved by all program participants during the reporting year, at the time of annual peak load, as opposed to the installed peakload reduction capability (potential peak load reduction). Actual peak load reduction is reported by large utilities only.

Energy Savingsis the change in aggregate electricity use (measured in megawatthours) for consumers that participate in a utility DSM program. These savings represent changes at the consumer's meter (i.e., exclude transmission and distribution effects) and reflect only activities that are undertaken specifically in response to utility

administered programs, including those activities implemented by third parties under contract to the utility.

Large Utilitiesare those electric utilities with annual sales to ultimate customers or sales for resale greater than or equal to 150 million kilowatthours in 1998

-2009 and, for years prior, the threshold was set at 120 million kilowatthours.

Potential Peak Load Reductionis the potential peak load reduction as a result of load management.
Advanced Metering:New in 2011,Automated Meter Reading (AMR) and Advanced Metering Infrastructure (AMI), including historical data back to 2007. From 2007

-2009, the count by sector isfor number of customers, for2010

-2011, the count is the actual number of meters. For example; if an industrial customerhad 12 meters, in2007

-2009the count would have been 1, in2010

-2011, the count would be 12.

Sensitive Data:None.


## Forms EIA

-906 and EIA

-920 (Replaced in 2008 by Form EIA

-923) The Form EIA

-906 was used to collect plant

-level data on generation, fuel consumption, stocks, and fuel heat content, from electric utilities and nonutilities. Data were collected monthly from a model

-based sample of approximately 1,700 utility and nonutility electric power plants. The form was also used to collect these statistics from another 2,667 plants (i.e., all other generators 1 MWor greater) on an annual basis. The form was ended after the 2007 data collection andreplaced by the Form EIA

-923.
Instrument and Design History:The Bureau of Census and the U.S. Geological Survey collected, compiled, and published data on the electricpower industry prior to 1936. After 1936, the FPC assumed all data collection and publication responsibilities for the electric power industry and implemented the Form FPC

-4. The Federal Power Act, Section 311 and 312, and FPC Order 141 defined the legislative authority to collect power production data. The Form EIA

-759 replaced the Form FPC

-4 in January 1982. In 1996, the Form EIA

-900 was initiated to collect sales for resale data from unregulated entities. In 1998, the Form EIA

-900 was modified to collectsales for resale, gross generation, and sales to end userU.S. EnergyInformation Administration | Electric Power Annual



### data. In 1999, the form was modified to collect net generation, consumption, and ending stock data. In 2000, the form was modified to include data on the production of useful thermal output (typically process steam) by combined heat and power (CHP) plants.
In January 2001, Form EIA

-906 superseded Forms EIA

-759 and EIA

-900. In January 2004, Form EIA

-920 superseded Form EIA

-906 for those plants defined as CHP plants; all other plants that generated electricity continued to report on Form EIA

-906. The Federal Energy Administration Act of 1974 (Public Law 93 275) defines the legislative authority to collect these data. In January 2008, the Form EIA

-923 superseded this form.

Issues within Historical DataSeries:A relatively small number electric commercial

-and industrial

-only plants are, for the purposes of this report, are included in the CHP data categories. The small number of electric utility plants that are CHP units are reported together with other utility plants. No information on the production of useful thermal output (UTO) or fuel consumption for UTO was collected or estimated for the electric utility CHP plants.

Sensitive Data:The only business sensitive data element collected on the FormsEIA

-906 and EIA

-920 was fuel stocks at the end of the reporting period.


## Form EIA

-923 Form EIA

-923, “Power Plant Operations Report,” is used to collect information on receipts and cost of fossil fuels, fuel stocks, generation, consumption of fuel for generation, nonutility source and disposition ofelectricity, combustionby

-product collection and disposal,and cooling systems,as well as operational data for flue gas desulfurization, particulates, and nitrous oxide controls

.Data are collected from a monthly sample of approximately 1,900 plants, which includes a census of nuclear and pumped

-storage hydroelectric plants. The plants in the monthly sample report their receipts, cost and stocks of fossil fuels, electric power generation, and the total consumption of fuels for both electric power generation and,at combined heat and power (CHP)plants, useful thermal output. At the end of the year, the monthly respondents report their annual source and disposition of electric power (nonutilities only),operationaldatafor air emissions controls and cooling systems, and the collection and disposal of combustion by

-productson the Form EIA

-923 Supplemental Form (Schedules 6, 7, and 8A to 8F). Approximately4,200plants, representing all generators not included in the monthly sample and with a nameplate capacity of 1 MW or more, reportapplicabledata on the entire form annually. In addition to electric power generating plants, respondents include fuel storage terminals without generating capacity that receive shipments of fossil fuel for eventual use in electric power generation. The monthly data are due by the last day of the month following the reporting period.
Receipts of fossil fuels, fuel cost and quality information, and fuel stocks at the end of the reporting period are all reported at the plant level. Fuel receipts and costs are collected from plants with a nameplate capacity of 50 MW or more and burn fossil fuels. Plants that burn organic fuels and have a steam turbine capacity of at least 10 megawatts report consumption at the boiler level and generation at the generator level for each month, regardless of whether the plant reports in the monthly sample or reports annually. For all other plants, consumption is reported at the prime

-mover level and generation is reported at the prime

-mover level or, for noncombustible sources (e.g., wind, nuclear), at the prime

-U.S. EnergyInformation Administration | Electric Power Annual



### mover and energy source levels (including generating units for nuclear only). The source anddisposition of electricity are reported annually for nonutilities at the plant level, as is revenue from sales for resale. Operational datafor air emissions equipmentare collected annually from facilities that have a steam turbine capacity of at least10 megawatts, and operational data on coolingsystemsanddata on the collection and disposal of combustion by

-products are collectedfromfacilities that have a steam turbine capacity of at least 100 megawatts

. Instrument and Design History:See discussion of predecessor forms (EIA

-906,

-920,

-767, and

-423, and FERC Form 423).
Imputation:For data collected monthly, regression prediction, or imputation, is done for all missing data including non

-sampled units and any non

-respondents. For data collected annually, imputation is performed for non

-respondents. For gross generation and total fuel consumption, multiple regression is used for imputation (see discussion, above).Approximately 0.02 percent of the national total generation for is imputed, although this will vary by State and energy source.
When gross generation is reported and net generation is not available,or vice versa,net orgross generation is estimated by using a fixed ratioof netto gross generation by prime

-mover typeand installed emissions equipment

.These ratios are:

For stocks, a linear combination of the prior month’s ending stocks value and the current month’s consumption and receipts values is used.
Receipts ofFossilFuels:Receipts data, including cost and quality of fuels, are collected at the plant level from selected electric generating plants and fossil

-fuel storage terminals in the United States.Power plantsinclude independent power producers, electric utilities, and commercial and industrial CHPU.S. EnergyInformation Administration | Electric Power Annual



### facilities witha totalfossil

-fueled nameplate capacityof50 megawatts or more. The data on cost and quality of fuel shipmentsare usedto produce aggregates and weighted averages for each fuel type at the State, Census division, and U.S. levels

. The units for receipts are: 1) coal and petroleum coke, tons and million Btu per ton; 2) petroleum, barrels and million Btu per barrel.; and gases,thousand cubic feet (Mcf) and million Btu per thousand cubic feet.

Net and GrossGenerationand Fuel Consumptionand Stocks:Generation dataare collected in megawatthours from all power plants with a sum of nameplate capacity at least 1 MW. The fuels consumed are collected in tons (solids), barrels (liquids) and thousand cubic feet (gases).Fuels are grouped into coal, petroleum liquids, petroleum coke, natural gas, other gases, and other miscellaneous fuels. Energy consumption is not collected for nuclear, wind, solar, geothermal or other plants that do not burn fuels. For information on fuel groupings, see the instructions to the Form EIA

-923 at http://www.eia.gov/survey/form/eia_923/instructions.pdf

.Combustion By

-Product Collection and Disposal:Data are collected in thousand tons. Associated financial data for by

-products (O&M and capital expenses and revenue) are collected in thousand dollars.

Air EmissionsEquipment:Operationalefficiencies and emission rates arecollected forflue gas desulfurization, particulate matter, and nitrous oxide control equipment for steam

-electric unitswith at least 10 MW nameplate capacity.
Cooling Systems:Operational data on water use is collected from steam

-electric plants, including nuclear plants, with at least 100 MW nameplate capacity.
Methodology to Estimate Biogenic and Non

-biogenicMunicipal Solid Waste:4

### Municipal Solid Waste (MSW) consumption for generation of electric power is split into its biogenic and non

-biogenic components beginning with 2001 data by the following methodology:
The tonnage of MSWconsumedis reported on the Form EIA

-923. The composition of MSW and categorization of the components were obtained from the Environmental Protection Agency (EPA) publication,Municipal Solid Waste in the United States: 2005 Facts and Figures. The Btu contents of the components of MSW were obtained from various sources.
In 2011, the components of MSW as a percentage of the total were updated. The updated values were applied to final 2011 data andtopreliminary 2012 and 2013 data. Although updated component percentages for 2006 through 2010 were available, historical EIA data series for consumption of MSW and net generation were not revised for 2005 to 2010. The tables below are the percentages applied to the EIA data for each year.
The potential quantities of combustible MSW discards (which include all MSW material available for combustion with energy recovery, discards to landfill, and other disposal) were multiplied by their respective Btu contents. The EPA

-based categories of MSW were then classified into renewable and

non
-renewable groupings. From this, EIA calculated how much of the energy potentially consumed fromU.S. EnergyInformation Administration | Electric Power Annual



### MSW was attributed to biogenic components and how much to non

-biogenic components (see Table 1 and 2, below).5



### These values are used to allocateconsumption of municipal solid waste andnet generation published in the Electric Power Monthly tables.The tons of biogenic and non

-biogenic components were estimated with the assumption that glass and metals were removed prior to combustion. The average Btu/ton for the biogenic and non

-biogenic components is estimated by dividing the total Btu consumption by the total tons. Published net generation attributed to biogenic MSW and non

-biogenic MSW is classified under Other Renewables and Other, respectively

. Table 1. Btu consumption for biogenic and non

-biogenic municipal solid waste (percent)

20012002200320042005200620072008200920102011 Biogenic5756555556565656565651
Non

biogenic434445454444444444449



### Table 2. Tonnage consumption forbiogenic and non

-biogenic municipal solid waste (percent)

20012002200320042005200620072008200920102011 Biogenic7777767675757575757564
Non

biogenic2323242425252525252536



### UsefulThermalOutput(UTO):With the implementation of the Form EIA

-923, “Power Plant Operations Report,” in 2008,combined heat and power (CHP) plantswere required to report total fuel consumed and electric power generation. Beginning with preliminary January 2008 data, EIA estimated the allocation of the total fuel consumed at CHP plants between electric power generation and UTO.
The estimated allocation methodology is summarized in the following paragraphs. The methodology was retroactively applied to 2004

-2007 data. Prior to 2004, UTO was collected on the Form EIA

-906 and an estimated allocation of fuel for electricity was not necessary.
First, an efficiency factor is determined for each plant and prime mover type. Based on data for electric power generation and UTO collected in 2003 (on Form EIA

-906, “Power Plant Report”), efficiency was calculated for each prime mover type at a plant. The efficiency factor is the total output in Btu, including electric power and UTO, divided by the total input in Btu. Electric power is converted to Btu at 3,412 Btu per kilowatthour.
Second, to calculate the amount of fuel for electric power, the gross generation in Btu is divided by the efficiency factor. The fuel for UTO is the difference between the total fuel reported and the fuel for

electric power generation. UTO is calculated by multiplying the fuel for UTO by the efficiency factor.U.S. EnergyInformation Administration | Electric Power Annual



### In addition, if the total fuel reported is less than the estimated fuel for electric power generation, then the fuel for electric power generation is equal to the total fuel consumed, and the UTO will be zero.
Issues within Historical Data Series for Receipts and Cost and Quality of Fossil Fuels:Values for receipts of natural gas for 2001 forward do not include blast furnace gas or other gas.

Historical data collected on FERC Form 423 and published by EIA have been reviewed for consistency between volumes and prices and for their consistency over time. However, these data were collected by FERC for regulatory rather than statistical and publication purposes. EIA did not attempt to resolve any late filing issues in the FERC Form 423 data. In 2003, EIA introduced a procedure to estimate for late

or non
-responding entities that were required to report on the FERC Form 423. Due to the introduction of this procedure, 2003 and later data cannot be directly compared to previous years’ data.
Prior to 2008, regulated plants reported receipts data on the FERC Form 423. These plants, along with unregulated plants, now report receipts data on Schedule 2 of FormEIA

-923. Because FERC issued waivers to Form 423 filing requirements to some plants who met certain criteria, and because not all types of generators were required to report (only steam turbines and combined cycle units reported), a significant number ofplants either did not submit fossil fuel receipts data or submitted only a portion of their fossil fuel receipts. Since Form EIA

-923 does not have exemptions based on generator type, or reporting waivers, receipts data from 2008 and later cannot be directly compared to previous years’ data for the regulated sector. Also beginning with January 2008 data, tables for total receipts included imputed quantities for plants with capacity one megawatt or more, to be consistent with other electric power data. Previous published receipts data were from plants at or over a 50 megawatt threshold, which was a legacy of their original collection as information for a regulatory agency, not as a survey to provide more meaningful estimates of totals for statistical purposes. Totals appeared to become smaller as more electric production came from unregulated plants, until the Form EIA

-423 was created to help fill that gap. As a further improvement, estimation of all receipts for the universe normally depicted in the ElectricPowerAnnual (i.e., one megawatt and above), with associated relative standard errors, provides a more complete assessment of the market.
Issues within Historical Data Series for Generation and Consumption:Beginning in 2008, a new method of allocating fuel consumption between electric power generation and UTO was implemented (see above). This new methodology evenly distributes a CHP plant’s losses between the two output products (electric power and UTO). In the historical data, UTO was consistently assumed to be 80 percent efficient and all other losses at the plant were allocated to electric power. This change causes the fuel for electric power to be lower while the fuel for UTO is higher as both are given the same efficiency. This results in the appearance of an increase in efficiency of production of electric power between periods.

Sensitive Data:The total delivered cost of fuel delivered to nonutilities, the commodity cost of fossil fuels, and fuel stocks are considered business sensitive. 

## Average Capacity Factors This section describes the methodology for calculating capacity factors by fuel and technology type for operating electric power plants.Capacity factor is a measure (expressed as a percent) of how often anU.S. EnergyInformation Administration | Electric Power Annual



### electric generator operatesovera specific period of time,using a ratio of the actual output to the maximum possible output over that time period.
The capacity factor calculation only includes operating electric generators in the Electric Power Sector (sectors 1, 2 and 3) using the net generation reported on the Form EIA

-923 and the net summer capacity reported on the Form EIA

-860.The capacity factor for a particular fuel/technology type is given by: ∑ ∑ 

### Where x represents generators of that fuel/technology combination and m represents the period of time (month or year).Generation and capacity are specific to a generator, and the generator is categorized by its primary fuel type as reported on the EIA

-860.All generation from that generator is included, regardless of other fuels consumed.Available time is also specific to the generator in order to account for differing online and retirement dates.Therefore, these published capacity factors will differ from a simple calculation using annual generation and capacity totals from the appropriate tables in this publication

. 

## Air Emissions This section describes the methodology for calculating estimated emissions of carbon dioxide (CO2

### ) from electric generating plants for 1989 throughthe present, as well as the estimated emissions of sulfur dioxide (SO2

### ) and nitrogen oxides(NOx

### ) from electric generating plants for 2001 throughthe present

. For a description of the methodology used for other years, see the technical notes to the EPA 2003. Methodology Overview:Initial estimates of uncontrolledSO2

### and NOx emissions for allplants are made by applying an emissions factor to fuel consumption data collected by EIA on the Form EIA

-923. An emission factor is the average quantity of a pollutant released from a power plant when a unit of fuel is burned, assuming no use of pollution control equipment. The basic relationship is: Emissions = Quantity of Fuel Consumed x Emission Factor Quantity is defined in physical units (e.g., tons of solid fuels, million cubic feet of gaseous fuels, and thousands of barrels of liquid fuels) fordetermining NOx

### andSO2

### emissions. As discussed below, physical quantities are converted to millions of Btus for calculating CO2

### emissions. For some fuels, the calculation ofSO2

### emissions requires including in the formula the sulfur content of the fuelmeasured in percentage of weight. Examples include coal and fuel oil. In these cases the formula is: Emissions = Quantity of Fuel Consumed x Emission Factor x Sulfur Content The fuels that require the percent sulfur as part of the emissions calculationare indicated in Table A.1., which lists theSO2

### emission factors used for this report.

In the case ofSO2

### andNOx

### emissions, the factor applied to a fuel can also vary with the combustion system: a steam

-producing boiler, a combustion turbine, or an internal combustion engine. In the case of boilers,NOx

### emissions can also vary with the firing configuration of a boiler and whether or not the boiler is a wet

-bottom or dry

-bottom design.6

### These distinctions are shown in Tables A

.1

.and A

.2.U.S. EnergyInformation Administration | Electric Power Annual



### ForSO2

### andNOx

### ,the initial estimate of uncontrolled emissions is reduced to account for the plant’s operational pollution control equipment, when data on control equipment are available from the historical Form EIA

-767 survey (i.e., data for the years 2005 and earlier) and the EIA

-860 and EIA

-923 surveys for the years 2007 through 2010. A special case for removal ofSO2

### is the fluidized bed boiler, in which the sulfur removal process is integral with the operation of the boiler. TheSO2

### emission factors shown inTable A

.1

.for fluidized bed boilers already account for 90 percent removal ofSO2

### since, in effect, the plant has no uncontrolled emissions of this pollutant. AlthoughSO2

### andNOx

### emission estimates are made for all plants, in many cases the estimated emissions can be replaced with actual emissions data collected by the U.S. Environmental Protection Agency’s (U.S. EPA’s) Continuous Emissions Monitoring System (CEMS) program. (CEMS data forCO2

### are incomplete and are not used in this report.) The CEMS dataaccount for the bulk ofSO2

### andNOx 

### emissions from the electric power industry. For those plants for which CEMS data are available, the EIA estimates ofSO2

### andNOx

### emissions are employed for the limited purpose of allocating emissions by fuel, since theCEMS data itself do not provide a detailed breakdown of plant emissions by fuel. For plants for which CEMS data are unavailable, the EIA

-computed values are used as the final emissions estimates. There are a number of reasons why the historical data areperiodically revised. These include data revisions, revisions in emission and technology factors, and changes in methodology. For instance, the 2008 ElectricPowerAnnual reportfeatures a revision in historicCO2

### values. This revision occurred due to achange in the accepted methodology regarding adjustments made for the percentage combustion of fuels. The emissions estimation methodologies are described in more detail below.

CO2

### Emissions:CO2

### emissions are estimated using the information on fuel consumption in physical units and the heat content of fuel collected on the Form EIA

-923 and predecessors. Heat content information is used to convert physical units to millions of Btu (MMBtu) consumed. To estimateCO2

### emissions, the fuel

-specific emissionfactor from Table A

.3

.is multiplied by the fuel consumption in MMBtu. The estimation procedure calculates uncontrolledCO2

### emissions.CO2

### control technologies are currently in the early stages of research and there are no commercial systems installed. Therefore, no estimates of controlledCO2

### emissions are made.

SO2

### andNOx

### Emissions:To comply with environmental regulations controllingSO2

### emissions, many coal

-fired generating plants have installed flue gas desulfurization (FGD) units. Similarly,NOx

### control regulations require many fossil

-fueled plants to install low

-NOx

### burners, selective catalytic reduction systems, or other technologies to reduce emissions. It is common for power plants to employ two or even threeNOx

### control technologies; accordingly, theNOx

### emissions estimation approach accounts for the combined effect of the equipment (Table A

.4

.). However, control equipment information is available only for plants that reported on the Form EIA

-923 and for historical data from the Form EIA

767. The Form EIA

-860, EIA

-923, and the historical EIA

-767 surveys are limited to plants with boilers fired by combustible fuels7

### with a minimum generating capacity of 10 megawatts (nameplate). Pollution control equipment data are unavailable from EIA sources for plants that did not report on the historical EIA

-767 survey, or the Forms EIA

-860 and EIA

-923. The following method is used to estimateSO2

### andNOx

### emissions:U.S. EnergyInformation Administration | Electric Power Annual 

### For steam electric plants, uncontrolled emissions are estimated using the emission factors shown in Tables A

.1

.and A

.2

.as well as reported data on fuel consumption, sulfur content, and boiler firing configuration. Controlled emissions are then determined when pollution control equipment is present. Although information on control equipment was not collected in 2006, updates for new installations during this period were made based on EPA data. Beginning in 2007, these data were collected on the Forms EIA

-860 and EIA

-923. ForSO2

### , the reported efficiency of the plant’s FGD units is usedto convert uncontrolled to controlled emission estimates. ForNOx

### ,the reduction percentages shown in Table A

.4

.are applied to the uncontrolled estimates.

For plants and prime movers not reported on the historical Form EIA

-767 survey or Forms EIA

-860 and EIA

-923, uncontrolled emissions are estimated using the Table A

.1

. and Table A

.2

.emission factors and the following data and assumptions:

oFuel consumption is taken from the Form EIA

-923 and predecessors.

oThe sulfur content of the fuel is estimated from fuel receipts for the plant reported on the Form EIA

-923. When plant

-specific sulfur content data are unavailable, the national average sulfur content for the fuel, computed from the Form EIA

-923 is appliedto the plant.

oAs noted earlier, the emission factor for plants with boilers depends in part on the type of combustion system, including whether a boiler is wet

-bottom or dry

bottom, and the boiler firing configuration. However, this boiler information is unavailable for steam electric plants that did not report on the historical Forms EIA

-767 or EIA

-860. For these cases, the plant is assumed to have a dry

-bottom,

non
-cyclone boiler using a firing method that falls into the “All Other” category shown onTable A

.1.8 

### For the plants that did not report on the historical Form EIA

-767 or EIA

-860, pollution control equipment data are unavailable and the uncontrolled estimates are not reduced.

If actual emissions ofSO2

### orNOx

### are reported in the EPA’s CEMS data, the EIA estimates are replaced with the CEMS values, using the EIA estimates to allocate the CEMS plant

level data by fuel. If CEMS data are unavailable, the EIA estimates are used as the final values.


## ConversionFactors for Propane, Petroleum Coke, and Synthesis Gases. The quantityconversionfor petroleum coke is5 barrels (of 42 U.S. gallons each) per short ton (2,000 pounds), propane is 1.53 thousand cubic feet per barrel, coal

-derived synthesis gas is 98.06thousand cubic feet per ton, andpetroleum coke

-derived synthesis gas is 107.31thousand cubic feet per ton. 

## Relative Standard Error The relative standard error (RSE) statistic, usually given as a percent, describes the magnitude of sampling error that might reasonably be incurred. TheRSE is the square root of the estimated variance, divided by the variable of interest. The variable of interest may be the ratio of two variables, or a single variable.U.S. EnergyInformation Administration | Electric Power Annual



### The sampling error may be less than the non

-sampling error. In fact, large RSE estimates found in preliminary work with these data have often indicated non

-sampling errors, which were then identified and corrected. Non

-sampling errors may be attributed to many sources, including response errors, definitional difficulties, differences in theinterpretation of questions, mistakes in recording or coding data obtained, and other errors of collection, response, or coverage. These non

-sampling errors also occur in complete censuses. Using the Central Limit Theorem, which applies to sums and meanssuch as are applicable here, there is approximately a 68 percent chance that the true total or mean is within one RSE of the estimated total. Note that reported RSEs are always estimates, themselves, and are usually, as here, reported as percents. As an example, suppose that a net generation from coal value is estimated to be 1,507 total million kilowatthours with an estimated RSE of 4.9 percent. This means that, ignoring any non

-sampling error, there is approximately a 68 percent chance that the true million kilowatthour value is within approximately 4.9 percent of 1,507 million kilowatthours (that is, between 1,433 and 1,581 million kilowatthours). Also under the Central Limit Theorem, there is approximately a 95 percent chance that the true mean or totalis within 2 RSEs of the estimated mean or total. Note that there are times when a model may not apply, such as in the case of a substantial reclassification of sales, when the relationship between the variable of interest and the regressor data does nothold. In such a case, the new information represents only itself, and such numbers are added to model results when estimating totals. Further, there are times when sample data may be known to be in error, or are not reported. Such cases are treated as if they were never part of the model

-based sample, and values are imputed. 

## Business Classification Nonutility power producers consist of entities that own or operate electric generating units but are not subject to direct economic regulation of rates, such as by state utility commissions. Nonutility power producers do not have a designated franchised service area. In addition to entities whose primary business is the production and sale of electric power, entities with other primary business classifications
can and do sell electric power. These can consist of, for example, manufacturing facilities and paper mills.
The EIA, in the ElectricPowerAnnualand other data products, classifies nonutility power producers into the following categories:

Electric Utility(Sector 1):All regulated plants with a primary purpose ofselling electricity in the public markets (NAICS = 22)

.
Independent Power Producers (Sector 2):All non

-regulated plants with a primary purpose of electric power generationand a primary purpose of selling electricity in the public markets(NAICS = 22) with no ability to cogenerate heat and power.

Electric Power, Combined Heat and Power (Sector 3):All non

-regulated plants with a primary purpose of electric power generationand a primary purpose ofselling electricity in the public markets(NAICS = 22) with the ability to cogenerate heat and power.

Commercial, Non

-Combined Heat and Power (Sector 4):All plants with a commercial primary purpose with no ability to cogenerate heat and power

.U.S. EnergyInformation Administration | Electric Power Annual 

### Commercial, Combined Heat and Power (Sector 5):All plants with a commercial primary purpose with the ability to cogenerate heat and power

.
Industrial, Non

-Combined Heat and Power (Sector 6):All plants with an industrial primary purpose with no ability to cogenerate heat and power

.
Industrial, Combined Heat and Power (Sector 7):All plants with an industrial primary purpose with the ability to cogenerate heat and power

. The following is a list of theNorth American Industry Classification System (NAICS)classifications used by EIA

.
Agriculture,Forestry, Fishing and Hunting 111 Crop Production 112 Animal Production 113 Forestry and Logging 114 Fishing, Hunting and Trapping 115 Support Activities for Agriculture and Forestry

Mining, Quarrying, and Oil andGas Extraction 211 Oil and Gas Extraction 2121 Coal Mining 2122 Metal Ore Mining 2123 Nonmetallic Mineral Mining and Quarrying

Utilities

22 Electric Power Generation, Transmission and Distribution (other than 2212, 2213, 22131, 22132 or 22133) 2212 Natural Gas Distribution 22131 Water Supply and Irrigation Systems 22132 Sewage Treatment Facilities 22133 Steam and Air

-Conditioning Supply

Manufacturing 311 Food Manufacturing 312 Beverage and Tobacco Product Manufacturing 313 TextileMills (Fiber, Yarn, Thread, Fabric, and Textiles) 314 Textile Product Mills 315 Apparel Manufacturing 316 Leather and Allied Product Manufacturing 321 Wood Product Manufacturing 322 Paper Manufacturing (other than 322122 or 32213) 322122 NewsprintMills 32213 Paperboard Mills 323 Printing and Related Support Activities 324 Petroleum and Coal Products Manufacturing(other than 32411) 32411 Petroleum Refineries 325 Chemical Manufacturing(other than 32511, 32512, 325193, 325188, 3252 325211, 3253or 325311) 32511 Petrochemical Manufacturing 32512 Industrial Gas Manufacturing 325193 Ethyl Alcohol Manufacturing (including Ethanol) 325188 Industrial Inorganic Chemicals 3252 Resin, Synthetic Rubber, and Artificial Synthetic Fibers and FilamentsManufacturing (other thanU.S. EnergyInformation Administration | Electric Power Annual 325211) 325211 Plastics Material and Resin Manufacturing 3253 Pesticide, Fertilizer, and Other Agricultural Chemical Manufacturing (other than 325311) 325311 Nitrogenous Fertilizer Manufacturing 326 Plastics and RubberProducts Manufacturing 327 Nonmetallic Mineral Product Manufacturing(other than 32731) 32731 Cement Manufacturing 331 Primary Metal Manufacturing(other than 331111 or 331312) 331111 Iron and Steel Mills 331312 Primary Aluminum Production 332 Fabricated Metal Product Manufacturing 333 Machinery Manufacturing 334 Computer and Electronic Product Manufacturing 335 Electrical Equipment, Appliance, and Component Manufacturing 336 Transportation Equipment Manufacturing 337 Furniture and RelatedProduct Manufacturing 339 Miscellaneous Manufacturing

421 Wholesale Trade

441 Retail Trade

Transportation and Warehousing 481 Air Transportation 482 Rail Transportation 483 Water Transportation 484 Truck Transportation 485 Transit andGround Passenger Transportation 486 Pipeline Transportation 487 Scenic and Sightseeing Transportation 488 Support Activities for Transportation (other than 4881, 4882, 4883 or 4884) 4881 Support Activities for Air Transportation (including Airports) 4882 Support Activities for Rail Transportation (including Rail Stations) 4883 Support Activities for Water Transportation (including Marinas) 4884 Support Activities for Road Transportation 491 Postal Service 492 Couriers and Messengers 493 Warehousing and Storage

Information 511 Publishing Industries (except Internet) 512 Motion Picture and Sound Recording Industries 515 Broadcasting (except Internet) 517 Telecommunications 518 Data Processing, Hosting, and Related Services 519 Other Information Services

521 Finance and Insurance

53 Real Estate and Rental and Leasing (including Convention Centers and Office Buildings)

541 Professional, Scientific, and Technical Services

55 Management of Companies and EnterprisesU.S. EnergyInformation Administration | Electric Power Annual Administrative and Support and Waste Management and Remediation Services 561 Administrative and Support Services 562 Waste Management and Remediation Services (other than 562212 or 562213) 562212 Solid Waste Landfill 562213 Solid Waste Combustorsand Incinerators

611 Educational Services

Health Care and Social Assistance 621 Ambulatory Health Care Services 622 Hospitals 623 Nursing and Residential Care Facilities 624 Social Assistance

Arts, Entertainment, and Recreation 711 Performing Arts, Spectator Sports, and Related Industries 712 Museums, Historical Sites, and Similar Institutions 713 Amusement, Gambling, and Recreation Industries

Accommodation and Food Services 721 Accommodation 722 Food Services and DrinkingPlaces
Other Services (except Public Administration) 811 Repair and Maintenance 812 Personal and Laundry Services 813 Religious, Grantmaking, Civic, Professional, and Similar Organizations 814 Private Households

92 Public Administration (otherthan 921, 922, 92214 or 928) 921 Executive, Legislative, and Other General Government Services 922 Justice, Public Order and Safety Activities (other than 92214) 92214 Correctional Facilities 928 National Security and International Affairs (includingMilitary Bases)

1The basic technique employed is described in the paper “Model

-Based Sampling and Inference,” on the EIA website. Additional references can be found on the InterStat website (http://interstat.statjournals.net/). See the following sources: Knaub, J.R., Jr. (1999a), “Using Prediction

-Oriented Software for Survey Estimation,” InterStat, August 1999, http://interstat.statjournals.net/; Knaub, J.R. Jr. (1999b), “Model

-Based Sampling, Inference and Imputation,” EIA web site: http://www.eia.gov/cneaf/electricity/forms/eiawebme.pdf;Knaub, J.R., Jr. (2005), “Classical Ratio Estimator,” InterStat, October 2005,http://interstat.statjournals.net/; Knaub, J.R., Jr. (2007a), “Cutoff Sampling and Inference,” InterStat, April 2007, http://interstat.statjournals.net/; Knaub, J.R., Jr. (2008), “Cutoff Sampling.” Definition in Encyclopedia of Survey Research Methods, Editor: Paul J. Lavrakas, Sage, to appear; Knaub, J.R., Jr. (2000), “Using Prediction

-Oriented Software for Survey Estimation

-Part II: Ratios of Totals,” InterStat, June 2000,http://interstat.statjournals.net/; Knaub, J.R., Jr.(2001), “Using Prediction

-Oriented Software for Survey Estimation

-Part III: Full

-Scale Study of Variance and Bias,” InterStat, June 2001, http://interstat.statjournals.net/

.

2Due to the restructuring of the electric power industry, many plants which had historically submitted this information for utility plants on the FERC Form 423 (see subsequent section) were being transferred to the nonutility sector. As a result, alarge percentage of fossil fuel receipts were no longer being reported. The Form EIA

-423 was implemented to fill this void and to capture the data associated with existing nonregulated power producers. Its design closely follows that of the FERC Form 423.U.S. EnergyInformation Administration | Electric Power Annual 3Thebasic technique employed is described in the paper “Model

-Based Sampling and Inference,” on the EIA website. Additional references can be found on the InterStat website (http://interstat.statjournals.net/). See the following sources: Knaub, J.R., Jr. (1999a), “Using Prediction

-Oriented Software for Survey Estimation,” InterStat, August 1999, http://interstat.statjournals.net/; Knaub, J.R. Jr. (1999b), “Model

-Based Sampling, Inference and Imputation,” EIAweb site: http://www.eia.gov/cneaf/electricity/forms/eiawebme.pdf;Knaub, J.R., Jr. (2005), “Classical Ratio Estimator,” InterStat, October 2005,http://interstat.statjournals.net/; Knaub, J.R., Jr. (2007a), “Cutoff Sampling and Inference,” InterStat, April 2007, http://interstat.statjournals.net/; Knaub, J.R., Jr. (2008), “Cutoff Sampling.” Definition in Encyclopedia of Survey Research Methods, Editor: Paul J. Lavrakas, Sage, to appear; Knaub, J.R., Jr. (2000), “Using Prediction

-Oriented Software for Survey Estimation

-Part II: Ratios of Totals,” InterStat, June 2000,http://interstat.statjournals.net/; Knaub, J.R., Jr.(2001), “Using Prediction

-Oriented Software for Survey Estimation

-Part III: Full

-Scale Study of Variance and Bias,” InterStat, June 2001, http://interstat.statjournals.net/

.

4See the following sources: Bahillo, A. et al. Journal of Energy Resources Technology, “NOx and N2O Emissions During Fluidized Bed Combustion of Leather Wastes.” Volume 128, Issue 2, June 2006. pp. 99

-103; U.S. Energy Information Administration. Renewable Energy Annual 2004. “Average Heat Content of Selected Biomass Fuels.” Washington, DC, 2005; Penn State Agricultural College Agricultural and Biological Engineering and Council for SolidWaste Solutions. Garth, J. and Kowal, P. Resource Recovery, Turning Waste into Energy, University Park, PA, 1993; Utah State University Recycling Center Frequently Asked Questions

5Biogenic components include newsprint, paper, containers and packaging,leather, textiles, yard trimmings, food wastes, and wood. Non

-biogenic components include plastics, rubber and other miscellaneous non

-biogenic waste.

6A boiler’s firing configuration relates to the arrangement of the fuel burners in the boiler, and whether the boiler is of conventional or cyclonedesign. Wet

-and dry

-bottom boilers use different methods to collect a portion of the ash that results from burning coal. For information on wet

-and dry

-bottom boilers, see the EIA Glossary at http://www.eia.gov/glossary/index.html

.Additional information on wet

-and dry

-bottom boilers and on other aspects of boiler design and operation, including the differences between conventional and cyclone designs, can be found in Babcock and Wilcox,Steam: Its Generation and Use, 41stEdition, 2005.

7Boilers that rely entirely on waste heat to create steam, including the heat recovery portion of most combined cycle plants, did not report on the historical Form EIA

-767 or EIA

-923.

8The “All Other” firing configuration category includes, for example, arch firing and concentric firing. For a full list of firing method options for reporting on the historical Form EIA

-767, see the form instructions, page xi, at http://www.eia.gov/survey/form/eia_767/instructions_form.pdf

.Fuel EIA Fuel CodeSource and Tables (As Appropriate) Emissions Units Lbs = Pounds MMCF = Million Cubic Feet

MG = Thousand GallonsCyclone BoilerFluidized Bed Boiler Opposed Firing BoilerSpreader Stoker BoilerTangential Boiler All Other Boiler TypesCombustion Turbine Internal Combustion Engine Agricultural ByproductsABSource: 1 Lbs per ton 0.08 0.01 0.08 0.08 0.08 0.08 N/A N/A

Blast Furnace Gas BFGSources: 1 (including footnote 7 within source); 2, Table 1.4-2 (including footnote d within source) Lbs per MMCF 0.60 0.06 0.60 0.60 0.60 0.60 0.60 0.60 Bituminous Coal* BITSource: 2, Table 1.1-3 Lbs per ton 38.00 3.80 38.00 38.00 38.00 38.00 N/A N/A Black Liquor BLQSource: 1 Lbs per ton ** 7.00 0.70 7.00 7.00 7.00 7.00 N/A N/A Distillate Fuel Oil* DFOSource: 2, Table 3.1-2a, 3.4-1 & 1.3-1 Lbs per MG 157.00 15.70 157.00 157.00 157.00 157.00 140.00 140.00

Jet Fuel* JFAssumed to have emissions similar to DFO. Lbs per MG 157.00 15.70 157.00 157.00 157.00 157.00 140.00 140.00

Kerosene* KERAssumed to have emissions similar to DFO. Lbs per MG 157.00 15.70 157.00 157.00 157.00 157.00 140.00 140.00

Landfill Gas LFGSources: 1 (including footnote 7 within source); 2, Table 1.4-2 (including footnote d within source) Lbs per MMCF 0.60 0.06 0.60 0.60 0.60 0.60 0.60 0.60 Lignite Coal* LIGSource: 2, Table 1.7-1 Lbs per ton 30.00 3.00 30.00 30.00 30.00 30.00 N/A N/A Municipal Solid WasteMSWSource: 1 Lbs per ton 1.70 0.17 1.70 1.70 1.70 1.70 N/A N/A

Natural Gas NGSources: 1 (including footnote 7 within source); 2, Table 1.4-2 (including footnote d within source) Lbs per MMCF 0.60 0.06 0.60 0.60 0.60 0.60 0.60 0.60

Other Biomass Gas OBGSources: 1 (including footnote 7 within source); 2, Table 1.4-2 (including footnote d within source) Lbs per MMCF 0.60 0.06 0.60 0.60 0.60 0.60 0.60 0.60
Other Biomass Liquids*OBLSource: 1 (including footnotes 3 and 16 within source) Lbs per MG 157.00 15.70 157.00 157.00 157.00 157.00 140.00 140.00

Other Biomass SolidsOBSSource: 1 (including footnote 11 within source) Lbs per ton 0.23 0.02 0.23 0.23 0.23 0.23 N/A N/A

Other Gases OGSource: 1 (including footnote 7 within source) Lbs per MMCF 0.60 0.06 0.60 0.60 0.60 0.60 0.60 0.60

Other OTHAssumed to have emissions similar to Natural Gas. Lbs per MMCF 0.60 0.06 0.60 0.60 0.60 0.60 0.60 0.60 Petroleum Coke* PCSource: 1 Lbs per ton 39.00 3.90 39.00 39.00 39.00 39.00 N/A N/A

Propane Gas PGSources: 1 (including footnote 7 within source); 2, Table 1.4-2 (including footnote d within source) Lbs per MMCF 0.60 0.06 0.60 0.60 0.60 0.60 0.60 0.60 Residual Fuel Oil* RFOSource: 2, Table 1.3-1 Lbs per MG 157.00 15.70 157.00 157.00 157.00 157.00 N/A N/A
Synthetic Coal* SCAssumed to have the emissions similar to Bituminous Coal. Lbs per ton 38.00 3.80 38.00 38.00 38.00 38.00 N/A N/A
Sludge Waste SLWSource: 1 (including footnote 11 within source) Lbs per ton ** 2.80 0.28 2.80 2.80 2.80 2.80 N/A N/A Subbituminous Coal*SUBSource: 2, Table 1.1-3 Lbs per ton 35.00 3.50 35.00 38.00 35.00 35.00 N/A N/A

Tire-Derived Fuel* TDFSource: 1 (including footnote 13 within source) Lbs per ton 38.00 3.80 38.00 38.00 38.00 38.00 N/A N/A

Waste Coal* WCSource: 1 (including footnote 20 within source) Lbs per ton 30.00 3.00 30.00 30.00 30.00 30.00 N/A N/A
Wood Waste Liquids*WDLSource: 1 (including footnotes 3 and 16 within source) Lbs per MG 157.00 15.70 157.00 157.00 157.00 157.00 140.00 140.00 Wood Waste Solids WDSSource: 1 Lbs per ton 0.29 0.08 0.29 0.08 0.29 0.29 N/A N/A Waste Oil* WOSource: 2, Table 1.11-2 Lbs per MG 147.00 14.70 147.00 147.00 147.00 147.00 N/A N/A 

### Table A.1. Sulfur Dioxide Uncontrolled Emission Factors Fuel, Code, Source and Emission Units Combustion System Type / Firing Configuration

Notes: * For these fuels, emissions are estimated by multiplying the emissions factor by the physical volume of fuel and the sulfur percentage of the fuel (other fuels do not require the sulfur percentage in the calculation). Note that EIA data do not provide the sulfur content of TDF. The value used (1.56 percent) is from U.S. EPA, Control of Mercury Emissions from Coal-Fired Electric Utility Boilers, April 2002, EPA-600/R-01-109, Table A-11 (available at:http://www.epa.gov/appcdwww/aptb/EPA-600-R-01-109A.pdf). ** Although Sludge Waste and Black Liquor consist substantially of liquids, these fuels are measured and reported to EIA in tons.

Sources: 1. Eastern Research Group, Inc. and E.H. Pechan & Associates, Inc., Documentation for the 2002 Electric Generating Unit National Emissions Inventory, Table 6, September 2004. Prepared for the U.S. Environmental Protection Agency, Emission Factor and Inventory Group (D205-01), Emissions, Monitoring and Analysis Division, Research Triangle Park 2. U.S. Environmental Protection Agency, AP 42, Fifth Edition (Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Sources); available at: http://www.epa.gov/ttn/chief/ap42/Cyclone BoilerFluidized Bed Boiler Spreader Stoker Boiler

Fuel EIA Fuel CodeSource and Tables (As Appropriate) Emissions Units Lbs = Pounds MMCF = Million Cubic Feet

MG = Thousand GallonsDry-Bottom Boilers Dry-Bottom Boilers Dry-Bottom Boilers Wet-Bottom Boilers Dry-Bottom Boilers Agricultural ByproductsABSource: 1 Lbs per ton 1.20 1.20 1.20 N/A 1.20

Blast Furnace Gas BFGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 15.40 15.40 15.40 N/A 15.40 Bituminous Coal BITSource: 2, Table 1.1-3 Lbs per ton 33.00 5.00 12.00 31.00 11.00 Black Liquor BLQSource: 1 Lbs per ton ** 1.50 1.50 1.50 N/A 1.50 Distillate Fuel Oil DFOSource: 2, Tables 3.4-1 & 1.3-1 Lbs per MG 24.00 24.00 24.00 N/A 24.00 Jet Fuel JFSource: 2, Tables 3.1-2a, 3.4-1 & 1.3-1 Lbs per MG 24.00 24.00 24.00 N/A 24.00 Kerosene KERSource: 2, Tables 3.1-2a, 3.4-1 & 1.3-1 Lbs per MG 24.00 24.00 24.00 N/A 24.00

Landfill Gas LFGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 72.44 72.44 72.44 N/A 72.44 Lignite Coal LIGSource: 2, Table 1.7-1 Lbs per ton 15.00 3.60 6.30 N/A 5.80 Municipal Solid WasteMSWSource: 1 Lbs per ton 5.00 5.00 5.00 N/A 5.00

Natural Gas NGSource: 2, Tables 1.4-1, 3.1-1, and 3.4-1 Lbs per MMCF 280.00 280.00 280.00 N/A 280.00

Other Biomass Gas OBGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 112.83 112.83 112.83 N/A 112.83
Other Biomass LiquidsOBLSource: 1 (including footnote 3 within source) Lbs per MG 19.00 19.00 19.00 N/A 19.00

Other Biomass SolidsOBSSource: 1 (including footnote 11 within source) Lbs per ton 2.00 2.00 2.00 N/A 2.00

Other Gases OGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 152.82 152.82 152.82 N/A 152.82

Other OTHAssumed to have emissions similar to Natural Gas. Lbs per MMCF 280.00 280.00 280.00 N/A 280.00

Petroleum Coke PCSource: 1 (including footnote 8 within source) Lbs per ton 21.00 5.00 21.00 N/A 21.00 Propane Gas PGSources: 3; EIA estimates Lbs per MMCF 215.00 215.00 215.00 N/A 215.00 Residual Fuel Oil RFOSource: 2, Table 1.3-1 Lbs per MG 47.00 47.00 47.00 N/A 47.00 Synthetic Coal SCAssumed to have the emissions similar to Bituminous Coal. Lbs per ton 33.00 5.00 12.00 31.00 11.00 Sludge Waste SLWSource: 1 (including footnote 11 within source) Lbs per ton ** 5.00 5.00 5.00 N/A 5.00 Subbituminous Coal SUBSource: 2, Table 1.1-3 Lbs per ton 17.00 5.00 7.40 24.00 8.80

Tire-Derived Fuel TDFSource: 1 (including footnote 13 within source) Lbs per ton 33.00 5.00 12.00 31.00 11.00

Waste Coal WCSource: 1 (including footnote 20 within source) Lbs per ton 15.00 3.60 6.30 N/A 5.80
Wood Waste LiquidsWDLSource: 1 (including footnote 16 within source) Lbs per MG 5.43 5.43 5.43 N/A 5.43 Wood Waste Solids WDSSource: 1 Lbs per ton 2.51 2.00 2.51 N/A 1.50 Waste Oil WOSource: 2, Table 1.11-2 Lbs per MG 19.00 19.00 19.00 N/A 19.00

Combustion Turbine Internal Combustion Engine

Fuel EIA Fuel CodeSource and Tables (As Appropriate) Emissions Units Lbs = Pounds MMCF = Million Cubic Feet

MG = Thousand GallonsDry-Bottom Boilers Wet-Bottom Boilers Dry-Bottom Boilers Wet-Bottom Boilers Dry-Bottom Boilers Dry-Bottom Boilers Agricultural ByproductsABSource: 1 Lbs per ton 1.20 N/A 1.20 N/A N/A N/A

Blast Furnace Gas BFGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 15.40 N/A 15.40 N/A 30.40 256.55 Bituminous Coal BITSource: 2, Table 1.1-3 Lbs per ton 10.00 14.00 12.00 31.00 N/A N/A Black Liquor BLQSource: 1 Lbs per ton ** 1.50 N/A 1.50 N/A N/A N/A Distillate Fuel Oil DFOSource: 2, Tables 3.4-1 & 1.3-1 Lbs per MG 24.00 N/A 24.00 N/A 122.00 443.80 Jet Fuel JFSource: 2, Tables 3.1-2a, 3.4-1 & 1.3-1 Lbs per MG 24.00 N/A 24.00 N/A 118.00 432.00 Kerosene KERSource: 2, Tables 3.1-2a, 3.4-1 & 1.3-1 Lbs per MG 24.00 N/A 24.00 N/A 118.00 432.00

Landfill Gas LFGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 72.44 N/A 72.44 N/A 144.00 1,215.22 Lignite Coal LIGSource: 2, Table 1.7-1 Lbs per ton 7.10 N/A 6.30 N/A N/A N/A Municipal Solid WasteMSWSource: 1 Lbs per ton 5.00 N/A 5.00 N/A N/A N/A

Natural Gas NGSource: 2, Tables 1.4-1, 3.1-1, and 3.4-1 Lbs per MMCF 170.00 N/A 280.00 N/A 328.00 2,768.00

Other Biomass Gas OBGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 112.83 N/A 112.83 N/A 313.60 2,646.48
Other Biomass LiquidsOBLSource: 1 (including footnote 3 within source) Lbs per MG 19.00 N/A 19.00 N/A N/A N/A

Other Biomass SolidsOBSSource: 1 (including footnote 11 within source) Lbs per ton 2.00 N/A 2.00 N/A N/A N/A

Other Gases OGSources: 1 (including footnote 7 within source); EIA estimates Lbs per MMCF 152.82 N/A 152.82 N/A 263.82 2,226.41

Other OTHAssumed to have emissions similar to Natural Gas. Lbs per MMCF 170.00 N/A 280.00 N/A 328.00 2,768.00

Petroleum Coke PCSource: 1 (including footnote 8 within source) Lbs per ton 21.00 N/A 21.00 N/A N/A N/A Propane Gas PGSources: 3; EIA estimates Lbs per MMCF 215.00 N/A 215.00 N/A 330.75 2,791.22 Residual Fuel Oil RFOSource: 2, Table 1.3-1 Lbs per MG 32.00 N/A 47.00 N/A N/A N/A
Synthetic Coal SCAssumed to have the emissions similar to Bituminous Coal. Lbs per ton 10.00 14.00 12.00 31.00 N/A N/A
Sludge Waste SLWSource: 1 (including footnote 11 within source) Lbs per ton ** 5.00 N/A 5.00 N/A N/A N/A Subbituminous Coal SUBSource: 2, Table 1.1-3 Lbs per ton 7.20 N/A 7.40 24.00 N/A N/A

Tire-Derived Fuel TDFSource: 1 (including footnote 13 within source) Lbs per ton 10.00 14.00 12.00 31.00 N/A N/A

Waste Coal WCSource: 1 (including footnote 20 within source) Lbs per ton 7.10 N/A 6.30 N/A N/A N/A
Wood Waste LiquidsWDLSource: 1 (including footnote 16 within source) Lbs per MG 5.43 N/A 5.43 N/A N/A N/A Wood Waste Solids WDSSource: 1 Lbs per ton 2.51 N/A 2.51 N/A N/A N/A Waste Oil WOSource: 2, Table 1.11-2 Lbs per MG 19.00 N/A 19.00 N/A N/A N/A

Notes: ** Although Sludge Waste and Black Liquor consist substantially of liquids, these fuels are measured and reported to EIA in tons.

Sources: 1. Eastern Research Group, Inc. and E.H. Pechan & Associates, Inc., Documentation for the 2002 Electric Generating Unit National Emissions Inventory, Table 6, September 2004. Prepared for the U.S. Environmental Protection Agency, Emission Factor and Inventory Group (D205-01), Emissions, Monitoring and Analysis Division, Research Triangle Park 2. U.S. Environmental Protection Agency, AP 42, Fifth Edition (Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Sources); available at: http://www.epa.gov/ttn/chief/ap42/ 3. U.S. Environmental Protection Agency, Factor Information Retrieval (FIRE) Database, Version 6.25; available at: http://www.epa.gov/ttn/chief/software/fire/index.html 

### Table A.2. Nitrogen Oxides Uncontrolled Emission Factors Fuel, Code, Source and Emission Units Combustion System Type / Firing Configuration

Opposed Firing Boiler

Fuel, Code, Source and Emission Units Combustion System Type / Firing Configuration

Tangential Boiler All Other Boiler TypesFuel EIA Fuel Code Source and Tables (As Appropriate) Factor (Pounds of

CO2 Per Million Btu)*** Bituminous Coal BITSource: 1 205.30000 Distillate Fuel Oil DFOSource: 1 161.38600 Geothermal GEOEstimate from EIA, Office of Integrated Analysis and Forecasting 16.59983 Jet Fuel JFSource: 1 156.25800 Kerosene KERSource: 1 159.53500 Lignite Coal LIGSource: 1 215.40000 Municipal Solid WasteMSWSource: 1 (including footnote 2 within source) 91.90000 Natural Gas NGSource: 1 117.08000 Petroleum Coke PCSource: 1 225.13000 Propane Gas PGSources: 1 139.17800 Residual Fuel Oil RFOSource: 1 173.90600 Synthetic Coal SCAssumed to have the emissions similar to Bituminous Coal. 205.30000 Subbituminous Coal SUBSource: 1 212.70000 Tire-Derived Fuel TDFSource: 1 189.53800 Waste Coal WCAssumed to have emissions similar to Bituminous Coal. 205.30000 Waste Oil WOSource: 2, Table 1.11-3 (assumes typical heat content of 4.4 MMBtus per barrel) 210.00000 

### Table A.3. Carbon Dioxide Uncontrolled Emission Factors

Notes: *** CO2 factors do not vary by combustion system type or boiler firing configuration.

Sources: 1. Energy Information Administration, Office of Integrated Analysis and Forecasting, Voluntary Reporting of Greenhouse Gases Program, Table of Fuel and Energy Source: Codes and Emission Coefficients; available at: http://www.eia.doe.gov/oiaf/1605/coefficients.html 2. U.S. Environmental Protection Agency, AP 42, Fifth Edition (Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Sources); available at: http://www.epa.gov/ttn/chief/ap42/Nitrogen Oxides Control Technology EIA-Code(s)Reduction Factor Advanced Overfire Air AA 30% Alternate Burners BF 20% Flue Gas Recirculation FR 40% Fluidized Bed Combustor CF 20% Fuel Reburning FU 30% Low Excess Air LA 20% Low NOx Burners LN 30% Other (or Unspecified) OT 20% Overfire Air OV 20% Selective Catalytic Reduction SR 70% Selective Catalytic Reduction With Low Nitrogen Oxide Burners SR and LN 90% Selective Noncatalytic Reduction SN 30% Selective Noncatalytic Reduction With Low NOx Burners SN and LN 50% Slagging SC 20% 

### Table A.4. Nitrogen Oxides Control Technology Emissions Reduction Factors

Notes: Starting with 1995 data, reduction factors for Advanced Overfire Air, Low NOx Burners, and Overfire Air were reduced by 10 percent.Unit Equivalent Kilowatt (kW) 1,000 (One Thousand) Watts Megawatt (MW) 1,000,000 (One Million) Watts Gigawatt (GW) 1,000,000,000 (One Billion) Watts Terawatt (TW) 1,000,000,000,000 (One Trillion) Watts
Gigawatt 1,000,000 (One Million) Kilowatts Thousand Gigawatts 1,000,000,000 (One Billion) Kilowatts

Kilowatthours (kWh) 1,000 (One Thousand) Watthours Megawatthours (MWh) 1,000,000 (One Million) Watthours Gigawatthours (GWh) 1,000,000,000 (One Billion) Watthours Terawatthours (TWh) 1,000,000,000,000 (One Trillion) Watthours
Gigawatthours 1,000,000 (One Million) Kilowatthours Thousand Gigawatthours 1,000,000,000(One Billion Kilowatthours

U.S. Dollar 1,000 (One Thousand) Mills U.S. Cent 10 (Ten) Mills

Barrel of Oil 42 Gallons 

### Table A.5. Unit of Measure Equivalents

Source: U.S. Energy Information Administration

### U.S. Energy Information Administration | Electric Power Annual