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Alaska Electric Power Statistics (with Alaska Energy Balance) 11-2003
Alaska Electric Power Statistics (with Alaska Energy Balance) 1960-2001 Prepared by Institute of Social and Economic Research University of Alaska Anchorage Prepared for Alaska Energy Authority Reguiatory Commission cf Alaska Denali Commission November, 2003 Institute of Social and Economic Research University of Alaska Anchorage ' 4500 Diplomacy Drive Anchorage, Alaska 99508 Alaska Electric Power Statistics (with Alaska Energy Balance) 1960-2001 Prepared by Institute of Social and Economic Research University of Alaska Anchorage Prepared for Alaska Energy Authority Regulatory Commission of Alaska Denali Commission November, 2003 Institute of Social and Economic Research University of Alaska Anchorage * 4500 Diplomacy Drive Anchorage, Alaska 99508 ALASKA ELECTRIC POWER STATISTICS TABLE OF CONTENTS INTRODUCTION SECTION 1. ELECTRIC POWER STATISTICS Part 1. SUMMARY TABLES Table 1. Utility Summary Data Part 2. ELECTRIC UTILITIES INSTALLED CAPACITY Table 2.1a Installed Capacity by Prime Mover by Plant Table 2.1b Installed Capacity by Prime Mover (Percent Distribution) DISPOSITION Table 2.2 Net Generation and Total Disposition (MWH) NET GENERATION Table 2.3a Net Generation by Prime Mover Table 2.3b Net Generation by Fuel Type and Fuel Use Table 2.3c Net Generation, Fuel Use, and Fuel Cost by Plant REVENUES AND CUSTOMERS Table 2.4a Utility Sales, Revenue, and Customers Table 2.4b Average Annual Energy Use and Cost Table 2.4c Pro Forma Monthly Residential Electric Bills Part 3. ALASKA INDUSTRIAL ELECTRICITY STATISTICS Table 3.1 Installed Capacity Table 3.2 Net Generation 19 22 28 36 42 48 55 61 62 Part 4. NATIONAL DEFENSE ELECTRICITY STATISTICS Table 4.1 Table 4.2 Installed Capacity Net Generation Part 5. ELECTRIC UTILITY HISTORICAL TABLES Table 5.1 Table 5.2 Table 5.3 Table 5.4 Table 5.5 Table 5.6 Utility Installed Capacity by Prime Mover Utility Installed Capacity by Region . Utility Net Generation by Fuel Utility Net Generation by Region Utility Sales, Revenue, and Customers Average Annual Energy Use and Cost SECTION 2. ALASKA ENERGY BALANCE APPENDICES a-oaocm Utility List (name, abbrev, location, region, type, regulatory status, PCE) Map of Electric Power Regions Description of Hydroelectric facilities Description of Railbelt Region Data sources for Electric Power Statistics Federal Forms Data Sources for Energy Balance 63 64 65 66 67 68 69 70 72 A-1 B-1 C-1 D-1 E-1 F-1 G-1 ELECTRIC POWER STATISTICS wal ALASKA ELECTRIC POWER STATISTICS INTRODUCTION Prior to 1985, the federal Alaska Power Administration published the Alaska Electric Power Statistics. Then, the Alaska Energy Authority (formerly the Alaska Power Authority) began gathering statistical data and publishing this annual report. In 1988, the Alaska Electric Power Statistics report became a combined effort between the Alaska Systems Coordinating Council and the Alaska Energy Authority. Beginning in 1993, the report became a joint effort between the Alaska Systems Coordinating Council and the Department of Community and Regional Affairs, Division of Energy. After the 1995 no further reports were published until this year. This twenty-second edition of the Alaska Electric Power Statistics has been prepared by the Institute of Social and Economic Research of the University of Alaska Anchorage with funding provided by the Alaska Energy Authority, the Regulatory Commission of Alaska, and the Denali Commission. The report this year has a new look for a number of reasons. First, information on utility, industry, and military electricity capacity, generation, and other characteristics was gathered primarily from reports filed.with the US Department of Energy and made available on their website. This was supplemented by data collected by the Power Cost Equalization Program and a limited number of direct contacts with electric power producers in the state. Consequently some information contained in prior reports does not appear this year. Information on service interruptions, typical monthly residential bills, and work in progress is not reported this year. At the same time the federal data source has provided some information not collected in prior years. New this year is a table showing the disposition of generation for each utility, including purchases and sales for resale. In addition there is more information on the cost of fuels used in generation. Second, heightened concerns about the security of the physical infrastructure of the nation led to a decision not to include maps showing the transmission grids in the state. Third, a decision was made by the Alaska Energy Authority to drop some of the tables that had not proven to be useful in the past. Thus the tables showing monthly sales have been excluded from the report this year. The data is presented using the same regional definitions as in past reports, but since some utilities have operations that span more than a single region, their combined operations characteristics are also reported. In addition we present a breakdown of operations between the Railbelt utilities, the Power Cost Equalization utilities, and all other. Finally, an entirely new section has been added to the report that describes the production and consumption of all energy in the state. All producers of electricity with installed capacity greater than 1 megawatt are required by law to report their operations to the federal government. A number of utilities in the state fall below that installed capacity threshold. We were successful in contacting most of these very small utilities, but a few did not respond. These non-responding small utilities are listed in the installed capacity table (Table 2.1a) without any data entries. Industrial and military producers of electricity are also required by law to report their operations to the federal government. However, we found that the reporting of those installations with more than 1 megawatt of installed capacity was not complete. We attempted to fill in the blanks for the largest producers, but we undoubtedly missed a few industrial and military producers. In many parts of the state there is no utility electricity available and any activity requiring electricity must self generate. The number of such small installations is quite large and it would be a very expensive task indeed to try to identify and contact each one individually. Consequently the industrial and military tables in this report only include the largest producers, and although they account for the vast majority of non- utility electricity capacity and generation, they underestimate the true totals. In conjunction with the preparation of this annual report, we developed a set of excel files containing all the information reported by Alaska electricity generators to the Energy Information Administration. These master files, including documentation and instructions for developing the data sets in future years, are available to users by contacting either the Alaska Energy Authority or the Institute of Social and Economic Research. Table 1a.-1c. 2001 Utility Summary Data 1a. Installed Capacity (KW) Non-PCE Total Railbelt Non-Railbelt Arctic Northwest. 76,102 0 30,850|___. 106,952 South Central __ 18,931| 1,208,902 124,104| 1,351,937 South East 41,844 0 373,902 415,746 SouthWest [__69,141 0 0 69,141 Yukon 277,000 3,572 315,129 7,485,902) 532,428] 2,258,905 Arctic Northwest South Central ‘South East Arctic Northwest _ ‘Soutt ‘SouthWest Railbelt Cr) ee) 3,530,534 “["57,842|__ 774543 sean — Aas eTT 1c. Sales (MWh) 1b. Net Generation (MWh) Non-Railbelt 203,762 672,422 2,134 954,412 179,162 704,468 167,057 834,519 5,646,290 [52,249] 7,077,392] 1,788] 7,125,429] 357,537| 4,127,392 T5067 5,419,836 1c. Revenue ($000) [Region PCE OT Non-PCE Total Railbelt Non-Railbelt $19,925 ee $7,61 2 s2.oe) $38, oi Yukon $12,680 : $102,604 Totals: $75,418] $461,866| $102,341| $639,625] PCE = Utilities in the Power Cost Equalization Program Railbelt = Utilities interconnected along the Alaska Railroad Table 2.1a 2001 Utility Installed Capacity (KW) by Prime Mover by Plant Arctic Northwest : 106,952 19,300 Oo ° 0 530 o- South Central . _.4,351,937 585,000 222,176 15,000 101,900 ° 310,700 South East 7 415,746 60,800 219,642 135,304 ° oo 0 South West 69,141 0° 1,624 «67,517 ° a) ° Yukon 315,129 192,950 © 68,632 53,500 o 0 ° i i | | | | | i | i | co Ua: eclooococ]e jooeoocn, aB coo coo ooo 585,000 222,176 117,161 oo o o o o 9 10 en) Elec . Total AEGAT” : 72,910 72,910 : o oo oo ). Municipality of TotalMOA 381,303 160,967 44,400 2:236 0 33,000 0 140,700 138 144 Chugach Electric Assn Total CEA _. 613,039 342,073 16,666. = «400.—= 15,000 «= «68,9000 170,000 | 289° 444 Copper Valley Electric Total CVEA 36,029 7,800 12,000 16,229 0 o 0 0 12 4 4250. 015,903. 0 Oo. 5 4 o o 2,300 ° o o o 64 95 0 22,500 60,575 0 o o o 2 23 415,746 60,800_219,642 135,304 0 oo o 3,600 0 o oO 0 ~~~ 28,300___ 25,800 Oe” 10,100 oo 0 a en) a) 0 . 2 it & Power C0 =o, Alaska Power & Telephone “oo 0 Alaska Power & T: ooo ‘Alaska Power & Telephone oO oO Alaska Power & Telephone oO oO o Alaska Power & Telephone — en) ° ‘Alaska Power & T oo o Alaska Power & Telephone a) 0 ‘Alaska Power & Telephone a) 0 oo ° c= 0 ‘Alaska Electric Light & Alaska Power & Telephone. Ketchikan, City of Metlakatla Power & Light. Pelican Utlity District Sitka City of & Borough of Tlingit & Haida Region Electric Authority Wrangell, City of ©! cio cle cools alo ale cleccccolle clo cle! cocococe ecocoooc[) & | andoo’ 8 Ondalo i wi HNL | | yooooooo ecolcoccoe Kugkolewim Electro Coop Se ee ——<—<—<—<—— Middle Kuskokwim Electric Coop, = ——— — idde Kiskakte Essie Gass Nelson Lagoon Elec. Coop._____Nelson. Newtok (Ungusraq Power Co.) Nikolai Light & Power Nushagak Electric Coop Pedro Bay Village Council Perrwille, Vilage of ~ Pilot Point Electrical toons Ung 9,688 1,560 7,970 10 68,632 53,500 eeecccccccccccce] | Peete ae et eeecjeccoccocoosce fe ale ole clo clo cle'ejeio'e'e of rs | USaSngagays eed aes teeuEsbe ty ececcccccccec00c]e i i | hi eocecsocccce | i | | | a i | } leo he | | eon co Oe jeccciocco o ooo °° eclo o 11 Alaska Power & Telephone Alaska Village Electric Coop Golden Valley Elec Assn Total APC Total AVEC Total GVEA 9,131 17,653 30,550 __ 53,500 ‘Special Categories ‘Aiaska Power & Telephone Company Total APC 27,489 State Total Total AVEC 44018 16,059 17,653 Community is community served or name of plant * Wholesale Only Table 2.1.b 2001 Utili Installed Ca 2,258,905 315,129 69/141 aci 612 by Prime Mover 3.045 19.6 21.1 13.8 13 4,351,937 43.3 16.4 8.7 4.4 75 0.0 23.0 126,000 00 CCaEios 37,910 100.0 = 0.0 “00 = 36,000° 100.0 0.0” 00° 00 ~ 007 00° 00° - 616 00 “1000 “007 “00 “00 00 ~ = | 00°32. 00° 00 00 ~ 00.” 185 1000 00 00. 00 00 00 11.6 00 00 00 124 00 628 699 _ 0.0 100.0 0. 00 00 0.0 00 0.0” 00° 0.0 0.0 ~ 45,000 8,927 0.0 100.0 12,000. 0.0. 100.0. 0.0. 0.00.0 _ Copper Valley Elec 15,102 51.6 48.4 0.0 00. Cordova Electric Coop 8100 0.0 00 Oo. Cordova Electric Coop Kodiak Electric Assn (FDPPA) Larsen Bay City of (AEA) _ Matanuska Electric Assn_ 6,553 76 0.0 924 .0 ae 2300” 0.0 00 100.0 00 00 oo 83,075 00 271 729 00 00 - 792,148 357,216 120 | 732 Coco °c0f.00° & 1,149,334 1,087,257 eccooo8looe & 2 g cookclcccco o re Boooood loins * These utilities span more than one region and are excluded from the regional totals. NOTES ON PURCHASED POWER Bradley Lake Eklutna Lake hydro Purchases most of the Bradley Lake power for resale Purchases Solomon Gulch hydro Cooperative member of AEG&T Purchases Terror Lake hydro All power from Chugach Purchases Snettisham hyrdo Purchases Swan Lake hydro Purchases Tyee Lake hydro Power from Alaska Power & Telephone Purchases Tyee Lake hydro Some wind power owned by MEA esg-*7--se7eaA0 ce Generation is shares of Eklutna and Bradley Lake, cooperative member of AEG&T Purchases from Aurora Energy and AML&P,Chugach and Bradley lake shares via Intertie loocc co's jo Table 2.3a 2001 Utility Net Generation by Prime Mover (MWh) 1,724,844 1,361,093 477,814 194,287 462,241 950 1,425,061 5,646,290 ArcticNorthwest _ 80493 0 127,719 880 0 179,162 South Central . _ 83,841 «0 462,241 01,425,061 3,761,085 SouthEast . a ae 1083 864,184 90,261 704,468 South West “ ss i ee er Oe Oy oes 0 167,087 Yukon 580,285 0 9,947 194,287 o 0 0 834,519 127,719 4,114 653 “4,023 “1,944 1,376 1,088 22 214,610 38: 27,808 15 pan Akiachak Electric Co, _ Akiak, City of Akutan City of Alaska Village Electric Coop Alaska Village Electric Coop _ 100.0 0.0” 100.0 0.0 100.0 00 00.0 00 Alaska Village Electric fone Alaska Village Electric Coop Alaska Village Electric Coop ‘Chignik Lake Elec.Uti Egegik Light & Power Co_ False Pass G&K | Igiugig Electric Co L-N-N Electric Coop Inc L-N-N Electric Coop Inc King Cove City of Kipruuk Light Kokhanok Village Koliganek Village Ce a Kuiggiuum Kallugvia (Kwethluk Inc) Kwig Power Co Levelock ‘Electric Lime Village Electric Company _ Mancha Cy of "0.0" 100.0 ~ 0.0 0.0 1000 _ 0.0 Middle Kuskokwim Electric Coop | Middle Kuskokwim Electric Coop. Kuskokwim | Electric Coop _ Perryville, Village of Pilot Point Electrical Pilot Point ~ 16 907 0.0 0.0 7 0000 00 ‘00°00 00 17 315,129 61.2 21.8 17.0 Alaska Power & Telephone sO, 0.0 100.0. 0.0 Alaska Power & Telephone _ 387 0.0. _.. 100.0." 0.0 Alaska Power & Telephone 380° 0.0 0.0 Alaska Power & Telephone 650 0.0 ‘Alaska Power & Telephone. 1850.0 Alaska Power & Telephone “325 0.0 Alaska Power & Telephone _ ATT 0.0 Alaska Power & Telephone _ 1050.0 27” 0.0 Alaska Power & Telephone Alaska Power & Telephone 1,165 0.0. Alaska Power & Telephone 0.0 _ Alaska Village Electric Coop _ 0.0 Alaska Village Electric Coop. Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village El Alaska Village Ele ‘Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Golden Valley Elec Assn_ Golden Valley Elec Assn Gwitchyaa Zhee Utility Co” Hughes Power. & Light Co _ ‘Kotlik City of : ‘Koyukuk (City of) Manley Utility Co Inc __ Paxson Lodge Ruby (City of) Sheldon Point (Nunam qua) 995° 00 _i00.0 ~ 0.0 Data comes from several sources, where 2001 data was not available 2000 or 2002 data was used Community is community served or name of plant * Wholesale Only 18 Arctic Northwest _ South Central South East South Wi Yukon Alaska Power Conpany* Alaska Village Elec Coop, Inc * Table 2.2a 2001 Utility Net Generation and Total Disposition (in MWh) . 188,050 econ) 14, 2,464 = 080, . \812_ 2,309,639 6 9,957 266,882 ~~» 880.893 114 | (7,183 30,484 126551 754 256 2,292 9,184 1,087,257 33. 38 §,808 56,201 66,588 = 837 68,887 “61,342 "| 2.269 - 1,594 3,652 59,942 0 59,942 57,197 0 0 1,432 1,313 o 168,452 156,650 o Ai 2,161 9,630 = 9 0... 507 2,187 Os 0: O oe 1,851 oo 0 a) 0 o Oo. 0 0. won 0 : . o 9 = Pe 787 710 nn Ee eae sae = . 3914 | 0 o 0 747 672 0 0 3,557,379 2,312,459 5,867,496 3,280,812 2,309,839 6 9,957 266,862 493,608 _0 0 0 Sere oO. a ane) ~ 147,041 Ox oF 30,965 aEmeas oes as a or 8 ui 37, “375,076” 2,401,079" = 4,112,183” 0. 5,067 126,759 48,016 81,185 75,648 0 O° 244” 5,293 20 23,473 | 21,847 0 0 0 1,626 Pen. 532,152 532,643 | 476,823 0 O° 4,811 54,009 _ Kodiak Island Borough 131,054 125,347 0 0 || 333 5,374 Kodiak Island 849 a7 0 0 0 372 532,312 0 0. 2,486 36,339 - 653 0 0 Oo. 147 54,940 o 0 0, 5,933, 436 0 0 9 28 19 Alaska Electric Light & Power Co | Elfin Cove, City of Gustavus Electric, Inc Kelchikan, City of ‘Metlakatla Power & Light Pelican Ulility, inc Petersburg, City of Sitka, City & Borough of Tenakee Springs, City of _ Thorne Bay, City of Tlingit & Haida Region El Auth — Wrangell, City of Yakutat Power, inc Akutan, City of - Andreanof Electric Corporation ccoocoocooc ooo coclcoocotcocoo oe “156 “4,184 1,495 235 ~-- 169 - z » 3 coco Bi eooocoofe BBooco Boooowo Eloicielaloicicioicio‘cicicic! osoooo°o Bolo BoNos o8oBo! 3 1,093,033 696,909 173,210 _ 83,841 462,241 1,425,061 3,761,085 17,754 975,711 877,307. 2,034,663 69,801 23,681 133,488 23 1,033 664,184 39,251 21,690 ‘Alaska Electric Light & Power Alaska Electric Light & Power _ ‘Alaska Electric Light & Power (AIDEA) — Alaska Power & Telephone Alaska Power & Telephone _ Aesia Pow & Teoptore Soae se aeeeat” Alaska Power & Telephone Alaska Power & Te Alaska Power & Telephone Elfin Cove Electric Utility _ Gustavus Electric Kaikan (Cy) a Tyee Hydro (FOPPA) Wrangell (City of) Yakutat Power (City of Alaska Electric Li Alaska Power & Telephone __ Ketchikan (City of) _ Tlingit Haida Regional Electric Authority All Locations 24 Nelson Lagoon Electric Cooperative. Nikolai Light & Power ‘38 B88 25 Alaska Power & Telephone Alaska Power & Telephone Alaska Power & Telephone _ Alaska Power & Telephone. ‘Alaska Power & Telephone _ Alaska Power & Telephone 26 Special Categories Alaska Power & Telephone Company Total APC 4455021101 65651 ‘Alaska Village Electric Coop State Total 59779 “Arctic Northwest _ .. 22654 S — South Contra =r - z 108 . Yukon 23060 Railbelt 1,670,859 551,380 1,249 194,287 462,241 O 1,425,061 4,305,077 173210 173,210 27 ‘North Slope Borough ened Table 2.3b 2001 Utility Net Generation by Fuel Type and Fuel Use* lr 32,588,213 Arctic Northwest . _ 50,493 0 0 __ 760,123 i 0 South Central . 2.977.314 | 0. 696,909 30 31,828,000 0 _.0 South East O° _0 | 664,184 2 OO 0 South West 0 0 0 0 Yukon . 7 0 "194,008 0 579,967 — 105,091 ~~ 0 194,008 1,056,579 0 0 214,925 760,123 0 0 Alaska Village Electric Coop . P04 Alaska Village Electric Coop _ 132900 Alaska Village Electric Coop 1,935 Alaska Village Electric Coop 3,544 Alaska Village Electric Coop . _. 25690 . Alaska Village Electric Coop soe OED aes = Alaska Village Electric Coop _ . 3.164 . Alaska Vilage Electric Coop __ SES .. z aS Alaska Village Electric Coop . | 4,597 - Alaska Vilage Electric Coop S : 1499 Alaska Village Electric Coop _ 3,063 Alaska Village Electric Coop . 2,403 Alaska Vilage Electric Coop _ Alaska Village Electric Coop Ipnatchiag Electric Company _ Kobuk Valley Electric Company (8). Kotzebue Electric Assn In Kotzebue Electric Assn In Nome (Joint City of) _ Teller PowerCompany Unalakleet Valley Elec Co. 28 Alaska Vilage Electric Coop Anchorage Mun Light & Power _ Anchorage Mun Light & Power ~ 22,648 146,252 Anchorage Mun Light & Power, Anchorage Mun Light & Power _ ‘Anchorage Mun Light & Power _ Anchorage Mun Light & Power Chenega Bay IRA Village Council Copper Valley Electric (FDPPA) _ 6,875,046 | 4,497,292 © ~ eet 40,773,181 8,752,497 1,712,222” 62,561 29 “Tlingit Haida Regional Electric Authority Hoonah ual arrols) | Alaska Electric Light & Power (AIDEA) | Annex Creek Alaska Electric Light & Power __ “” “Auke Bay . Alaska Electric Light & Power -.. Auke Bay _ Alaska Electric Light & Power Ss Gold Creek 5,605 Alaska Electric Light & Power _ ~ Lemon Creek Alaska Electric Light & Power Lemon Creek Alaska Electric Light & Power «Salmon Creek _ 24,730 ‘Alaska Electric Light & Power - |.” Snettisham, “279,606 Alaska Power & Telephone Black Bear, 22,826 _ Alaska Power & Telephone Coffman Cove 5 : Alaska Power & Telephone __.. Craig, Klawock | 7 aa ‘Alaska Power & Telephone =—=—=~=—~S~S«Goat Lake ~ 18,487 | Alaska Power & Telephone = ..Haines _ Alaska Power & Telephone Hollis weed Alaska Power & Telephone Hydaburg Alaska Power & Telephone oa. Naukati Alaska Power & Telephone _ Skagway Alaska Power & Telephoni _ Skagway Alaska Power & Telephone = Whale Pass Elfin Cove Electric Utility Elfin Cove ‘Gustavus Electric Company ___. Gustavus Ketchikan (City of) ee Beaver Falls 41,248 Ketchikan (City of) _ 22,388 | Ketchikan (City of) _ 13,968 Ketchikan (City of) =e 5 Ketchikan (City of) (FDPPA) 82,888 Metlakatla Power & Light _ mee Metlakatla Power & Light 3,934, ‘Metlakatla Power & Light “14,494” Pelican Utility Co 1,998, Pelican Utlty Co . Petersburg (City of) 13,041 Petersburg (City off. Sitka City of & Borough Sitka City of & Borough 6,685 Sitka City of & Borough | aE = 44,894 Sitka City of & Borough Indian River Tenakee Springs, City of “ Tenakee Springs _ Thorne Bay Public Utility _ Thorne Bay | Tlingit ‘Haida Regional Electric “Authority “ “Angoon Tlingit Haida Regional Electric Authority" Chilkat Valley | Tlingit Haida Regional Electric Authority" Kake Tlingit Haida Regional Electric Authority" Kasaan Tlingit Haida Regional Electric Authority 1.061, * 4,002" ° | 2,581 - MBS ny) 1,374 _ 1,054 _ 979 aici meal BB 714 3,087 393 30 31 re Akiak, City of (a) Akutan Electric Utility Alaska Village Electric Coop Alaska Village Electric C Aniak Light & Power Co In Atmautluak Joint Utilities _ 32 Middle Kuskokwim Elec. Co. eees ) 33 Alaska Power & Telephone _ Alaska Power & Telephone _ Alaska Power & Telephone _ Alaska Power & Telephone Alaska Power & Telephone _ Alaska Power & Telephone _ Alaska Power & Telephone Alaska Power & Telephone _ Alaska Power & Telephone _ Alaska Power & Telephone Alaska Power & Telephone Alaska Village Electric Coop Alaska Village Electric Coop ‘Alaska Village Electric Coop _ Alaska Village Electric Coop _ Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop _ Alaska Vilage Electric Coop Alaska Village Electric Coop _ fee ree ‘Alaska Village Electric Coop, Beaver Joint Utilities Birch Creek Village Elec Util Central Electric, Inc. Chalkyitsik Village Energy System_ Circle Electric Utility a . _ 930 a . ~. 28,168,” 0 579,967 2,362 194,008 1,056,579 Special Categories Alaska Power & Telephone Company Total APC 44,550 36,827 Alaska Village Electric Coop State Total 112,017 _ South Central Lo . aa - Southwest 7 = Yukon Railbelt 2,408 2,977,314 194,008 $51,380 31,828,090 194,008 1,056,579 City of Seward . 5 Homer Electric Assn inc _ . AEGST : . . 2,002,898 Anchorage MBP co cae eee 826,008 oan 8,524,731 _ Chugach Electric Ass. = . 7 ee 1,975,216 . _ 21,300,461 . Golden Valley 568 . 7 194,008 __ 1,056,579 “Note:Fuel Use in Volume!Weight; coal in short tons, oil in 42 gallon barrels, gas in MCF(millions of cubic feet). (a) Generation value reflects “Total Sales" from PCE Report (b) IHN-N and King Cove have some hydro generation, no values for separation by prime mover: efficiency values not valid for INN. Error in reported fuel usages for Gwitchyaa Zhee- fuel efficiency values not valid. 35 Arctic Northwest _ SouthCentral SouthEast, South West Yukon Alaska Village Electric Coop _ Alaska Village Electric Coop — Alaska Village Electric Coop Alaska Village Electric Coop _ Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop Alaska Village Electric Coop soon ont Alaska Village Electric Coop Alaska Village Electric Coop | Alaska Village Electric Coop Alaska Village Electric Coop _ Alaska Village Electric Alaska Village Electric Alaska Village Electric Arctic Utilities (now TDX) Barrow Utils & Elec Coop Buckland, City of Diomede Joint Utilities Golovin Power Utilities Ipnatchiag Electric Company Kobuk Valley Electric Company ( Kotzebue Electric Assn In Kotzebue Electric Assn In Nome (Joint City of) North Slope Borough North Slope Borough North Slope Borough North Slope Borough North Slope Borough North Slope Borough North Slope Borough _ Teller Power Compa Unalakleet Valley Elec Co! White Mountain Utilities _ 179,162. 3,761,085 _ 704,468 Table 2.3c 2001 Utility Net Generation, Fuel Use and Fuel Cost by Plant * _ 167,087 834,519 179,162 Kotzebue ~. Snake River _ Anaktuvuk Pass = Atqasuk — " “Kaktovik Nuigsut Point Hope Point Lay Walrwright Teller Unalakleet _ White Mountain AA4 a) “4,023 ~ 941 . 2045 _. 1,329 193577 3,544 2,569 1,929 3,657 1,499 ae a =a 2,026 2,706 “4,079 © “40,993 160,123 (2,236 A149” 210777 1.250. 43,047, 5,736” _ 3,429 7,186 4275 6,908 4,589 1467 © 7,295 1494 2,638 0 3,164 4597 36 75138 7 10,773,181 8,752,497 Liaeri6 ES 0 2.459 6,038 at 2 2010 Ls Kodiak Electric Assn Inc (FDPPA) cL Larsen Bay Uliity Company * $1.40 Quzinkie, City of “$1.75 Tatitlek Elec. Util. 40-44 | 14.84 "10.79 "8s" 11.28 © ANT | “11.48” 12.01 970 — 1.67 “44.73 10.41 21.59 “$0.11 $0.18 arate 37 ro rs Alaska Electric Light & Power (AIDEA) Annex Creek Alaska Electric Light & Power . Auke Bay i" Alaska Electric Light & Power ‘Auke Bay. 12.79 Alaska Electric Light & Power = Gold Creek Alaska Electric Light & Power ‘Lemon Creek A Alaska Electric Light & Power ; eck 12.64 Alaska Electric Light & Power — “Salmon Creek Alaska Electric Light & Power Snettisham, Alaska Power & Telephone "Black Bear Alaska Power & Telephone © “Craig, Klawock 43,24 7 Alaska Power & Telephone Alaska Power & Telephone Alaska Power & Telephone Alaska Power & Telephone 13.89 Alaska Power & Telephone ape ee Alaska Power & Telephone = Alaska Power & T. i 12.10 Alaska Power & Telephone i Elfin Cove Electric Utility 12.41 Gustavus Electric’ ‘Company , 12.71, . Ketchikan (City of) Ketchikan (City of) Ketchikan (City of) Ketchikan (City of)” Ketchikan (City of) (FOPPA) Metlakatia Power & Light Metlakatla Power & Light Metlakatla Power & Light Pelican Utility Co Pelican 10.60 Pelican Utility Co pepe h Pecan ae: bana Petersburg (City of) - os Petersburg | : Petersburg (City of) Petersburg Ti Sitka City of & Borough 0 Blue Lake Sitka City of & - ‘Blue Lake Fish Vaive — ; Sitka City of & Borough” Green Lake ; Sitka City of & Borough . Indian River | . 1169 Tenakee Springs, Cityof ""_ "_Tenakee Springs _ fad Thome Bay Public Utility Thorne Bay se Tlingit Haida Regional Electric Authority” Angoon 43.05 Tlingit Haida Regional Electric Authority " ” Chilkat Valley” Tlingit Haida Regional Electric Authority 14.74 Tlingit Haida Regional Electric Authority | 13.78" Tlingit Haida Regional Electric Authority "Ka: ; aw 4 8.06 Tlingit Haida Regional Electric Authority Klukwan (See Chikat Vailey) 0 Tyee Hydro (FOPPA) |, Wrangell” a as , Wrangell (City of) i ‘Wrangell 1021 17.54 Yakutat Power (City of) Yakutat 13,660 $1.36 14.60 9 ' F ’ t f i t i __ 14.45 12.06 ee 10.730 12.03 | 428 10.58. ‘sas eo . $0.07 $0.10 “$0.09 $0.14 $0.00 “$0.10 $0.13 $0.14 © $0.11 $0.13 $0.15 $0.09 $0.13 $0.09 38 igiugig Electric Company EN-N Electric Goop Inc (b) co, 2497 . . 1675, 39 23474" “163. "435 © 49422 © 841 “$223 °° > 3149 > $1.49 40 279 731 194,008 180,663 614 1,298 579,314 | 1,053,13 179 733 ” 4436)” 3181” on 84, 905. 1,260. 120 (a) Generation value reflects "Total Sales" from PCE Report (b) I-N-N and King Cove have some hydro generation, no values for separation by prime mover: efficiency values not valid for I-N-N. Error in reported fuel usages for Gwitchyaa Zhee- fuel efficiency values not valid. 41 Table 2.4a 2001 Utility Energy Sales, Revenue and Customers 1 (9000) | (wy : : $9,197 44.414 7,100$13,486___91,317 3 8 $4,624 18.418 - _181,596 9,039 South Central $140,308 1,225,116 155,183 $153,027 22.795 191 $5,215 32,082 759 $411,727 3.262.684 “178,837 South East = : ~~~$25,332.___ 272,820 $16,453 eee) ~~~ 167_ $8,788. ===» 2/651. $50,386 ___ 706,202 $2,808 ‘South West $13,042 "46,293 $16,976 2,276 59° $5,314 715 $38,367 ~~ 153,925 10,067 $16,062 134.118 5,709 459° $3,491 10,260 433 $102,604 1,125,429 41,410 7,109 $13,466 91,317 1,223 $79 185, 8 $4,624 18,418 700 $27,541 151,596 9,039 ao a aa aeeeiees sos ‘$127 $311 $239. $176 $143 IS 8iaaen Binal ala ces $1,793, 7,563 _ $2,730 12,592 767 9,411 $2,204 12,091 $145 2 $222 439 = é $418 1,516 258 $609 2,398 - - : Regional Total $3,750 1,702 $1,132 3,338 V2 $3,286 Total NSB 665 1,222 26 42 $140,308 1,225,116 155,183 $153,027 __ 1,733,837 | — all nal al - = 235 $2,047 15,268 1,832 5,910. 3178 18,065 $8,409.56, as car "$2,370 as ~ _$17,512___ 151,667 $15,260 $5,121 30613 3. $38,166 332,253 $16,718 ‘$100 22,795 $23,880 _ 291,368 $2. $53,401 721,040. $83 276 ss? 305__ $1,951 __ 21,804 903 6 _481 363 10 20 Ey 1 $8,227 $83 $14,405. $3,415 $124 $478 $2,431 ‘$788 $1,448 $286 4,015 7,313 45,554 12,211 301 1,299 43 8,749 $16,976 $70 $14 528 319 a ec 9,705 $22 $345 $1,782 $197 A 391 420 $52 ~ $20 $13 a = 622 1563158 aoe 88 | 141 46 i 23 15 886 178 $326 91 116 a7 eoiOt: 24 a) “122 35 - 169 81 139 “i ; 400 4 - 83 19 : 1,078" 25 $204 8,546 109 $1,647, 39 $57 r eu obo 608 11,333 201 $93 $7 313 $100" 250 $98 229 $182 563 a $460 “1,281 137 156 13 $207 530 96 34 12 359 eres. eeeencenens $915 1227 167 $362, 1,013 20 44 es s = $55 78 7 ‘$612 056 183 45 $16,062 ‘Alaska Power & Telephone Co. ‘Alaska Power & Telephone Co. $371 851 "209° “$163 $230 493, 106 $16 3149 330 2 $34 $162 . $208 $200 $172 $435 $13,338 $432 $93 $92 $47 $357 $3,974 9,345 2.316 $1,018 $210 S08 ee eer ee 134,118 _ 575 1,548 124,023 1,265 52 3,034 5,709 $48,351 669,564 459 $3,491 $1,404 5,255 35 $103 5,253 $46,947 664,309 "424 . 73 7 - - St 10,260 433 $102,604 $842 18 $311 23 $840 23 $374 20 $289 15 $375 W $266 ST. $808. 26 ‘$410 19 $497 1h 16 $266 a: a $149 ao SAO, $59. " $379 12 $2,343 > $89,816 7 ‘$802 - $180 1 1 $664 385 $8,222 1,125,429 749 104 2.321 247 836 131 683, 97 A019 625 102 BAT BRT 1,042 140 1337145 261 348 673 90 A012 126 360 55 1679161 141 BEE 1081s 227 . 328 1,265 is3 8,170 321 4,071,392 37,370 2,267 331 se 330 nnn B44. 86. 505, 1000) 8 551 1226 aT, 408 14,691 21,723 2,838 46 y ‘$753 2.316 $1,018 178,285 $151,992 ‘506 28,940 62,946 $50,363 6 $1,320 4,767 65 $178,595 1,112,183 $1,331 10,909 267__—$87,431 $2” $1,491 11,958 145 $6,481 e 3 392,263" 37,466 $1 Soe ” 8 26” $58,459 532,312 40,510 Golden Valley Elec Assn Inc Fairbanks $26,135 283,060 31,693 $13,338 124,023 5.253 $46,947 664.309 424 -- = $89,816 1,071,392 37,370 “Totals may reflect values not accounted for in other fields (sales for resale). Some totals were supplied by EIA and contributing values were taken from secondary source to fil in details. 47 North Slope Borough North Slope Borough Nosth Slope Borough North Slope Borough _ North Slope Borough North Slope Borough _ North Slope Borough = __ Buckland, City of Central Electric, inc _ City of White Mountain _ Diomede Joint Utilities Golovin Power Utilities Ipnatchiag Electric Company Kotzebue Electric Assn, inc Nome Joint Utility Systems Teller Power Company, Inc Unalakieet Vailey Elec Coop Alaska Village Electric Coop North Slope Borough 36,372 5.219 Arctic Utilities, Inc (now TDX) ~~ Barrow Utils & Electric Coop, ine $1,294 222 74,666 $11,011 147 23,125 $9,875 42.7 26,326 $6,610 25.4 $904 11.5 76,061 $6,713 BB 1,825,487 $125, 42,291 __ $6,874 i $354 9.3 _ 93 621,257 _ $46,246 42,216 $3,315 $1,491 28.2 30,101 «$7,459 24.8 212,814 $35,254 25,906 $7,437 $916 11.1 23,494 $2,814 120 .745 $105,340 23,716 $8,070 340 $1,294 222 74,666 $14,011 14.7 23,125 $9,875 427 26,326 ‘$6,610 25.1 $2,195 47:3 19,600 _$7,300_ " wn sume ume, 8,200, $9,000 $1,691 42.9 "44,000 $14,000 18,000 $6,684 $1,957 44.7 “33,855 $11,687 26,063 $11,084 $2,380, _ 468 25,055 __ $0,178 = a — 21,782. _ $0,488 $2,476 43.5" 25,295 $9,114 33,606 “$10,969 $2,338_ 406 27.837. _$8,487_ a Se Oe re eee $2,504 39.9 332 $9,166 25,735 ($8,363 $2,813 456 14,433 “$5,659 $10,962 $2,016 44.3. 25,258 $8,951 = a __$9,576 . 455 31,890 $11 ——<— = “$10,195, $2,555 40.6 21,542 $6,879 $6,956 $2,192 44.0 34,432 «$11,405. ee ee $9,010 $ “477 718,290" $39,263 a $9,203 $1,866 40.4 29,633 $8,708 - $8,297 $1,689 41.3. 41,107 $12,733 “ $10,434 “a2 14417" $4,579 a 57,367 —_-= 260,484.” $41,200 a = —- $695 105,540 $7,654. M0718 $3,126 7 ee ete awed ~ ee = a _.15.0 71,22 15.0 50,029 a = . = i . 134 23,431 - a _ ee 131 27,287 15.0 175, eo = 5 —. 134 29,677" _ Se dy ep eee = 37.0 19,684 $879 48.0 1,628 $469 28.8 _ Se ee ee es $1,698 43.0_—«14,267 $6,133 43.0 23125 $9875 427 8,000 $3,333 43.0 8,986 nts 38.0 2,836 . pa = $1,975 38.7 27,385 $10,000 365 42,333" $4,333 "38.4 $1,749 237 “91,246 $19,783 217 _ $1,161 19.4. 50,803 $9,261 | 18.2_ . - 41,916 $7,571 18.1 $2,071 $3.5 16,259 $8,222 50.6 . $1,620 27.6 _34,754 $8,826 25.4 - a a $2,204 439 29,803 $10,106 33.9 25,093 $9,267 369 142 43,650 48 ‘Alaska Village Electric Chitina Electric, Inc s Chugach Electric Assn, Inc - 8,286 $924 ttt City of Anchorage _ . oe _ 6253 $594 9.5 City of Chignik 4,074 $1,222 30.0 City of Larsen Bay . . . _. 4164 $1,655 39.7 Chyct Ouignte _ - = — me 123, $1,321_ 32.0 City of Seward 8334 «$1,117 134 Copper Valley Elec Assn, Inc Valdez/CordovalCo . . Pper. oe 178 Cordova Electric Coop, inc Cordova 26.2 Homer Electric Assn, Inc ee Homer | . 1.5 Kodiak Electric Assn, inc . Kodiak _ | 16.7 Matanuska Electric Assn inc Mat-Su $1,019 115 Tatitlek Electric Utility Tatitlek 8323 © $3,228 38.8 con 78 121,102 74 - a 19,714 41,692, $2,091 40.4 33.871 —— 19,377 $37,519 85,677 _ $12,819 eee te 16,167, $3,607 $152,333 17.4 .. 48 2, $ - 15.0 66,105 $6,206 10,875 $4,250 ~~ 14,446 14,000 73,338 9,000 19,500 _ “14,000 82,469 _ 16,855 10,333 14,080. 169,200 24,536 2,000 $7,433 ‘$4,000 $20,308, $4,988 $2,545 $7,000 $5,167 $10,283 $2,747 $3,103 $1,736 ‘$42,000 $5,464 $1,000 ‘Alaska Electric Light & Power Co ‘Alaska Power & Telephone Co. Alaska Power & Telephone Co. Alaska Power & Telephone Co. Alaska Power & Telephone Co. Alaska Power & Telephone Co. ‘Alaska Power & Telephone Co. ‘Alaska Power & Telephone Co, Alaska Power & Telephone Co. City & Borough of Sitka City of Elfin Cove City of Ketchikan City of Petersburg City of Tenakee Springs City of Thome Bay. City of Wrangell Gustavus Electric, Inc Metlakatla Power Pelican Utility, Inc Tlingit Haida Regional Electric Authority Tlingit Haida Regional Electric Authority Tlingit Haida Regional Electric Authority Tlingit Haida Regional Yakutat Power, Inc ‘Alaska Power & Telephone Co. Tlingit & Haida Region Electric Authority $1,043 .. $4,022 $966 $958 $747 ‘$1 067 ‘$869 $1,428 ~ $943 $877 $1,639. "97 32.0 22.6 14.2 9.2. 92 ‘. 34.6 46 348 on 348. 346 446 188 46 39,616 47,090, 1,918 51,730 5,524 62,706 21,509 1 10,489" 93,842" 4,205 35,305 45.560 “16.110 604 29,762 415573 727 7.054 51,482 19,706 30,131 $3,668 $4,803 _- $1,429 $5,590 “$1,886 $1,519 $2,617 $2,543 $2,231 $3,974 $2,150, $10,976 — sabe 93 621,257 $46,246 83 $98,865 $42,271 7.4 112,902 $7,867 7.0 93 a "89. 2,577,909 88 571,517 32. 249 17,800 10.7 68,000 53.0. = 11.2. 90,400 13.8 23 | eS 24,804 $5,059 20.4 28.2 ~~ 8,630 $3,185 36.9 50 $1,491 282 30,101 $7459 24.8 212,814 $35,254 166 $7,437 28.7 $1,056 36.2 15,425 $6,250 40.5 = 39.0 $1,788 46.1 21,250 $9,250. 43.5 = — 20,400. 45.4 $2647 4 28,714 $12476 43.4 .. $1,967 46.7 34,000 $13,333 39.2 137,000 $1,707 _ 43.2 22,256 - 41.9 20,982 45.4 30,401 es . $7,675 $ 425 ~~ 7,080_ 13,480 ($5,738 $2,104 43.5. 19,152 $5,885 30.7 27,449 ($8,862 3 __.. $1,525 41.3. 80,729 $21,820 27.0 = = 12,514 $4,792 38.3 41.4 12,863 ~~ $4,598 35.7 ae _ 17,848 $6,747 37.8 42.1 48,641 $14,369 «29.5 21,237 $7,566 = 358 48.4" 19,819 $7,664 38.7 11,167 $5,009 44.9 40.2 21,834 $6871. 31.5 : 22,721 $7,426 32.7 436 25,018 $8,923 35.7 23,459 $6,861 37.8 41.8 47,521 $14,256 30.0 —- - 23478 $8,217 35.0 442 16,567 $6,536 «39.5 = = 21,319 $8520 400 429° 11, . 17,466 = $6,585 377 41.3 "16,515 - — = 18422 $6084 39.5 262 34,633 37.0 6,347 : . ——= _479 5,675 - 7 30.0 . - 345 12,000 $4,143 34.5 8,000 $2,633 35.4 20.3 25,000 20 _ _. _. 120,000" $24,300 "20.3 6 4,368 387 14,000°~ $4,591 32.8 _36.8 43,120 $13,800 32.0 40,533 $13,600 336 21,484 $7,935 36.9 23.2" 76,422 $16,349 “145 19,708 $3,626 19.4 56.0 9,231 «$5,051 26.4 50.0 4,114 _ a - . —— 5.931 7 = 7 = $3, 43.4 43,104 424 $1,850 58.7 13,000 4,250 $1,875 444 $2,320. 508 12,621 $5,961 47.2 . . = “ 275 30,248 oe = es $1.91 54.9 4,800 $2,600 54.2. 5,091 : 500 6632 ; _. $1,791 45.5 71,800 $31,600 44.0 . 10,250 $19,750 192.7 $2471 47.4 7,313 $4,750” 65.0 15,000” $2,333 15.6 = a = : . = 80.0 6,357 $1,888 37.9 22,333 $7,762 34.8 50,650 $18,100 357 ~ 85.1 2,362 = 7 : = ~ 65.1 9,108 — - 65.1 2,856 65.1 7,168. - oe oe - SS = oeecs = = 32,769 $7,052 21.5 3,739,000 $578,000 185 9,000 $6,600 73.3 6538 $3,000 45.9 27,288. $8,443 ” 30,000 $12,333, = 14,263 ; 25,592 $5,395 17,078 $3,711 217 15,714 $9,429 ee 13,200 $7,800 59.1 6,543 51 Pon 40.0 46.1 11,167 50.0 40.0 440 “427 65.1 Si $1; $1,053” $1,286, $1,395_. $888 $1,191 $1,100 $1,279. $1,231 $1,000 41.0 42.7. 17,810 “423 11,354 43.9 19,529 41,0” _ 13,603 400 ~ 160, 66.7 ~ 17,750 40.0, ; 50.0 7,678 $16, $4,368 $7,174 $5,406 “$8,750 3027 47.917 $14,333 20,919 23,810 36.9 17,329 _$32_ 9,000 53.0 8,709 763° 7,222, 40.0 ~ 41,358 2.4 266,000 a 9,834 51.0 14,656 $5,878 $2,539 $5,918 $4,778 $5,167_ $15,328 $7,833 $22,313 29.9 i 28.1 160,143 $40,114 26.7 10.8 1,566,767 $110,724 7A 342 _ 53.1, m5 a 29 49.7, 33.6 28,484 40,077 35,860 25,233 15,902 42,629 _ 43,602 13,258 20,340 20,061 30,562 20,089 23,568 (24,284 19,004 18,409 17,266 31,037 3,600 27,429 7,500 19,912 ~ 22,600 $4,154 $11,541 $13,542 $5,640 — $5,361 $0,493, $7,045, $9,425 $7,083 — $8,317 $6,281 $6,744 $7,380 $11,047 | $2,000 $2,485 $8,583 $10,143 $3,500 $2,867 "$11,060 32.6 “12 318 as 404 32.2 39.1 we 35.3 35.3 344 28.7 28.6 37.0 46.7 15.0 53 m pet | Commis Total APC 3567 21.6 16,342 — Regonel Tot =—__ 3,670 188 19,706 Be J 3 fick : Regional Total 3,309 29.5 8,639 Total AVEC 4414 $1,926 42.4 24,554 $8,294 33.8 23,063 352 36.2 Regional Total 4,945 204 439 29,803 $10,106 33.9 25,093 $9,267 369 . _RegionaiTotal 3,736 $1,870 484 8900 $4,219 474 . 4416 $7,433 51.6 Regional Total 4,439 «$1,940 42.7 «23,007 $7,702 33.5 19,268 $7,165 37.2 Regional Total 4,034 $1,716 40.8 22,196 $7,449 33.6 24,297 $8,397 M6 Railbelt ‘$887 10.9 68,883 $5,916 8.6 1,725,520 __ $115,827 67 48,885 $7,510 15.4 Chugach Electric Assn, Inc _ Anchorage $924 11.1. 69,938 $6,317 __ 9.0 4,706,667 $367,167 7.8 73,338 «= $20,308 «= 277 Gayot Anchorage _ Anchorage _ 9594 9.5 121,102 . — <<, 38,588 $4,985 12.9 City of Seward ee Seward $1117 134 19.377. $2,925 $37,519 89 82.469. $10.283 125 Homer Electric Assn, Inc Homer $849 115 50,696 $4,790 9 $297,654 48 14.080 $1,736 123 Matanuska Electric Assn inc Mat-Su $1,019 115 66,105 ‘$6,206 94 24536 © $5,464 223 Golden Valley Elec Assn Inc Fairbanks $688 99 23,610 $2,539 10.8 1,566,767 $110,724 7A i Rates in italics are weighted averages; commercial, industrial and other rates are calculated rates. r e ma ms $0.12 $29.3 $58.7 $88.0 $117.3 $166.5 _ $222.4 $85.9 $69. _se06 ~~ $02.9 “$21.3 $281.7 $83.3 $111.1 $140.9" $55.6 $0.22 $55.5 $177.0 $166.5 $222.1 _ $0.47 _. $236.5 $354.8 $473.0 _ sire $237.1 9148.5. $193.9 $401.3 $535.1 $206.8 $275.7 _ $219.3 "$328.9" $71.0 $106.6 $1 $35.5 $0.11 $28.6 $57.3 $85.9 $114.5 $0.37 $025 $185.0 «$277.5 $370.0 $0.60 $150.0 $300.0” $450.0.” $600.0 _ $048 "$120.9 _ $3626” _ $483.5 _ $0307 "$73.8 _ $2213" $295.0 ~ $0.35 $88.1 $264.3 $352.5 $011 $27.9 $636 $111.5 _ $0.10 $238 > $71.3 $95.0 “$0.30 «$75.0 $225.0 ~ $300.0 $0.40 "$208.0 _ $307.4 $0.32 $240.3_ “$100.6 $132.1 Alaska Power & Telephone Co. Alaska Power & Telephone Co. Alaska Power & Telephone Co, _ Alaska Power & Telephone Co. Alaska Power & Telephone Co. Alaska Power & Telephone Co. City & Borough of Sitka City of Elfin Cove City of Ketchikan $93.6 City of Petersburg $96.6 City of Tenakee Springs “$319.8 City of Thorne Bay $225.9 City of Wrangell E $111.5 Gustavus Electric, _ Gustavus $592.4 Metlakatla _. $92.5 Pelican $153.7 $345.8 i $0.38 _ $345.8 $0.35 $345.8 = $0.35 $345.8 $0.35 _ $3458 $0.35 " $259.4” $345.8 $0.25 $167.5 $250.0 Alaska Power & Telephone Co. Regional Total i $0.19 $46.9 $939 $140.8 “$187.7 Tlingit & Haida Region Electric Authority” Total THREA $0.35 $86.5 $173.0 $259.5 $346.0 56 [South West Aa Tae $70.4 “$106.2” _ $1032 $140.9 $211.3 $181.0 _ $148.9 $231.3 $2714 $261.7 $361.9 5. $390.0 $460.9 $412. $441.3 57 Pedro Bay Village Council Pilot Point Electrical ~ $2000. = ~ $200.0 __ $220.0 — Alaska Village Electric Corp. ___ $375.0 $500.0 $160.5 $214.1 2.” $597.6 _.'$262.5_~_ $350.0 $375.0” $500.0 “$167.1. $222.8 10 $456.3 $350.0 $481.0 $2525 $336.6 $300.0" $400.0 _ $345.7 $460.9 "$375.0 $500.0 $300.0 $400.0 $330.0 $440.0 $310.9” $4266 $488.3 $651.0 | $738 | $101.9 “$195. ~ $122.1- "$188.4 “$47.7 $203.8 — 59 Special Categories ‘Alaska Power & Telephone Co. Total APC $0.22 $54.0 $108.1 $162.1 $216.4 ‘South East Regional Total $0.19 $46.9 $93.9 $140.8 $187.7 Yukon Regional Total $0.30 $73.8 $147.7 $221.5 $295.4 ‘Alaska Village Electric Coop Total AVEC $0.42 $106.1 $212.7 $3182 $424.3 Arctic Northwest Regional Total $0.44 $109.6 5219.3 $328.9 $438.6 South Central Regional Total $0.48 $120.9 $362.6 $483.5 Southwest _ Regional Total $0.43 $1066 = $213.3 $319.9 $426.6 Yukon Regional Total $0.41 $101.9 $203.8 $305.6 $407.5 Railbelt $0.11 $27.2 $54.4 $81.7 $108.9 Chugach Electric Assn, inc Anchorage. _ $27.9 _ $83.6. $111.5 City of Anchorage _ $23.8 _ S713, x City of Seward : $33.5. Homer Electric Assn, Inc i $28.9 M Electric Assn Inc Mat-Su $28.7 (Note: Revenues reported in thousand dollars (US$), Sales reported in MWH and Consumers as accounts) 6 60 Table 3.1 Alaska Industry Energy Production 2000 Installed Capacity by Prime Mover (KW) 479,313 _ 155,720 40,000 Totals: 439,358 30,000 Petroleum Production and Transportation 439,358 - 439,358 Mining 30,000 _. 30,000 Petroleum Production and Transportation 12,755 52,380 65,135 Petroleum Processing 22,000 10,055 32,055 5,200 13,825 19,025 5,200 13,825 19,025 Totals: 35,460 35,460 35,460 35,460 Mining 4,400 4,400 Miscellaneous : 9,600 40,000 49,600 61 ee Table 3.2 Alaska Industry Energy Production 2000 Net Generation by Prime Mover (KWh) 2,595,577,335 2,016,873,072 370,225,263 208,479,000 _iTotals: _2,017,343,500 _1,805,461,000_ 211,882,500 Petroleum Production and Transportation 1,805,461,000 1,805,461,000 =O. Mining 211,882,500 211,882,500 270,044,830 197,585,856 72,458,974 Petroleum Production and Transportation 105,379,308 81,523,500 23,855,808 Petroleum Processing 164,665,522 116,062,356 48,603,166 __ Totals: 18,025,000 §,000,000 13,025,000 18,025,000 5,000,000 13,025,000 72,588,112 8,826,216 63,761,896 72,588,112 8,826,216 63,761,896 Totals: 217,575,893 9,096,893 208,479,000 2,816,893 2,816,893 214,759,000 6,280,000 208,479,000 F re mM Table 4.1 Alaska Military Energy Production 2000 Nameplate Capacity by Prime Mover (KW) [Military Totals; 14,000 95,400 _ 109,400 South Central 47,900 47,900 Yukon 14,000 47,500 61,500 ene nna pce 1100... 47,500. 61,500, 63 mm Table 4.2 Alaska Military Energy Production Net Generation by Primemover (KWH) 2000 Data by Community 360,383,083 0 3,185,893 357,197,190 South Central 188,864,000 0 0 188,864,000 Yukon 174,519,083 0 3,185,893 171,333,190 Table 5.1 ALASKA UTILITY INSTALLED CAPACITY (KW) BY PRIME MOVER (1962-2001) . 1968” "339,688. 1969 347,013 1970 ~ 1971, | AT2 z “1972 "© 533,639. "11973 | > 650,050" 1974 “1975 1976 - 1977 1,038,270 1978, _ 1,132,590 | 1979 1,257,835 _ 1980” 1,285,237 198174 1983. a7 eo a . 26 - 870,874 60% . 1984. 4 oe 4% ome . ; «= 947,624 | _ 59% 1985. |" 1,601,714 "224,000. _ 144,50 SS -. =a ok 933,600 58% _ 1986. 1,669,200 2 woul . 17,500 _ 972,100) 98% 1987 227 625 : erael on» 316,148 966,000 58% 1988 2 . coud _. 32 a ~ . , 907,600. 57% . 1989 _ 1,610,966 2 : a ow OH BM . » - 896,900 . 58% . 1990 _ 1,604,767 2 € a 00... 9%... 312,760 oS ng OOOO os OM. . 1991 . 8S s . . % 24,851 903,500 52% _ 1992, 1,7 365,632. see .. - 328,758 |. .. . . 906,300 52% 1993” ” 1,741,487 "* "901,500" |” ” $2% _ 1994 | 1,771,065 52% "1995 | | 4,777,575 - 52% _ 1996 2,078,865 59% .. 1997, _ 1,960,366 | 0%, 1998, _ 2,124,813 =e 1999 = 14:227,225 | S7% 2000 1,232,425 | 56% 2001 1,270,650 56% “From 1996 onward: Cumbustion Turbine (CT) includes Gas Turbine (GT) and Combined Cycle Turbines (CA) “*Wind Turbines (WT) included in net capacity value Data from 1996-2000 from EIA historical tables and not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. Data before 1996 from prior Alaska Electric Power Statistics reports. Table 5.2 ALASKA UTILITY INSTALLED CAPACITY (KW) BY REGION . _ 1970 1971 1972 en re Seeger ioscan . = wo en _ 1973 650,100 11,600 2% + «369,800 «57% 126,300 19% 11,600 “130,800 20% 1974 724,200 12,100 2% «438,700 «61% ~——*'129,600 «18% 12,300, 131,500 "18% 1975 763,500 14,700 2% 451,500 59% 136,900 18% +~——-20,400 "440,000 "18% 1976 | 971,700 18,200. 2% 556,900 57% 139,700 14% --23,400 _ 233,500 24% _ 1977 1978 ee eet eet Shera 1980... 1,283,054 58% 176,732. 14% 28,887 2% 299,772 23% 1981 1,373,734 61% 175,502 13% 29,867. 2% 297,502 22% 1982 1,412,504 60% 192,802, 14% ~~ 32,196 2% 300,777 21% 1983 1,447,752. “59% 215,747 15% 38,494 3% 304,152 21% 1984” 1,605,485 “59% 272,392 17% +~=—=—«439,884. 2% 301,512: 19% 1985 1,601,714 "58% 279,995 17% 41,215. «3% ~~~ 305,301 ~-—«19% _ 1986 60% 289,487 17% «42,283 3% SSi204,864 18% _ 1987 | 59% 288,238 17% 45,447 3% 287,229 17% - 1988 . 59% 291,911 18% 48,910 3% 271,270. 17% 1989 | “939,494” 58% 317,846 «20% ~~ 52,283. «3%. ~—S«249,376 15% 1990 ; | 939,487 59% «309,318 += «19% 53,327 «3%~=S—«C«24,350 «15% 1991 4,733,158 “1,054,479 61% "314,006 “18% 55,092 3% 245,466 14% 1992 1,739,890 _ 1,054,499 61% 314,011. 18% «57,832 3% 246,321 14% 1993 1,734,468 "1,046,065 60% 316,936 18% == —«62,323 4% 246,821 14% 1994 1,771,065 1,047,945 59% «341,471 «19% 62,912 4% 248,630 14% ©1995 4,777,575, 4,047,575. 69% 344,093. 19% 64,132. 4% 249,439 14% 1996 2,078,865 4,274,326 61% 351,316 17% == 60,279 38% 310,550 15% 1997 1,960,366 1,219,884 62% 343,139 18% 47,986 2% 284,528 15% _ 1998 2,124,813 _ 1,276,954 60% 380,294 18% == 64,772, 3% «316,353. 15% 1999 2,156,743 _ 1,292,639 60% 381,064 18% += 66,451. «3% «320,412 15% 2000 2,194,477 "98, 4,322,809" 60% "385,189 18% «66,680 3% 321,552 15% 2001 2,258,905 1,351,937 60% 415,746 18% 69,141 3% 318,129 14% Data from 1996-2000 from EIA historical tables and not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. Data before 1996 from prior Alaska Electric Power Statistics reports. me ry my Table 5.3 Utility Net Generation (GWh) By Fuel Type 1967 363 1968 363 Cae eed 340 1970 AA bee 1 ee i 362 197i ies ba ara i 1972) 4,207 , i 62% 2 i 1973, 406 189 13% 950 68% (267 | i Ti 1974 fF i: y 56% 299 f “319 17% 1975 ..- 2 i _ 58% _ 323.0 14% 351 16% 1976 eSB At 50% 314. 13% 369 15% 1977 4% | 51% 207 11% «498 18% 1978 j 14% 1,690 59% “41% 463 16% 1979 2,968” 363 13% 1,827 62% 308 10% 450 18% 1980" Fr 2% 18 61% 290. 10% 632. 18% 1981 3,154 pest i “60% 3388S 11%~~SS:C«SB1SS 18H 61% 364 10% 876 16% 331 9% ~~ BB 15% 308 8% 696 17% oa 2900 T% TTS 18% j 972 6% Ba 19% 1987 276 6% | 898 20% _ _ 1988 — _ 295 _ 22% | 1989 307 1% 5. 20% “1990 316. 7% ~—~—«1,024.—« 22% "1991 mM te 1992 : 0 302, 6% 1,337 28% — _ 1993 575 322° 7% 1,359 29% 1994 4,924 593 294 6% 1,384 28% 1995 5.019 591 309 6% 1,459 29% 1996 4,982 643 229 S% 1,266 25% 1997 5108 741 aes 5% 1,099 22% 1998 4590 757 | 171, 4% 1,113, 24% 1999 4,609 798. |, SR) JO 2000 ; 185. 4% 1,002 20% | 2001 5,646 483 3,028 194 1,361 24% ***Data was not collected in 1985, so 1984 and 1986 figures were averaged to arrive at estimated 1985 figures. Data from 1996-2000 from EIA historical tables and not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. Data before 1996 from prior Alaska Electric Power Statistics reports. 490 553 425 _ 539 459 580 10% 11% 9% 12% 9% 10% 67 1987. “1988 1989 1990 “901 ~ 4992 ms) 1994 1995 eT 1997 1998 1999 “2000 2001 _ 5,018,794 4,982,268 5,108,003 — 4,590,270 4,609,315 4,937,687 5,646,290 100,906 Table 5.4 Utility Net Generation (MWh) by Region (1963-2001) _ 0% : EONS "7,980 1% 0% 0% | 22976 2% <2 25.847 2% 28,798 2% 32,454 2% i 2% 211% 1% 94,981 107,467 112,398 ” "419,476 127,326 126,761 132,589 _ 135,373, 143,40 3% 3% 3% 3% 0,857 | 73,6257 1% | 122,432.” 3% 76632. 2% 128,838 98,213 2% om 167,057 | 3% 126,766” 179,162 "3% 3,761,085 Barrow Natural Gas values missing for 1996 Data from 1996-2000 from EIA historical tables and not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. Data before 1996 from prior Alaska Electric Power Statistics reports. “402,000 110,000 "117,350. 132,000. “145,000 ~ 171,000 198,000 240,132 276,574 312,437 -.320,485 18 348,567. 18 "433,577 © 476,860 "501,778 "486,613 _ 470,255 4 461,612 __ 449,855 _ 506,404 466,121 461,409 442,039 99 _ 491,264 3% "467,078 $33,270 "1 497,320 S02 549, _ 553,472 986,683 661,474 644,914 563,562 834,519 68 Table 5.5 Utility Sales, Revenue, and Customers (1962-2001) 7,472 27,000 000. $9,105 7,943 000 312,000 $10,060 8, 318 60,554 i 8 _ 357,000 $11,049 8,110 34,000 . $25,163 _ a ; - 53,797 391,000 $11,965 aw 7,000 $26,461 36,000 $12,285 65,902 411,000. $12,381 9,058. 64,000 $28,239 69,93 8 470,000. $1 69,000 513,000 $14,591 76,000 “$62,676” $85,810 _ 1,694,845 | $112,052 20,996 1,757,507 $126,179 21,778 $327,823 2 ; 12,266,920 $151.8 $351,620 1,610,969 $148,852 2,169,522 $172,254 296,143 _ $356,165 2 1,542,405 $150,996 4. 2,198,697 $179,972 __ 32,708 $26,185 2 5; 936 33,477 $27,697 2,538,044 $238,638 34,598: $21,660 s . 2,635,784 $248,265 $26,333 . 4,637,935 $472,891 250,815 i 1,870 2,702,302 4,779,562 $489,489 256,103 6 ~ 2,834,072 4,840,529 - 5,004,584 | § 992. $2 $277,217. 5,292,615 $} 4 9 _ 22 3,229,036 $281,217 _ X 5,309,970 4 30 2 . 4 .. $296,990 38,928 8s 2 5,419,836 a 885, E é 282, 097 37,372 191,183 $27,432 Data from 1996-2000 from EIA historical tables and not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. Data before 1996 from prior Alaska Electric Power Statistics reports. — |. 1969 "13,669 $404 “1996” 18,663" “$1,911 Table 5.6 Average Annual Energy Use and Cost (1962-2001) 19 8,673 1963” 9,625 $333 1964” 9,734” $325 "1965" 10,269 "$348 1966 11,461 $377 1967 12,493. $400 “1968” 12,857 $405 ~ AA 26,084 $1,092 37 34,261 $1,151 “35” "35,755" $1,148 $1,242 _ $1,362 $1374 1970 14,181 $412, 1974 1972 | 1973 1974 1975. wo = 1976 19,574 $746 38 10,238 1977 1978 78) - 1980" 19,548 ~ $1,008 1981 19,185 $1,181 1982. 19,769 $1,341 1983 18,988 $1,472 1984 18,303. $1,505. 198515079 $1,577 _1986 "8,238 $717 1987 17,354 $1,572 1988. 17,705. $1,614, 18,132 $1,671. 19 18,423 $1,749 1991 18,221. $1,783. § 1992,” 18.214 "$1,820 1993 18,056 _ $1,823 1994 ~ 18,555 "$1,900 1995 18,491 $1,885. _ 10,309 $529 «91943. $591. 10,373 $712 9,807” $787. 9,320 $789 "$829 $782. ‘$785 $827 10.7 . $858 10.1 $872 106 _ $891 10.8 $889 14.4 $928. 11. $915 _ 14.3. 77,279 188. $930. 4 1997 18,983. $1,912 10.1. 8,024 $918 11.4 1998 19,211 $1,916 10.0 7,931 $912 15 1999 19,615 $1,918 9.88210 M2 2000 $1,957 10.1 8,046 __ 922 14.5 2001 19,914. $2,350 14.8 «7,953 $933. 14.7 42,722 _” $5,699 36,344 $5,360 37,889 $5,184 (35,488 $5,026 44,714 $6,338 36,372, $5,219 87,844 Total sales, revenue, and customers may exceed the the sum of Residential and Commercial/industrial. This is due to the addition of accounts which do ‘Not fit into these two classes. These figures do not include sale for resale. Data from 1996-2000 from EIA historical tables and not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. Data before 1996 from prior Alaska Electric Power Statistics reports. & 70 ALASKA ENERGY BALANCE Section 2: The Alaska Energy Balance A. Overview Table 1 and Figure 1 summarize the amount of energy extracted, produced, exported, or used in Alaska in 2001. The different types of fuels are listed across the top of the table and the disposition of energy in Alaska is listed down the side. Total extraction of energy in Alaska amounted to the equivalent of 4853 trillion Btu’s in 2001. This extracted energy was in the form of coal, natural, gas, crude oil, natural gas liquids, and water power. Net Extraction: About 2,288 trillion Btu’s of this total extracted energy was re-injected into the ground in the form of natural gas to help lift additional oil out of North Slope wells. In addition, about 200 trillion Btu's of natural gas and crude oil were used during the process of extracting oil and gas and transporting oil through the TAPS pump stations. © The net extraction of energy in Alaska equals total extraction minus this energy that was re-injected or used during the process of extracting or transporting oil and gas. This net extraction of energy in Alaska amounted to 2,355 trillion Btu’s in 2001. Figure 2 summarizes the composition of total and net extraction of energy in Alaska. About 45% of all energy extracted in Alaska is in the form of crude oil that is either processed in Alaska or exported. Processed Products: Alaska’s four petroleum refineries and two natural gas processing plants processed crude ail and natural gas with the combined energy equivalent of about 400 trillion Btu's.?. These plants and refineries produced liquid natural gas, jet fuel, motor gasoline, diesel fuel, ammonia, and urea. These petroleum and natural gas products amount to the energy equivalent of about 363 trillion Btu’s. About 34 trillion Btu’s of energy are used up in the processing of these petroleum products. As shown in Figure 3, jet fuel and liquid natural gas comprised the largest shares of energy processed by Alaska refiners. Exports: Alaska exported 1878 trillion Btu's of raw energy products, including crude oil, natural gas liquids, and coal. In addition, all of the liquid natural gas and all of the ammonia-urea were exported. About two thirds of the jet fuel produced in the state were exported out of the state to the Lower 48 or foreign countries in the fuel tanks of international air carriers flying through Anchorage and Fairbanks. In total, about 2,139 trillion Btu's of energy were exported from the state either as raw products or processed petroleum products. As shown in Figure 4, crude oil contributed the largest share (89%) of energy exports from the state. ' This estimate of energy used during extraction does not include the crude oil petroleum products refined at the North Slope refinery and used locally. These petroleum products from the North Slope refi inery are included in the “Processing” line in the summary tables of this report. ? Alaska's four petroleum refineries are in North Pole, Nikiski, Valdez, and the North Slope. There is also a gas-to-liquids processing plant in Nikiski and an ammonia and urea processing plant in Nikiski. 72 wa Electric Power: As discussed in other parts of this report, electric utilities used energy to generate electricity. The utilities used as total inputs the energy equivalent of about 38 trillion Btu’s of coal, natural gas, liquid petroleum fuels, waterpower, and wind. In the process of generating electricity, utilities used up 20 trillion Btu’s of energy. The utilities generated as output the energy equivalent of 18 trillion Btu's of generated electric power for sales to consumers.* As shown in Figure 5, most of the electric power generated by utilities was produced from natural gas. Imports: Alaska imported a variety of petroleum products from the Lower 48. Consumers in Alaska get about 36% of their petroleum products from refineries outside Alaska. In particular, Alaska gets about two thirds of its motor gasoline and nearly all of its jet fuel from Alaska refineries. The rest of these petroleum aicttaiaid purchased by Alaska consumers come from outside the state. Net Domestic Consumption is composed of four components: residential, commercial, industrial, and transportation consumption. Notably, net domestic consumption does not include energy used by utilities for electric power generation or energy used up during petroleum product processing. Net domestic consumption in Alaska amounted to 223 trillion Btu’s in 2001. Transportation consumption was by far the largest component of net domestic consumption and amounted to 116 trillion Btu’s. Residential consumption totaled about 38 trillion Btu's. Commercial consumption was about 27 trillion Btu’s. Industrial consumption (including military bases) totaled 33 trillion Btu’s. Consumers used the “net domestic consumption” of energy in many different ways. We have estimates of the energy consumed for some of these specific uses, including transportation uses, heating use, military uses, and other uses: ¢ Transportation use: The single largest transportation use of energy was for airplanes, which consumed the energy equivalent of 47 trillion Btu’s (8 million barrels) of jet fuel. Diesel trucks and cars consumed 35 trillion Btu’s (6 million barrels) of distillate fuel. Gasoline vehicles consumed 33 trillion Btu’s (6 million barrels). We do not have sufficient information to determine how much of this transportation energy use was by each type of consumer. e Heating use: Residential and commercial consumers consumed about 52 trillion Btu's for space and water heat. Most of this energy came from natural gas (26 trillion Btu's) and from distillate fuels (20 trillion Btu’s). Electricity contributed 5 trillion Btu’s to heating uses. Wood and other petroleum products (such as propane) contributed much smaller amounts of energy heating uses by residential and commercial consumers. 5 Electric power and heat generated by industrial users other than utilities is accounted for in the summary table under “industrial net domestic consumption” of energy. 73 Industrial uses: Military bases in Alaska used about 9 trillion Btu's for heating and generating power. Alaska industries (other than military bases and oil and gas extraction or processing) used 33 trillion Btu’s for a variety of industrial uses, including heat, generating power, and processing materials. We do not have sufficient information to determine how much energy these industrial consumers used for each of these uses. Other uses: After accounting for heat, transportation, and industrial uses, the remaining 17 trillion Btu’s was used primarily in the form of electricity by residential and commercial consumers for lighting and other non- transportation uses. 74 Table 1: Summary of Energy Balance in Alaska in 2001 in Trillion Btu's Petroleum . ° Natural] Dis- Motor i Ect Total Gas | tillate |Jet Fuel] Gas- ui Fuel oline 2 TABS e gers ABs tt eee Are cae Se Industrial excluding extraction and processing Transportation Unclassified litem: Gross Product Exports Process Use Product Exports tem: Total Energy for Electricity 38 Used in Production : 19) 18 GonmodityipBTU Conversion Fastgr [ont oa] a7] er] a7] sal sv] a2 ex] aa] oo} aa | Source: US Energy Information Agency, Alaska Department of Natural Resources, ISER survey of electric power generators, Alaska Business Monthly, and US Army Corps of Engineers, Waterborne Commerce of the US. Final Consumption of hydroelectric power is included in electricity sales. 75 2001 Alaska Energy Flow (Trillion BTUs) a Gross Extraction Raw Exports Gross Product Exports Net Alaska = Product 4,844 1,878 Production 261 Consumption Imports 436 223 59 ind ‘6ther2! Residential/ Commercial <3 Ere eee hE yO! Utility Electricity Generation 37 dena deceoere cee tter ee seossouencaveds > SES OOWISSSS SESS 99555 5995 20 RSS EROOESS 5 SSS 5S Ss QESEAsS ee DPPSI S555 555.5555 bees Trans po! rtation 116 8935535 RRS 53555555555 76 Figure 2: Composition of Total Energy Extracted in Alaska in 2001 (Btu's) Gas Used For Sr Extraction 0.4% 4.0% Net Oil Extraction 44.7% Re Injected Gas 47.3% ~~ — ; Oil Used during Net Gas Extraction extraction 3.4% 0.1% Source: ISER Calculations Figure 3: Composition of Energy Used by Petroleum and Natural Gas Processors in Alaska Total used us mei (ears) during all types of oil and gas processing 8% Liquid Natural Gas product Other Petroleum 1 Products 6% 13% Distillate Fuel Ammonia and Urea product product a Th fo = Jet Fuel product product ae 10% ‘o Source: ISER Calculations 77 Figure 4: Composition of Energy Exports from Alaska in 2001 (Btu's) Liquid Natural Gas, Ammonia, Coal and Urea 1% Motor Gasoline 4% LO 0.9% Jet Fuel 5% Crude Oil 89% Source: ISER Calculations Figure 5: Electricity Generated from Each Fuel in Alaska in 2001 (Btu's) Electricity from Coal 4% Electricity from Hydroelectric 27% Electricity from Electricity from Petroleum Sf Natural Gas Products 59% 10% Source: ISER Calculations B. Commodities Table 2 summarizes the quantities of energy commodities extracted, processed, exported, or used in Alaska. Coal: In 2001, 1,514 thousand short tons of coal were extracted from the Usibelli Coal Mine nearly Healy, Alaska. About 194 thousand short tons were used as inputs for electric power generation at the GVEA electric power generator near the mine. About 750 thousand short tons were shipped through the Port of Seward to South Korea. The remaining 570 thousand short tons were sold to industrial and commercial customers, including Clear Air Force Station, Eielson Air Force Base, Fort Wainwright Army Post, and the University of Alaska Fairbanks.* These consumers used the coal for heating and power generation. Natural Gas: Almost 3400 billion cubic feet of natural gas were extracted in 2001 from the North. Slope and in Cook Inlet. Over 86% of this gas was re- injected into the ground to assist with lifting oil to the surface on the North Slope. Another 251 billion cubic feet was used to produce power and heat for North Slope facilities and the first two TAPs pump stations. The Phillips Petroleum gas-to-liquids plant near Nikiski processed approximately 78 billion cubic feet of natural gas into liquid natural gas.° About 11% of this natural gas is used to power the compressors and boilers at the gas-to-liquids plant.” In addition, about 54 billion cubic feet were used at the Agrium plant near Nikiski to produce ammonia and urea. Both are used as ingredients for making fertilizer and other products. All of the liquid natural gas, ammonia, and urea were exported from Alaska. About 33 billion cubic feet of natural gas were used to generate electricity by utilities in Alaska. Residential, commercial, military, and industrial consumers in Alaska used about 49 billion cubic feet of natural gas, much of it for heating. Petroleum: In 2001, 382 million barrels of petroleum were extracted from the North Slope and Cook Inlet as either crude oil or natural gas liquids. Alaska refineries in North Pole, Valdez, Kenai, and the Nikiski processed a total of about 52 million barrels of crude oil into about 26 million barrels of jet fuel, 8 million barrels of motor gasoline, 5 million barrels of diesel and heating fuel, and 9 million barrels of other petroleum products.’ All of the crude oil that was not refined in state was exported to the Lower 48 or Pacific Rim markets. Most of . 5 hrom Usibelli Coal Mine web page http:/www.usibelli.com/who.html 5 These estimates of natural gas processed into natural gas liquids, urea, and ammonia are from 1998 and are the most recent available from the Department of. Natural Resources Division of Oil and Gas Annual Reports. ® Kenai Peninsula Online, April 23, 2000, http://peninsulaclarion.com/stories/042300/new_0423000002.shtm! These estimates of refined petroleum products are approximations based on the published estimates of the percentage composition of petroleum products produced refiners. 79 the jet fuel refined in the state is exported as fuel for international air carriers flying through the state. Alaska consumers use about 12 million barrels of distillate fuel, 8 million barrels of jet fuel, and 6 million barrels of motor gasoline.® Most of these petroleum products come from Alaska refiners. However, Alaska also imports about 8 billion barrels of distillate fuel and 2 million barrels of motor gasoline from outside the state. Alaska also exports some motor gasoline that is refined within the state. Electricity: Other chapters in this report discuss the generation and use of electricity in more detail. Residential and commercial consumers use most of the 6 million megawatt hours of electric power generated in Alaska. Alaska neither exports nor imports electric power. . 8 About 2 million barrels of motor gasoline that re refined in Alaska are exported. 80 Table 2: Summary of Energy Balance in Alaska in 2001 in Commodity Units Total Crude Oil, Petroleu m Products, and NGL a =e Ee ea AES pees eee aes, z - Other Use during Extraction Woe ne ore mea | = Net Extraction” Net: Electrictiy Output (Million MWH of electricity) - Processing Use Miltary (part of oa - Transportation consumption) == |Heating (part of Residential and Commercial consumption) Source: US Energy Information Agency, Alaska Department of Natural Resources, ISER survey of electric power generators, Alaska Business Monthly, and US Army Corps of Engineers, Waterborne Commerce lof the U: 81 C. Prices Table 3 summarizes the price of energy in both dollars per million Btu and dollars per unit of energy commodity. Natural gas is by far the least expensive source of energy, costing on average $1.64 per million Btu. The price to industrial users on the North Slope ($1.51) is substantially lower than the cost to residential consumers (about $2 to $4 per million Btu). Coal is the next least expensive source of energy, costing about $2.21 per million Btu. Liquid petroleum products cost $7 or more per million Btu. Electricity is one of the most convenient and versatile forms of energy but is also the most costly, at $22 to over $30 per million Btu. Table 3: Summary of Energy Final Consumption Prices in Alaska in 2000 Petroleum Products All Distillate Fuel Dollars per million Btu |All Consumers Residential Commercial Industrial | Transportation ing (part of Residential and Commercial) llars per commodity unit All Consumers Residential Commercial Industrial Transportation Heating (part of Residential and Commercial) Source: US Energy Information Agency, Alaska Department of Natural Resources, ISER survey of electric power generators, Alaska Business Monthly, and US Army Corps of Engineers, Waterbome Commerce of the US 82 D. Historical Trends Using data on the consumption of energy from the US Energy Information Administration, we can track the amount of energy used since statehood in Alaska. Notably, these estimates of consumption from the EIA include the industrial use of natural gas on the North Slope during oil and gas extraction processes. As a result, they are higher than our estimates of gross consumption, which do not include the use of natural gas during extraction. Natural gas became the predominant source of energy used in Alaska after oil and gas production began in Cook Inlet, in the late 1960’s (see Figure 6). When oil and gas production began on the North Slope in the late 1970's, natural gas consumption by industrial users increased dramatically because it was used to power North Slope operations. All other fuels -- including diesel, motor gasoline, jet fuel, and coal, have contributed relatively stable shares of total energy consumption per capita in the state. Figure 6: Consumption of Energy in Alaska in | O!ndustrial Use of ~ Natural Gas Btu per capita Soha: 8 ONatural Gas used by non industrial users Other Petroleum Products Distillate Fuel = N = Motor Gasoline Million Btu per capita Jet Fuel QO > 40 “ S\ F FS SS PP PP FP SF FPF SS Wicoal Note: The US Energy Information Agency estimates of energy consumption include energy consumed during oil and gas extraction. Source: US Eneray Information Agency Natural gas has consistently been the least expensive form of energy and has averaged slightly less than $2.50 per million Btu (see Figure 7). Electricity has become less expensive over time as more power is generated from relatively cheaper natural gas (see Figure 8). The price of petroleum products closely follows the price of crude oil over time (see Figure 9). 83 Figure 7: Average Price of Natural Gas for All Consumers in Alaska in Constant 2002 Dollars $3.5 $3.0 $2.5 $2.0 $1.5 $1.0 $0.5 Constant 2002 Dollars per Million Btu $0.0 — O Av ab Ao XW KS Oo Vv o D sv LP KF FEE IHS ES s Source: US Energy Information Administration Figure 8: Average Price of Electrictity for All Consumers in Alaska in Constant 2002 Dollars $45 $40 $35 $30 $25 $20 $15 $10 $5 Constant 2002 Dollars per Million Btu $0 rr “ © Av ad XS SS - © ae M % FPP SF FEF EE IS SF IFS s Source: US Energy Information Agency 84 Alaska in Constant 2002 Dollars $25 $20 $15 An a Figure 9: Average Price of Petroleum Products in Motor Gasoline = = = Distiallate Fuel Jet Fuel a PLL S PPS iS, PIS EPS Constant 2002 Dollars per Million Btc % ‘9. ei o>, | * Source: US Energy Information Agency 85 E. Regional Consumption Some of the energy consumption in Alaska can be attributed to particular regions of the state: Coal: Most consumption of coal occurs in the railbelt, either near the Usebelli Coal Mine near Healy or at military bases and university campus either in or near Fairbanks. Natural Gas: Most final consumption of natural gas by consumers occurs in or near Anchorage. Substantial amounts of natural gas are also used for oil and gas extraction in Cook Inlet and the North Slope. Petroleum Products: Much of the petroleum products refined in North Pole and Nikiski are transported to other parts of the state by barge or by road. We investigated the Department of Revenue “Motor Fuel Reports” and the US Army Corps of Engineers Waterborne Commerce Reports in order to estimate regional consumption of petroleum products. Neither of these reports.provided sufficient information to estimate regional consumption of petroleum products in Alaska. Electricity: As discussed in detail in other chapters of this report, we estimated the regional generation and consumption of energy based on reports from individual utilities. Housing Characteristics: One of the primary determinants of residential consumption of energy is housing characteristics. Houses use various fuels for space and water heating and variations in housing characteristics across the state would partially explain regional variations in energy use. As listed in Table 4, housing units use a variety of fuels for heating. Notably, the railbelt uses mostly natural gas for heating while housing units in other regions use heating oil or electricity (often generated from diesel fuel in rural Alaska). Larger homes require more energy for space heating. One indicator of the size of homes is the number of rooms. Table 5 summarizes the average number of rooms in houses in different regions of the state. On average, the homes with the most number of rooms are in the Railbelt. Because of climatic variations across the state, there are substantial differences in the amounts of heat required to heat homes. Table 6 summarizes the number of heating degree-days for select places in Alaska to give some indication of the variation in space heating requirements in different regions of the state. 86 Coa Table 4: Percent of Housing Units within Each Region Using Each Type of Fuel Bottled Fuel oil, |tank or LP| kerosene,| Coal or Solar No fuel Utility gas} gas (Electricity etc coke Wood energy |Other fuell used Region | heating | heating | heating | heating | heating | heating | heating | heating | heating | Railbelt 58.8% 2.1% 10.4%] 23.6% 0.6% 2.9% 0.0% 1.0%] 0.6%| \Southeast 0.9% 3.5%] 16.2%] 72.0% 0.0%} 5.7% 0.0% 1.4%) 0.3%) Rest of State 5.1% 1.5%} 3.8% 80.8% 0.1% 7.2% 0.0% 1.2%] 0.4% [State 45.9%) 2.2% 10.2%] 35.8% 0.5% 3.7% 0.0% 1.1%] 0.5%| ISource: US Census of Population 2000 |The railbelt is defined as Anchorage, Fairbanks, Mat-Su, Denali, and Kenai Boroughs as well as the Southeast Fairbanks and Valdez-Cordova Census Areas Table 5: Percent of Housing Units within each Region with Number of Rooms 9or = 3 4 5 6 Z 8 more | Mean 1 room| rooms | rooms | rooms | rooms | rooms | rooms | rooms | rooms |Rooms' Railbelt 5.8% 8.6% 11.3% 17.3% 18.2%] 13.9% 10.4% 7.3% 7.3% 5.0 Southeast 6.3% 8.7% 14.0% 18.3% 19.1% 14.1% 9.4% 4.9% 5.2% 4.9 Rest of State] 12.2%| 13.3% 17.2% 19.7% 18.6% 10.1% 4.7% 2.2% 21% 3.9 State 6.7% 9.3% 12.4% 17.7% 18.4% 13.4% 9.5% 6.3% 63% 49 Source: US Census of Population 2000 87 Table 6: Heating Degree Days in Select Places in Alaska Heating Degree! Days (base of Region Place 65 Degrees F.) Railbelt Anchorage 10570, Fairbanks 13940, Homer 10054) (Talkeetna 11606) Valdez 9953, Southeast ‘Annette 6987} Vakutat 9485 (Other [Barrow 2022, Bethel 13098 Bettles 15689 Big Delta 13534 Cold Bay 9734 |Gulkana 13807 King Salmon 1145 Kodiak 8817 Kotzebue 15812) McGrath 14396 INome 1412 ISt Paul Island 11031 \Source: Western Regional Climate Center 88 F. Sources of Data Extraction: Data for the amounts of crude oil, natural gas, and natural gas liquid extraction and re-injection are from the Alaska Department of Natural Resources, Division of Oil and Gas 2002 Annual Report. Coal extraction is from Energy Information Administration Annual Coal Report. Estimates of the crude oil and natural gas used during extraction is available from Division of Oil and Gas Annual Report for 2000 through 1998, but is not available in the 2002 annual report for more recent years. Exports: Estimates of exports are available from the US Army Corps of Engineers, Waterborne Commerce of the US. We assume that all crude oil not consumed or processed within the state is exported to the Lower 48. We also assume that all of the liquid natural gas and urea fertilizer processed in the state were exported. Sales of jet fuel at Anchorage International Airport are from a special printout of the “Fuel Sellers Report — Gallons Sold” for fiscal years from the Anchorage International Airport Statistics System. These sales help estimate the amount of jet fuel exported from the state. Petroleum Refining and Natural Gas Processing: The Department of Natural Resources, Division of Oil and Gas 2000 Annual Report has statistics on use of crude oil and approximate composition of petroleum liquid refining of each refinery for 1998. Articles from Alaska Business Monthly provide additional detail for 2002 for select refineries. Petroleum Product Sales: Petroleum products sales by refiners come from the US Energy Information Agency Annual Petroleum Report. The statistics in this report are based on forms submitted by refiners, retailers, and wholesalers about the amount of each type of petroleum products they sell. The forms include ElA-782A, “Refiners’ / Gas Plan Operators’ Monthly Petroleum Product Sales Reports. Total retail sales of petroleum products is from EIA form EIA-782C, “Monthly Report of Prime Supplier Sales of Petroleum Products Sold for Local Consumption.” The Department of Natural Resources, Division of Oil and Gas Annual Report for 2000 has “Fuel Consumption History” section that lists detailed fuel consumption for taxable, exempt, and unclassified fuel use through 1998. The source of this data is the Alaska Department of Revenue “Motor Fuel Activity Reports” which list each type of fuel sold in Alaska using the categories and types of sales listed in Table 7. These Motor Fuel Reports are available through 2001, but are no longer generated by the Alaska Department of Revenue. The Motor Fuel Reports are not available for each region of Alaska. These motor fuel activity reports provide the most detailed and accurate source of information on fuel sales in Alaska. The EIA reports provide confirmation about certain types of fuels. 89 Table 7: Categories and Types of Fuel Sales Used in Department of Revenue Motor Fuel Reports Category Type of Fuel Sales Exempt [Foreign Flights Heating Fuel Bulk Sales asohol [Public Utilities State and Local Government [Federal Government Exported as Cargo Exempt Power Plants \Charitable Institutions \Consigned to Foreign Countries Losses \Other Not Categorized \Oil and Gas Operations Foreign Trade Zone Domestic Non-Alaska Air Miles \Other (Taxable viation Gas viation Jet iesel Motor Gasoline Highway Diesel Highway Gas Marine Diesel Marine Gas {Gasohol Source: Alaska Department of Revenue Motor Fuel Reports Electricity: See the Appendix of this report for sources. Use of fuels for power generation is also available through 2000 from the EIA Consumption Database and the Electric Power Annual Report. Fuel consumed by electric utilities is from EIA Form EIA- 759 “Monthly Power Plant Report.” Final Consumption: Final consumption of petroleum products is derived from Department of Revenue Motor Fuel reports. We used information from Department of Natural Resources, Division of Oil and Gas annual reports to estimate final consumption of natural gas. The consumption of coal is derived from reports from Usibelli Mine. Final consumption of electricity is based on the ISER surveys of electric utilities in the state. We used the US Energy Information Administration Petroleum Annual Report to estimate consumption of some petroleum products, including asphalt 90 ou and residual fuels. The US Energy Information Administration reports also provided information for the final consumption of wood and ethanol. Conversion Factors: The conversion factors for converting commodity units (like short tons, barrels, and cubic feet) to Btu's are from the US Energy Information Administration, which estimates conversion factors for each commodity for each state and for each year. The conversion factors we used in our calculations appear along the bottom of Table 1 and also in Table 8 below. Table 8: Conversion Factors Used to Convert Commodity Units to Btu’s |__commomty | Srcor | us| Col tf Million BTU per short ton NaturalGas | 0.781] Thousand BTU per Cubic foot Crude | 5.67 Milion BTU per barrel DistilateFuel S| 5.825] Million BTU per barrel Other Petroleum Products | 6.065] Million BTU per barrel Wood 0.020] Million Btu per thousand Cord Electricity | tT U per KWH ource: Energy Information Agency 91 APPENDICES ALASKA ELECTRIC POWER STATISTICS Appendix A. UTILITY LIST. a ra ete erence emcee sss cases ces east eee ees HOLY CROSS N N Y. = ane see rerevernstoarestrareenrnaee arcareorrreens a a AVEC COOPERATIVE, INC. HOOPER BAY N OE aeaeeeee OE ATINE, ING. cecal ccc Ocoee eee ELECTRIC = —— — = AVEC COOPERATIVE, INC. HUSUA NOUN UY. errno emer Scenes ciassbniinicee moreno ceinis asc ae so ncn oe an KALTAG Kesigtk hes sore backup capacity, primary ee 8S... wer is provided by AVEC In: Sie 2 ALASKA VILLAGE ELECTRIC AVEC COOPERATIVE, INC. ALASKA Kasigluk has some backup capacity; primary Yes_ power is provided by AVEC in Nunapitchuk. “ALASKA VILLAGE ELECTRIC” AVEC COOPERATIVE, | INC. ‘ALASKA VILLAGE ELECTRIC AVEC COOPERATIVE, INC. ALASKA VILLAGE ELECTRIC ‘ALASKA VILLAGE ELECTRIC AVEC. COOPERATIVE, INC. . MINTO N N YY ceoe Seed dL OS, ‘ALASKA VILLAGE ELECTRIC AVEC COOPERATIVE, INC. = NOORVIK N N Y anc iu 1 Yes “ALASKA VILLAGE ELECTRIC = : ‘AVEC in Nunapitchuk provides electricity to AVEC. COOPERATIVE, INC. NUNAPITCHUK Pitas Point provided power by AVEC in Si ~ “ALASKA VILLAGE ELECTRIC COOPERATIVE, INC. ALASKA VILLAGE ELECTRIC AVEC ... COOPERATIVE, INC. RUSSIAN MISSION N N Y Yd Ves ‘AVEC jin Saint Mary's provides power to = Ua 7 Seer sss ‘ALASKA VILLAGE ELECTRIC COOPERATIVE, INC. eesssee SAVOONGA NN 8 eu Yes ‘ALASKA VILLAGE ELECTRIC™ = AVEC COOPERATIVE, INC. | SELAWIK N N Y anc u_ 1 Yes ALASKA VILLAGE ELECTRIC AVEC COOPERATIVE, INC. SHISHMAREF N N Yan cu 1 Yes ALASKA VILLAGE ELECTRIC AVEC COOPERATIVE,INC. TUNUNAK NOUN UY sw oc ou 1 Yes A-2 ANOREANGF ELECTRIC CORPORATION AEC ATKA, N N Y sw 1 Yes ALUTIIQ POWER COMPANY ANDI KARLUK LIGHT AND POWER ‘COMPANY, Information from Aurora Energy LLC: capacity, = Yansedcoreeen Oren NO. 28O% SOOTMOR 208 UO URN BR ea ee BBL BBL HYDRO, INC. WHOLESALE Y Y. Y__.s¢ BEAVER VILLAGE ELECTRICAL UTILITY BEAVER: BEAVER. N BETHEL UTILITIES CORPORATION, INC. foe Bethel Uliies provides power to Nepekiek. CIRCLE HOT SPRINGS eves CENTRAL) Chitina Electric Co. reported directly: capacity, sales and fuel usage. Also reported that they nave a SSkw hyro generator that is currently es, offing but they sre looking inio repaking Information from CEA directly: breakdown of ANCHORAGE, ‘sales, purchases and generation. Values were CHUGACH | CHUGACH ELECTRIC ASSOCIATION, INC. MUNICIPALITY OF ¥ y Y_..8¢..¢ U0 No. the same as reported by EIA. CHUGACH ELECTRIC ASSOCIATION, ING. COOPER LANDING CIRCLE ELECTRIC BiBiA RICHARD CIRCLE HUTCHINSON CIRCLE. N N Y 1 ‘CLARKS CLARKS POINT, GiTY GF D/B/A CLARKS CLARK'S POINT sheen ce er casi COPPER Vailey é ELECTRIC CVEA ASSOCIATION, INC GAKONA N CVEA ASSOCIATION, INC GLENNALLEN N N Y se CVEA ASSOCIATION, INC GULKANA en a ) A-3 FALSE PASS Yes sales and fuel usage. BAY ‘GALENA GALENA, CiTY GF “GOLDEN VALLEY ELECTRIC ASSOCIATION, INC. GVEA ASSOCIATIOI GOLDEN VALLEY ELECTRIC GVEA ASSOCIATION, INC. Y Y Y. ELTA JUNCTION GOLDEN VALLEY ELECTRIC GVEA ASSOCIATION, INC. FAIRBANKS Y Y Mose YceeeEieee ct 0... .NO GOUDEN VALLEY ELECTRIC GVEA ASSOCIATION, INC. GOLDEN VALLEY ELECTRIC ASSOCIATION, INC. FORT WAINWRIGHT. ASSOCIATION, INC. GOLDEN VALLEY ELECTRIC ASSOCIATION, INC. MCKINLEY PARK | y y “""GOLOEN VALLEY ELECTRIC ASSOCIATION, INC. City of Golovin reported directly: sales and fuel usage. Capacity from EIA figures where GOLOVIN _GOLOVIN, CITY OF see GOLOVIN No N Y u__1__Yes available. del) iPNATCHIAG ELECTRIC COMPANY KAKE TRIBAL CORPO! KETCHIKAN KETCHIKAN, CITY OF “KODIAK ELECTRIC ASSOCIATION, ING.” CHINIAK A-4 KOKHANOK KOKHANOK ELECTRIC UTILITY, KOKHANOK N N KOLIGANEK KOLIGANEK VILLAGE COUNCIL ELECTRIC KOLIGANEK KOTZEBUE KOTZEBUE ELECTRIC ASSOCIATION, INC. KOTZEBUE N N el ee ee KOYUKUK, CITY OF KUIGGLUUM KALLUGVIA’ COOPERATIVE, KK INC. Kw KWIG POWER COMP, ‘TARSEN BAY LARSEN BAY ELECTRIC N N Y ui Yes LEVELOCK ELECTRIC COOPERATIVE, LECI INC. LEVELOCK LvTc LIME VILLAGE TRADITIONAL COUNCIL ~“MANOKOTAK POWER COMPANY | MATANUSKA' ELECTRIC ASSOCIATION, MEA INC. UNALAKLEET Y 7 7 ee MATANUSKA ELECTRIC ASSOCIATION, MEA INC. WASILLA, Y a Y sc ¢ ou 0 No MATANUSKA ELECTRIC ASSOCIATION, MEA INC. MLPC MCGRATH LIGHT & POWER CO. kane NATUR CONE ET anne a asneennsrenrusovarvctaniciourtoumenreneeroeretrereteete MIDDLE KUSKOKWiM ELECTRIC MKEC COOPERATIVE., INC. CHUATHBALUK vy Yee 1 Yes MIOOLE KUSKOKWIM ELECTRIC MKEC COOPERATIVE.. INC. NEA NAKNEK ELECTRIC ASSOCIATION, INC. SOUTH NAKNEK N N Y sw oc ou 1 Yes 10. Napakiak provided by. A-5 NELSON LAGOON NIKOLAI LIGHT & POWER D/B/A NiKOLAT, NORTH SLOPE BOROUGH POWER & UGHT SYSTEM D/B/A NORTH SLOPE UGHT SYSTEM D/B/A NORTH SLOPE NSPL BOROUGH ATQASUK N N Yan mou 1 Yes (UGHT SYSTEM D/B/A NORTH SLOPE NSPL BOROUGH NORTH SLOPE BOROUGH POWER & LIGHT SYSTEM D/B/A NORTH SLOPE NSPL_____BOROUGH POINT LAY NON Yan NORTH SLOPE BOROUGH POWER & LUGHT SYSTEM D/B/A NORTH SLOPE BOROUGH WAINWRIGHT N N Yan miu 1 Yes NUSHAGAK ELECTRIC & TELEPHONE PEDRO BAY VILLAGE COUNCIL ELECTRIC Information from Pedro Bay Village Council: PEDRO BAY UTILITY Capacity, sales, generation and fuel use. ‘SEWARD, CITY OF ELDON POINT ELEC Sheldon Point Electic Co. reported directiy: iui “SITKA, CITY & BOROUGH TAKOTNA __INC. TAKOTNA N N Y sw. 1 Yes iad A-6 Tera Bese cenleeeyms a) aay citvoe esmerensreed ae A. BAY THORNE BAY N ON Y se mu 1 Yes YAKUTAT, CITY OF TAT, SOC OF, AVEC reported information for all communities: capacity, generation, sales, revenue, customers ‘| MATANUSKA ELECTRIC ASSOCIATION, INC. a ALASKA ELECTRIC POWER STATISTICS Appendix B. REGIONAL MAP Arctic & Northwest ALASKA ELECTRIC POWER STATISTICS Appendix C. HYDROELECTRIC FACILITIES The reporting of installed capacity of the state hydroelectric facilities is complicated by the ownership structure of the larger units, since they have changed over time and the reporting to different entities has not always been consistent. In 2001 4 hydroelectric facilities owned by the Alaska Energy Authority (AEA) of the Alaska Industrial Development and Export Authority (AIDEA) provided power to communities in Southeast and South Central Alaska. These facilities are also commonly known as the Four Dam Pool and are currently owned by the Four Dam Pool Power Agency (FDPPA). Facility Name Communities Served Swan Lake Ketchikan Tyee Wrangell and Petersburg Terror Lake Kodiak Solomon Gulch Valdez and Glennallen In 2002 these facilities were sold by AIDEA and purchased by the utilities that had purchased their output. Also in Southeast Alaska, the Snettisham hydroelectric facility, providing power to Juneau, was owned by the federal government until the AEA took it over. It may soon be purchased by the Juneau utility. In Southcentral Alaska the largest hydroelectric facility is at Bradley Lake, owned by the AEA. The power from Bradley Lake is shared among the Railbelt utilities via the intertie according to a formal sharing agreement. Utility Share of Bradley Lake Chugach Electric Association 30.4% Anchorage Municipal Light and Power 25.9% Homer Electric Association 12.0% Matanuska Electric Association 13.8% Seward Electric Utility 01.0% Golden Valley Electric Association 16.9% The Eklutna hydroelectric facility was owned by the federal government until 1994 when it was taken over by Anchorage Municipal Light & Power. The Cooper Landing hydroelectric facility is owned and operated by Chugach Electric Association. A number of smaller hydroelectric projects, owned by individual utilities, are located across the state, mostly in Southeast Alaska. There are also some very small private facilities mostly owned by fish processors. A summary of the larger facilities serving utilities follows: Facility Installed Capacity (Mw) Bradley Lake 114 Snettisham 78.2 Eklutna 30 Swan Lake 22.4 Terror Lake 20 Tyee 20 Cooper Lake 16.7 Solomon Gulch 12 Annex Creek 3.6 Beaver Falls 5.4 Black Bear Lake 4.5 Blue Lake 6 Chester Lake 1 Goat Lake 4 Gold Creek 1.6 Green Lake 18.6 Humpback Creek fea) Ketchikan 4.2 Larson Bay 1 Pelican 7 Petersburg 2 Purple Lake 3.9 Salmon Creek 6.7 Silvis 2.1 Skagway 1 There are several owners of multiple facilities, such as the Four Dam Pool Power Agency (FDDPA), Alaska Energy Authority (AEA) and the Alaska Industrial Development and Export Authority. C-2 ALASKA ELECTRIC POWER STATISTICS Appendix D. THE RAILBELT The Alaska Railbelt is generally defined to include the cities of Anchorage and Fairbanks as well as the communities adjacent to the Alaska Railroad connecting them and the cities on the Kenai Peninsula. There are seven interconnected utilities serving the Railbelt, with a combined installed capacity of more than 65 percent of the state total, producing about 80 percent of the total electricity generated by Alaska utilities. Six of the utilities are located in the South-Central region while one, Golden Valley Electric Association, is located in the Yukon region. The seven included entities are as follows: Chugach Electric Association (CEA) Anchorage Municipality Light and Power (ML&P) Homer Electric Association (HEA) Matanuska Electric Association (MEA) Alaska Electric Generation and Transmission (AEG&T) Seward Electric Systems (SES) Golden Valley Electric Association (GVEA) CEA, the largest electric utility in the state, is responsible for close to 30 percent of the electric power generation in the state. Over 500 mega-watts (MW) installed capacity come from gas driven generators and hydroelectric power at Cooper Lake. CEA purchases power from several sources, mainly Eklutna Lake, Bradley Lake, and AEG&T. The Bradley Lake purchase includes the shares for MEA and SES as well as their own. Of their total energy accounted for, nearly 50 percent is sold for resale to other Railbelt utilities. Included in this is electricity delivered to GVEA in Fairbanks through the state Intertie system. ML&P is responsible for producing much of its own electricity, nearly eighty-five percent. The utility gets a share of the Bradley Lake output, operates and transmits the power from the Eklutna Lake hydro facility and has several generating facilities of its own. Some power is purchased from CEA as needed. HEA has a small amount of its own generation but purchases most of its power to meet customer demands. They purchase their share of the Bradley Lake output directly as well as operating and maintaining the facility under contract. The remainder of their purchased power comes through AEG&T, which is owned with MEA. MEA comprises the second half of the AEG&T cooperative. They do not generate power but purchase power to provide customers with service. Their purchases D-1 come from AEG&T, CEA and their share of the Eklutna output. CEA purchases MEA’s share of the Bradley Lake output then sells it back to them for distribution. AEG8&T is a cooperative between HEA and MEA, responsible for delivering power to the two. The cooperative purchases power from CEA in order to meet the necessary demand of the two utilities. AEG&T owns some generation equipment in Soldotna, which is operated by HEA. SES has its own backup and standby generation facility but is a primary customer of CEA. CEA purchases SES’s share of Bradley Lake output and then sells it back to them along with any other power they require. SES is dependent on CEA for all its electric power requirements. GVEA provides electric power in and around the Fairbanks area: The utility generates approximately seventy (70) percent of its total sales. The remainder of the demand is met through purchases from Aurora Energy (a private company), GVEA’s share of Bradley Lake, ML&P and CEA. The last three purchases are transmitted through the state Intertie system. ALASKA ELECTRIC POWER STATISTICS Appendix E. DATA SOURCES FOR ELECTRIC POWER STATISTICS The primary data source for the electric power statistics is the Energy Information Administration (EIA) of the United States Department of Energy. Every utility and industrial (including military) electrical generating facility in the state with a capacity greater than 1 megawatt is required to report their operating characteristics to the EIA annually, and in some instances, monthly. This information is compiled by the EIA and is available for every generating facility in the state from their website at (http://www.eia.doe.govw/). We obtained data for the years between 1996 and 2001. The forms of interest to us are the EIA 860, 861 and 906. These are forms reporting - capacity, generation, sales and revenues. The use of the EIA database was a departure from previous Alaska Electric Power Statistics reports for which the primary data source was a questionnaire sent to each Alaska utility and industrial facility. There were several reasons we chose to use the federal database for this report. First, most utilities and industrial facilities are required by law to report to the federal government each year on their activities using the EIA forms. Since this information for each utility then becomes available on the EIA website, it is redundant to collect the same information through a second questionnaire. It is much less expensive to collect the data from the EIA website than to collect it through a mailout survey. Past experience has been that it has required a very large follow-up effort to get a high response rate from the mailout questionnaire. Furthermore _ using the EIA data reduces the reporting burden placed on the utilities and industrial producers of electricity. Finally, respondents are required by law to report to the EIA and this should make the response rate high. In addition, getting generating characteristics from a single source helps to insure consistency between federal and state reports. In retrospect the use of the EIA data proved to be a good decision, although it was not without some problems. First, not all the information reported in previous versions of Alaska Electric Power Statistics was collected via the EIA forms. Second, not all Alaska generating facilities reported as required by law. Third, the smallest utilities, those with installed capacity less than 1 megawatt, were not included in the database. Fourth, reconciling the information across the different forms was sometimes difficult. And finally, the federal data was available only with a considerable time delay. The most serious problem was missing utilities and other generating units and incomplete data on reporting units. To fill in the missing data we created a comprehensive list of electric utilities using a combination of the list of utilities from the 1996 Alaska Electric Power Statistics working papers and the master utility list from the Regulatory Commission of Alaska. To fill in missing data we used the annual Power Cost Equalization Reports, Alaska Village Electric Cooperative (AVEC reports), and direct mail and phone contact to utilities and large industrial producers of electricity. Inevitably the use of multiple data sources introduced some inconsistencies in reporting, but we believe these are inconsequential. The combination of these data sources allowed us to collect information for almost all the utilities and important industrial generating facilities in the state without incurring the considerable cost of conducting a complete census of all producers. A few of the smallest utilities that were not either in the EIA database or the Power Cost Equalization database never provided information for this report although all were contacted by mail and phone. The 2001 Power Cost Equalization report provided us with data on the generation and sales (residential and commercial) of all utilities participating in the Power Cost Equalization program, including a breakdown by community for those utilities that operate in multiple communities, such as AVEC and Alaska Power Company. (The EIA data for these utilities was reported only as a total across all communities, and we used this as control totals.) For AVEC, we contacted the utility directly to obtain installed capacity for each plant as well as net generation, fuel usage and costs and sale/revenues/customers information. In this case we were able to publish information taken directly from the utility reflecting statistics from each of its service communities. E-2 Sa ALASKA ELECTRIC POWER STATISTICS Appendix F. FEDERAL FORMS We made use of 3 forms that generators of electric power in Alaska file with the US Dept of Energy, Energy Information Administration: EIA-860 Annual Electric Generator Report, completed by all electric generating plants with nameplate rating of 1 megawatt or more, contains information on capacity and types of fuel used. EIA-861 Annual Electric Power Industry Report, completed by electric industry participants including: electric utilities, wholesale power marketers, energy service providers, and electric power producers, contains information on peak, generation, sales, and revenues. EIA 906 Power Plant Report, completed by a monthly sample of electric power plants and annually by electric power plants that do not report monthly, by state and by energy source, contains information on generation by energy source. (An additional form was identified but never fully investigated to determine what information might be available not covered in the 3 EIA forms. This was FERC Form 423--Cost and Quality of Fuels for Electric Plants Database). ANNUAL ELECTRIC GENERATOR REPORT ENERAL INFORMATION: 2 PURPOSE Form EIA-860 collects data on the status of existing electric generating plants and associated equipment in the United States, and those scheduled for initial commercial operation within 5 years of the filing of this report. The data from this form appear in the EIA publications, Jnventory of Electric Utility Power Plants in the United States, Electric Power Annual, and the Annual Energy Review. The data collected on this form are used to monitor the current status and trends of the electric power industry and to evaluate the future of the industry. REQUIRED RESPONDENTS The Form EIA-860 is to be completed for all electric generating plants, which have or will have a nameplate rating of 1 megawatt (1000 kW) or more, and are operating or plan to be operating within 5 years of the year of this form. The operator (or planned operator) of jointly-owned plants should be the only respondent for those plants, SANCTIONS The timely submission of Form EIA-860 by those required to report is mandatory under Section 13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as amended. Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation, or a fine of not more than $5,000 per day for each criminal violation. The government may bring a civil action to prohibit reporting violations, which may result in a temporary restraining order or a preliminary or permanent injunction without bond. In such civil action, the court may also issue mandatory injunctions commanding any person to comply with these reporting requirements, Title 18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements as to any matter within its |_ jurisdiction. METHODS OF FILING RESPONSE Secure methods of electronically transmitting survey information are the web-based form option (Option 1). With this option, EIA uses security protocols to protect the information against unauthorized access during transmission. Facsimile and e-mail transmissions (including files attached to e-mail messages) travel over ordinary telephone lines and are not considered secure electronic methods of transmitting survey data. Option 1 is the preferred method for filing. Option 1: Submit your data electronically over the Internet using a web-based form. Log on to www.cia.doe.gov/electricity/edc for system validation instructions. Option 2: FAX your Form EIA-860 to the following FAX number: (202) 287-1960 Option 3: Mail your Form EIA-860 to the EIA at the following address: U.S. Department of Energy Energy Information Administration, EI-53 Mail Station: BG-076 (Form EIA-860) 1000 Independence Avenue, S.W. Washington, D.C. 20077-5651 Note: If you choose reporting Option 1 (Internet) or Option 2 (FAX), you are not required to submit your form by mail. Retain a completed copy of this form for your files. Respondents who designate their regional electric reliability council(s) to file on their behalf must submit Form EIA-860 data to their regional council(s) in the format prescribed by their regional council(s). Respondents who designate an agent or agents to file on their behalf should return Schedule 6, “Authorization for Reporting,” and a copy of the fully completed Form EIA-860 or the Form EIA-411, Schedule 3, “Generator Information,” to the EIA in the enclosed envelope or in an envelope using the mailing address above. The completed authorization sheet should include the name(s) of the designated agent(s), name(s) of contact person(s) at the designated agent(s), their corresponding telephone number(s), the name of the respondent (electric generating company) official authorizing the agent(s) to file, the official's title, address, telephone number, signature, and the date the form is signed. CONTACT For questions regarding the Form EJA-860 or for additional information contact: Regulated Companies: Kenneth McClevey Unregulated Companies: Betty Williams Telephone Number: (202) 287-1732 Telephone Number: (202) 287-1927 FAX Number: (202) 287-1960 FAX Number: (202) 287-1962 mail: bet neue a ov Email: kenneth.mcclevey@eia. The EIA's provi jons s for confidentiality “of the data elements are as follows: 1. The EIA is required to provide company-specific data to the Department of Justice, or to any other Federal Agency when requested for official use, which may include enforcement of Federal law. The information may also be made available, upon request, to another component of the Department of Energy (DOE); to any Committee of Congress; the General Accounting Office; or to Congressional agencies authorized by law to receive such information. A court of competent jurisdiction may obtain this information in response to an order. 2. The information will be kept confidential and not disclosed to the public to the extent that it satisfies the criteria for exemption in the Freedom of Information Act (FOIA), 5 U.S.C. §552, the DOE regulations 10 C.F.R. §1004.11, implementing the FOIA, and the Trade Secrets Act, 18 U.S.C. §1905. Upon receipt of a request for this information under the FOIA, the DOE shall make a final determination whether the information is exempt from disclosure in accordance with the procedures and criteria provided in the regulations. Respondents may be asked for additional information on how release of the designated confidential information would be likely to cause substantial competitive harm. The respondents are encouraged to provide a letter with their submission of data that explains (on an element-by-element basis) the reasons why the confidential information would be likely to cause the respondent substantial competitive harm if released to the public. The letter would be kept on file to respond to requests for the information under the FOIA. A new justification is not needed each time information is submitted on an EIA form if the justification has not changed. The information contained on Schedule 2, Latitude and Longitude; and Schedule 3, Part B, Tested Heat Rate; will be kept confidential and not disclosed to the public to the extent that it satisfies the criteria for exemption under the Freedom of Information Act (FOIA), 5 U.S.C. §552, the DOE Regulations, 10 C.F.R. §1004.11, implementing the FOIA, and the Trade Secrets Act, 18 U.S.C., §1905. The data reported on the Form EIA-860 not specifically stated in this section as moti are not Submit the completed Form EIA-860 directly to the ELA annually, on or before February 15 (for 2003 reporting year, March 28). Respondents who designate an agent or agents to file on their behalf should complete Schedule 6 and submit it directly to the EIA on or before January 15 (for 2003 reporting year, March 17)of the reporting calendar year. The submittal date of the completed Form EIA-860 by these respondents is determined by the agent(s) and takes precedence provided that date is prior to February 15 of the reporting calendar year. 1. Verify all preprinted information, including company and plant name, and plant and generator identification number. If incorrect, revise the incorrect entry and provide the correct information. State codes are two-letter U.S. Postal Service abbreviation. Provide any missing information. Typed or legible handwritten entries are acceptable. Allow the original entry to remain readable. See more specific instructions for correcting data in Schedule 2, “Power Plant Site Information,” and Schedule 3, “Generator Information.” 2. Check all data for consistency with the same or related data that appear in more than one schedule of this or other forms or reports submitted to EIA. Explain any inconsistencies under Schedule 5, “Footnotes.” 3. For planned power plants or generators, use planning data to complete the form. 4. Report in whole numbers (i.¢., no decimal points), except where explicitly instructed to report otherwise. 5. Indicate negative amounts by using a minus sign before the number. 6. Report date information as a two-digit month and four-digit year, e.g., “11 - 1980.” 7. Furnish the requested information to reflect the status of your current or planned operations as of the beginning of the reporting calendar year. If the company no longer operates a specific power plant, place an asterisk (*) before the power plant’s name in Schedule 2, and report the current operator under Schedule 5, "Footnotes.” Do not complete the form for that power plant. 8. To request additional blank schedules contact the Energy Information Administration using the contact information page i. Specific Instructions Schedule 1. Identification Respondents who designate their regional council to file on their behalf should submit changes to Schedule 1 by telephone, fax, or e-mail to ELA. 1. For line 1, Legal Name of Operator, verify the name. 2. For line 2, Current Address of Principal Business Office of Plant Operator, verify the principal name and address to which this form should be mailed. Include an attention line, room number, building designation, etc., to facilitate the future handling and processing of this form (EIA-860). 3. For line 3, Preparer's Legal Name, verify the name to which this form should be mailed if different from line 1. 4. For line 4, Current Mailing Address of Preparer's Office, verify the address to which this form should be mailed. Include an attention line, room number, building designation, etc., to facilitate the future handling and processing of this form (EIA-860), if preparer is different from operator in line 1. i 5. For line 5, Type of Reporting Entity, indicate either regulated or unregulated. See Glossary for definition of regulated and unregulated entities. 6. For line 6, If Reporting Entity is Regulated, if in line item 5, reporting entity was marked as being regulated, enter an “X” for the appropriate type of entity. Schedule 2. Power Plant Data 1. Verify or complete one section for each existing power plant and each power plant planned for initial operation within 5 years. To report a new plant or a plant that is not identified on the preprinted form, use a separate (blank) section of Schedule 2. 2. For line 1, Plant Name and Street Address, enter the name and street address of the power plant. Enter “NA 1,” “NA 2,” etc., for planned facilities that have no name(s). Each power plant must be uniquely identified. The type of plant does not need to be a part of the plant name, ¢.g., “Plant x Hydro” needs to be reported as “Plant x” only, The type of plant is recognized by the prime mover code(s) reported in Schedule 3. There may be more than one prime mover type associated with a single plant name (single site). 3. For line 2, EIA Plant Code, enter or verify the ELA Plant Code for the power plant. 4. For line 3, County Name and City Name, enter the county and city in which the plant is (will be) located. Enter “NA” for planned facilities that have not been sited. If a mobile power plant indicate with a footnote on Schedule 5. 5. For line 4, State, enter the two-letter U.S. Postal Service abbreviation for the State in which the plant is located. Enter “NA” for planned facilities for which the State has not been determined. If the State is “NA,” the county name must be “NA.” 6. For line 5, Zip Code, enter the zip code of the plant. Provide, at a minimum, the five-digit zip code; however, the nine-digit code is preferred. 7. For line 6, Latitude, enter the latitude of the plant in degrees, minutes, and seconds. it 10. i. 12. ; Specific Instructions Schedule 2. Power Plant Data (Continued) For line 7, Longitude, enter the longitude of the plant in degrees, minutes, and seconds. For line 8, NERC Region and NERC Subregion, enter the NERC region and subregion in which the plant is located. A map of the NERC regions can be found on the Internet URL: www.cia.doe.gov/cneaf/electricity/chg_str_fuel/html/fig02.html. For line 9, Name of Water Source, enter the name of the principal source from which cooling water for thermal-electric plants and water for generating power for hydroelectric plants is directly obtained. If more than one water source is (will be) used, enter the name(s) of the other sources of water under “Notes.” Enter “Municipality” if the water is from a municipality. Enter “wells” if water is from wells. Enter “NA” for planned facilities for which the water source is not known, For line 10, Primary Purpose of Facility, enter the North American Industry Classification System (NAICS) code that best describes the primary purpose of the reporting facility. For line 11, Unregulated Company Only, enter the name of the electric regulated entity with which the facility is interconnected. If not connected ~ enter "Not Connected." Schedule 3. Generator Information. Verify or complete for each existing or planned generator. Complete one column for each generator (up to three generators can be reported on one page) as determined by the following: (1) is in commercial operation (whether active or inactive), or (2) is expected to be in commercial operation within 5 years and is cither planned, under construction, or in testing stage. Do not report auxiliary generators. Multiple generators operated together (i.e., cross-compound) should be reported with one generator ID. To report a new generator, use a separate (blank) section of Schedule 3. To report a new generator that has replaced one that is no longer in service, update the status of the generator that has been replaced along with other related information (e.g., retirement date), then use a separate (blank) section of Schedule 3 to report all of the applicable data about the new generator. Each generator must be uniquely identified within a plant. The EIA cannot use the same generator ID for the new generator that was used for the generator that was replaced. Schedule 3. Generator Information, Part A. Generators For line 1, Plant Name, enter the official or legal name of the power plant as reported on Schedule 2. For line 2, ELA Plant Code, enter the EIA plant code as reported on Schedule 2. For line 3, Generator Identification, enter the unique generator identification commonly used by plant management. Generator identification can have a maximum of four characters, and should be the same identification as reported on other ELA forms to be uniquely defined within a plant. For line 4, Prime Mover, for each existing combined cycle unit, enter one of the mover codes: Prime Mover Code Prime Mover Description ~ ST Steam Turbine, including nuclear, geothermal and solar steam (does not include combined cycle) GT Combustion (Gas) Turbine (includes jet engine design) Ic Intemal Combustion Engine (diesel, piston) CA Combined Cycle Steam Part CT Combined Cycle Combustion Turbine Part (type of coal must be reported as energy source for integrated coal) cs Combined Cycle Single Shaft (combustion turbine and steam turbine share a single generator) cc Combined Cycle Total Unit (use only for plants/generators that are in planning stage, for which specific generator details cannot be provided) HY Hydraulic Turbine (includes turbines associated with delivery of water by pipeline) PS Hydraulic Turbine — Reversible (pumped storage) PV Photovoltaic WT Wind Turbine CE Compressed Air Energy Storage FC Fuel Cell oT Other NA Unknown at this time (use only for plants/generators that are in planning stage, for which specific generator details cannot be provided.) For line 5, Unit Code (Multi-generator code), identify all generators that are operated with other generators as a single unit. (Identify generators in Schedule 5, “Footnotes.”) Generators operating as a single unit should have the same four-character unit (multi-generator code) code. These generators should have a single heat rate and (aggregate) capacity reported. The four-character unit code is entered by EIA. If generators do not operate as a single unit, this space should be left blank. For line 6, Ownership, identify the ownership for each generator using the following codes: "S" for single ownership by respondent, "J" for jointly owned with another entity, or "W" for wholly owned by an entity other than respondent. iii oa Specific Instructions Schedule 3. Generator Information, Part B. Existing Generators For line 1, Maximum Generator Nameplate Capacity, report the highest value on the nameplate in megawatts rounded to the nearest tenth. For line 2, Net Capacity, enter the generator’s (unit's) summer and winter net capacities for the primary energy sources. Report in megawatts, rounded to the nearest tenth. For generators that are out of service for an extended period or on standby or have no 10 generation during the respective seasons report the estimated capacities based on historical performance. For line 3, Status Code, enter one of the following status codes: Status Code Status Code Description OP Operating - in service and producing some electricity. SB Standby - available for service but not normally used (has little or no generation during the year). os Out of service - units that could not be used for the reporting year, but are expected to be retumed to service in the future. RE Retired - no longer in service and not expected to be retumed to service. For line 4, Initial Date of Operation, enter the month and year of commercial operation. For Line 5, Retirement Date, enter the date the generator was retired in month and year format. For line 6, Tested Heat Rate, enter the tested heat rate under full load conditions for all generators that derive their energy from combustion or fission of fuel. Report the heat rate as the fuel consumed in British thermal units (Btu(s)) necessary to generate one net kilowatthour of electric energy. Report the heat rate based on the primary energy source. Report the tested heat rate under full load, not the actual heat rate, which is the quotient of the total Btu(s), consumed and total net generation. If generators are tested as a unit (not tested individually), report the same test result for each generator. For generators that are out of service for an extended period or on standby, report the heat rate based on the unit’s latest test. For Line 7, Energy Source Code(s), please specify up to 12 energy sources that the generator is capable of using to produce electricity. Enter in order of their predominance of use, where predominance is based on quantity of Btu(s) consumed. Include energy source codes(s) that the generator was capable of using, although the energy source may not have been used for electricity generation during the last 12 months. For generators that are out of service for an extended period of time or on standby, report the energy sources based on the generator’s latest operating experience. Select appropriate energy source codes from the following list. For generators driven by turbines using steam that is produced from waste heat or reject heat, report the original energy source used to produce the waste heat (reject heat). Energy Source Code Energy Source Description BIT (Anthracite Coal, Bituminous Coal) LIG Lignite Coal SUB Subbituminous Coal wc Waste/Other Coal (Anthracite Culm, Bituminous Gob, Fine Coal, Lignite Waste, Waste Coal) sc Coal-based Synfuel and include briquettes, pellets, or extrusions, which are formed by binding materials and processes that recycle material DFO Distillate Fuel Oil (includes all Diesel and No. 1, No. 2, and No. 4 Fuel Oils) JF Jet Fuel KER Kerosene RFO Residual Fuel Oil (includes No. 5.and No. 6 Fuel Oils and Bunker C Fuel Oil) ‘ wo Oil-Other and Waste Oil (Butane (Liquid), Crude Oil, Liquid Byproducts, Oil Waste, Propane (Liquid), Re-Refined Motor Oil, Sludge Oil, Tar Oil) PC Petroleum Coke NG Natural Gas BFG Blast-Furnace Gas OG Other Gas (Butane, Coal Processes, Coke-Oven, Refinery, and other processes) PG Propane NUC Nuclear (Uranium, Plutonium, Thorium) AB Agriculture Crop Byproducts/Straw/Energy Crops BLQ Black Liquor GEO Geothermal LFG Landfill Gas MSW Municipal Solid Waste OBS Other Biomass Solids (Animal Manure and Waste, Solid Byproducts, and other solid biomass not specifi ied) OBL Other Biomass Liquids (Ethanol, Fish Oil, Liquid Acetonitrile Waste, Medical Waste, Tall Oil, Waste Alcohol, and other biomass liquids not specified) OBG Other Biomass Gases (Digester Gas, Methane, and other biomass gases) OTH Other (Batteries, Chemicals, Coke Breeze, Hydrogen, Pitch, Sulfur, Tar Coal, and miscellaneous technologies) PUR Purchased Steam SLW Sludge Waste SUN Solar (Photovoltaic, Thermal) TDF Tires WAT Water (Conventional, Pumped Storage) WDS Wood/Wood Waste Solids (Paper Pellets, Railroad Ties, Utility Poles, Wood Chips, and other wood solids) WDL Wood Waste Liquids (Red Liquor, Sludge Wood, Spent Sulfite Liquor, and other wood related liquids not specified) WND Wind NA Not Available Specific Instructions ‘Schedule 3. Generator Information, Part B. Existing Generators (Continued) 8. For line 8, If Energy Source is Wind, enter the number of turbines. 9. _ For line 9, Combined Heat and Power Producer, check either "Yes" or "No". 10. For Line 10, Distributed Generator, check "Yes" if the generator is considered to be a distributed generator, and check "No" otherwise. 11. For line 11, Mode of Transportation for Fuel, enter the principal method of transportation for fuel to the plant that corresponds to the first two reported energy sources. Select from the list of codes below: Mode of Transportation Code Mode of Transportation Description cv Conveyer PL Pipeline RR Railroad TK Truck WA Water UN Unknown at this time, Schedule 3. Generator Information, Part C. Proposed Generator 1. For line 1, Maximum Generator Nameplate Capacity, enter the highest value on the nameplate in megawatts rounded to the nearest tenth. 2. For line 2 Net Capacity, enter the summer and winter capacities as specified below in megawatts rounded to the nearest tenth. [Status Code is: ‘Then Enter: TS, P, LT, U, V The capacity expected to be realized when the generator starts commercial operation. 3. ° For line 3, Status Code, enter one of the following status codes: Status Code_ Status Code Description IP Planned new generator canceled, indefinitely postponed, or no longer in resource plan TS Construction complete, but not yet in commercial operation (including lower power testing of nuclear imits) P Planned for installation but not under construction L Regulatory approval pending. Not under construction (started site preparation) T Regulatory approval received but not under construction U Under construction, less than or equal to 50 percent complete (based on construction time to date of operation) Vv Under construction, more than 50 percent complete (based on construction time to date of operation) oT Other (describe under “Notes”) 4. For Line 4, Planned Original Effective Date, enter the month and year of the original effective date that: 1) the generator was scheduled to start operation after construction is completed. (Please note that this date does not change once it has been reported the first time.) 5. For line 5, Planned Current Effective Date, enter the month and year of the current effective date that the generator is scheduled to start operation. 6. For line 6, Please Enter All Energy Source Code(s) That Pertain, using the energy source codes from Schedule 3, Part B, line 7. Enter in order of predominance of Btus. 7. For line 7, If Energy Sources is Wind, enter the number of turbines. 8. For line 8, Combined Heat and Power Producer, Check either "Yes" or "No." 9. For Line 9, Distributed Generator, check "Yes" if the generator is considered to be a distributed generator, and check "No" otherwise. 10. . For line 10, Mode of Transportation for Fuel, see instructions for Schedule 3, Part B line 11. 3, Specific Instructions. Schedule 3. Generator Information, Part D. Proposed Changes to Existing Generators For line 1, Maximum Generator Nameplate Capacity, enter the highest value on the nameplate in megawatts rounded to the nearest tenth. For line 2 Net Capacity, enter the summer and winter capacities as specified below in megawatts rounded to the nearest tenth. tus is: Then Enter: FC The change in capacity (if any) expected to be realized from the conversion to the new energy sources. A, D, RP The change in capacity (if any) expected be realized from the modification to the equipment. RA The capacity expected to be realized once the previously retired generator is reactivated. M,RT - The decrease (negative value) in capacity for the generator being deactivated or retired. For line 3, Status Code, enter one of the following status codes: Status Code FC Existing generator planned for conversion to another fuel or energy source RP Proposed for life extension or repowering A Proposed generator capability increase (rerating or relicensing) D Proposed generator capability decrease (rerating or relicensing) M Generator to be put in deactivated shutdown status RA Previously retired or deactivated generator planned for reactivation RT Existing generator scheduled for retirement co Proposed change of ownership (including change of shares of jointly-owned units) For Line 4, Planned Original Effective Date, enter the month and year of the original effective date that: 1) the generator was scheduled to start operation after modification or reactivation; 2) the change of ownership was effective; 3) the generator was scheduled for deactivated shutdown status; or 4) the generator was scheduled for retirement. (Please note that this date does not change once it has been reported the first time.) For line 5, Planned Current Effective Date, enter the month and year of the current effective date that the generator is scheduled to start operation after modification or reactivation, the month and year that the change of ownership is effective, the month and year that the generator is scheduled for deactivated shutdown status, or the month and year that the generator is scheduled for retirement. For line 6, Please Enter All Energy Source(s) That Pertain To Modification Or Change, using the energy source codes from Schedule 3, Part B, line 7. . For line 7, New Prime Mover, for existing generators with a status code of “RP”, enter the prime mover code that is applicable once the modification is complete if it will be different from the current prime mover. Use the codes for prime mover provided under “Prime Mover,” Schedule 3, Part A. Schedule 3. Generator Information, Part E. Federal Energy Regulatory Commission Generator Status Complete one schedule for each generator. Up to three generators can be reported on one page. Check the applicable response for lines 2 through 6. For line 7, Date of Sale, If Sold, enter the month and year of the sale of the generator (e.g., 12-2001). If data for line 8, are entered, Legal Name, Business Address, Contact Person, and Telephone of the Entity to Which this Facility was Sold, must be completed in Part E. vi ELECTRIC GENERATOR REPORT TINSTRUCTIONS = Specific Instructions Schedule 4. Ownership Of Generators Owned Jointly Or By Others 1. Complete a separate Schedule 4 for each existing and planned generator that is, or will be, jointly owned; each generator that the respondent operates but that is, or will be, jointly owned; and each generator that the respondent operates but is 100 percent owned by another entity. Only the current or planned operator of jointly-owned generators should complete this schedule. The total percentage of ownership must equal 100 percent. 2. For each jointly-owned generator, specify the Plant Name, EIA Plant Code, and Generator Identification, as listed on Schedule 3, Part A. 3. Enter the Owner or Participant Name and Address, in order of percentage of ownership, of cach jointly-owned generator. Enter the EIA Code for the owner, if known, otherwise leave blank. Enter the Percent Owned to two decimal places, i.e., 12.5 percent as “12.50.” If a generator is 100 percent owned by an entity other than the operator, then enter the percentage ownership as “100.00.” 4. Include any notes or comments on Schedule 5. Schedule 5. Notes This schedule provides additional space for comments. Please identify schedule and line number for each comment. Schedule 6. Authorization for Reporting Respondents have the option either to submit this schedule to the EIA or to designate an agent or agents (e.g., regional electric reliability council, North American Electric Reliability Council (NERC), or other groups) to submit this information to the EIA on its behalf. Each respondent is encouraged to designate its regional electric reliability council(s) as its agent(s) to report to the EIA on the respondent's behalf. The designated agent(s) must specify the electric generating company for which it is submitting information. The respondent (the electric generating company) has the ultimate responsibility for submitting the Form EIA-860 data or any data not submitted on its behalf by its designated agent(s). Respondents who designate an agent or agents to file on their behalf should return this completed schedule and a copy of the fully completed Form EJA-860 or the Form EIA-41 1, Schedule 3, to the EIA in the enclosed envelope or in an envelope using the mailing address above. The completed schedule should include the name(s) of the designated agent(s), name(s) of contact person(s) at the designated agent{ s), their corresponding telephone number(s), the name of the respondent (electric utility) official authorizing the agent(s) to file, the official's title, telephone number, signature, and the date the form is signed. Public reporting burden for this collection of information is estimated to average10.0 hours per response for regulated respondents and 5.0 hours per response for unregulated respondents, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data needed, and completing and reviewing the collection of information. Send comments regarding this burden estimate or any other aspect of this collection of information, including suggestions for reducing this burden, to the Energy Information Administration, Statistics and Methods Group, EI-70, 1000 Independence Avenue S.W., Forrestal Building, Washington, DC 20585-0670; and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, D.C. 20503. A person is not required to respond to the collection of information unless the form displays a valid OMB number. vii Combined Cycle: x cogeneration technology in which sdiitceal electricity is produced sequentially fon the otherwise Tost ante heat exiting from one of more gas-fired turbines. The exiting heat flow is routed to an exhaust-fired conventional boiler or to a steam turbine in the production of electricity. This process increases the efficiency of an electric generating system by tuming the rejected heat into thermal steam rather than discharging it into the atmosphere, Combined Heat and Power (CHP): A generating facility that produces electricity and another form of useful thermal energy (such as heat or steam) used for industrial, commercial, heating, or cooling purposes. To receive status as a qualifying facility (QF) under the Public Utility Regulatory Policies Act (PURPA), the facility must produce electric energy and "another form of useful thermal energy through the sequential use of energy" and meet certain ownership, operating, and efficiency criteria established by the Federal Energy Regulatory Commission (FERC).. (See the code of Federal Regulations, Title 18, Part 292.) Distributed Generator: Small, modular electricity generators sited close to the customer load — can enable utilities to defer or eliminate costly investments in transmission and distributed (T&D) system upgrades, and provide customers with better quality, more reliable energy supplies and a cleaner environment. Electric Power: The rate at which electric energy is transferred. Electric power is measured by capacity and is commonly expressed in megawatts (MW). Electricity: A form of energy characterized by the presence and motion of elementary charged particles generated by friction, induction, or chemical change. Electricity Generation: The process of producing electric energy or the amount of electric energy produced by transforming other forms of energy, commonly expressed in kilowatthours (kWh) or megawatthours (MWh). Energy Source: The primary source that provides the power that is converted to electricity through chemical, mechanical, or other means. Energy sources include coal, petroleum, and petroleum products, gas, water, uranium, wind, sunlight, geothermal, and other sources. Generator Nameplate Capacity (Installed): The maximum rated output of a generator, prime mover, or other electric power production equipment under specific conditions designated by the manufacturer. Installed generator nameplate capacity is commonly expressed in megawatts (MW) and is usually indicated ‘on a nameplate physically attached to the generator. Gross Generation: The total amount of electric energy produced by generating units and measured at the generating terminal in kilowatthours or megawatthours. Kilowatt (kW): One thousand watts. Kilowatthour (kWh): One thousand watthours. Maximum Generator Nameplate Capacity: The maximum rated output of a generator, prime mover, or other electric power production equipment under specific conditions designated by the manufacturer. Megawatt (MW): One million watts. Megawatthour (MWh): One million watthours. Net Capacity: The maximum load that a generating unit, generating station, or other electrical apparatus can carry, exclusive of station use, under specified conditions for a given period of time without exceeding approved limits of temperature and stress. Net Generation: The amount of gross generation less the electrical energy consumed at the generating station(s) for station service or auxiliaries. Note: Electricity required for pumping at pumped-storage plants is regarded as electricity for station service and is deducted from gross generation. Net Summer Capacity: The steady hourly output, which generating equipment is expected to supply to system load exclusive of auxiliary power, as demonstrated by tests at the time of summer peak demand. The summer peak period begins on June | and extends through September 30. Net Winter Capacity: The steady hourly output, which generating equipment is expected to supply to system load exclusive of auxiliary power, as demonstrated by tests at the time of winter peak demand. The winter peak period begins on December | and extends through March 31. North American Industry Classification System (NAICS): A set of codes that describes the possible purposes of a facility. Ownership: The entity or entities that own(s) the generator. Ownership may be single, joint, or held by an entity other than the respondent. Prime Mover: The motive force that drives an electric generator (e.g. steam engine, turbine, or water wheel). Qualifying Facility (QF): A cogeneration or small power production facility that meets certain ownership, operating, and efficiency criteria established by the Federal Energy Regulatory Commission (FERC) pursuant to the Public Utility Regulatory Policies Act (PURPA). (See the Code of Federal Regulations, Title 18, Part 292.) Regulated Entity: For the purpose of EIA’s data collection efforts, entities that either provide electricity within a designated franchised service area and/or file forms listed in the Code of Federal Regulations, Title 18, part 141 are considered regulated entities. This includes investor-owned electric utilities that are subject to rate regulation, municipal utilities, federal and state power authorities, and rural electric cooperatives. Facilities that qualify as CHP or small power producers under the Public Utility Regulatory Power Act (PURPA) are not considered regulated entities. Renewable Resource: An energy resource that is naturally replenishing but flow-limited. It is virtually inexhaustible in duration, but limited in the amount of energy that is available per unit of time. Renewable resources include: biomass, hydroelectric, geothermal, solar, and wind power. Tested Heat Rate: The fuel consumed in British thermal units (Btu) necessary to generate one net kilowatthour of electric energy, reported based on primary energy source under full load conditions. Reported in Btu per kilowatthour. Unit Code: Multi-generator code that identifies all generators that are operated with others as a single unit. Such generators should report a single heat rate. Unregulated Entity: For the purpose of EIA’s data collection efforts, entities that do not have a designated franchised service area and that do not file forms listed in the Code of Federal Regulations, Title 18, part 141 are considered unregulated entities. This leche qualifying CHP, qualifying small power Vili ANNUAL ELECTRIC GENERATOR REPORT NOTICE: The timely submission of F Form EIA 860 by those required to report is mandatory under Section 13(b) of the Federal Energy Administration ‘Act ‘of 1974 (FEAA) (Public Law 93-275), as amended. Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation, or a fine of not more than $5,000 per day for each criminal violation. The government may bring a civil action to prohibit reporting violations, which may result in a temporary restraining order or a preliminary or permanent injunction without bond. In such civil action, the court may also issue mandatory injunctions commanding any person to comply with these reporting requirements. A person is not required to respond to collection of information unless the form displays a valid OMB number. Data reported on Schedule 2, Latitude and Longitude; and Schedule 3, Part B, Tested Heat Rate, will be kept confidential. All other data are not confidential. Title 18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements as to any matter within its jurisdiction. RESPONSE DUE DATE: REPORT FOR: <respondent name> _<respondent id> REPORTING PERIOD: As of January 1, 2003 SURVEY CONTACTS: Persons to contact with questions about this form. Contact Person | Respondent: Title: Telephone:( ) FAX: ( ) E-mail: Contact Person 2 Supervisor: Title: 1 Legal Name of Operator 2 Current Address of Principal Business Office of Plant Operator 3 Preparer's Legal Name (if Different Than Line 1) 4 Current Address of Preparer's Office (If Different Than Line 2) 5 Type of Reporting Entity [ ] Regulated 7 {| ] Unregulated { ] Cooperative {| ] Municipal 6 alae Entity is Regulated, Check { ] Federal [ ] State ne { ] Investor Owned [ ] Other eu ANNUAL ELECTRIC GENERATOR REPORT REPORT FOR: < respondent name > <respondeat ié 1, 2003 ~PART A. PLANT (EXIST! ING "POWER PLANTS AND THOSE PLANNED FOR INITIAL COMMERCIAL OPERATION WITHIN 5 YEARS) LINE NO. 1__| Plant Name Street Address: | 2 EIA Plant Code 3 County Name City Name: I ic 4 State 5 Zip Code 6 Latitude (Degrees, Minutes, Seconds) 7 Longitude (Degrees, Minutes, Seconds) 8 NERC Region NERC Subregion 9 Name of Water Source (For Purpose of Cooling or Hydroelectric) 10 Primary Purpose of the Facility (North American Industry Classification System Code) u Unregulated Company Only (Enter the electric utility in whose service area the facility is located. If not connected to an electric utility enter "Not Connected" after utility name.) PART B. PLANT (EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL OPERATION WITHIN 5 YEARS) 1__| Plant Name [ Street Address: | 2 EIA Plant Code 3 County Name City Name: I 4 State : 5 Zip Code 6 Latitude (Degrees, Minutes, Seconds) a Longitude (Degrees, Minutes, Seconds) 8 | NERC Region En I NERC Subregion 9 Name of Water Source (For Purpose of Cooling or Hydroelectric) 10 | Primary Purpose of the Facility (North American Industry Classification System Code) il Unregulated Company Only (Enter the electric utility in whose service area the facility is located. If not connected to an electric utility enter "Not Connected" after utility name.) PART C. PLANT (EXISTING POWER PLANTS AND THOSE PLANNED FOR INITIAL OPERATION WITHIN 5 YEARS) 1 Plant Name Street Address: 2 EIA Plant Code : 3 County Name | City Name: L 4 State 5 Zip Code 6 Latitude (Degrees, Minutes, Seconds) 7. Longitude (D Minutes, Seconds) 8 NERC Region NERC Subregion 9 Name of Water Source (For Purpose of Cooling or Hydroelectric) 10 Primary Purpose of the Facility (North American Industry Classification System Code) i Unregulated Company Only (Enter the electric utility in whose service area the facility is located. If not connected to an electric utility enter "Not Connected" after utility name.) PART D. PLANT. ING POWER PLANTS AND THOSE PLANNED FOR INITIAL OPERATION WITHIN 5 YEARS) [1 _] Plant Name | Street Address: 2__| EIA Plant Code 4 3 County Name CityName: | 4 State 5 Zip Code 6 Latitude (Degrees, Minutes, Seconds) oh Longitude (Di Minutes, Seconds) 8 | NERC Region [ I NERC Subregion | 1 9 Name of Water Source (For Purpose of Cooling or Hydroelectric) _| Primary Pu: of the Facility (North American Industry Classification System Code) Unregulated Company Only (Enter the electric utility in whose service area the facility is located. If not connected to an electric utility enter "Not Connected" after utility name.) ANNUAL ELECTRIC GENERATOR REPORT REPORT FOR: <respondent name > <respondent id> REPORTING EERIOD: As of January 1, 2003 | SCHEDULE 3. GENERATO! ORMATIC (EXISTING. GENERATORS AND THOSE PLANNED FOR INITIAL COMMERCIAL LINE NO | PART A. GENERATORS (Complete One Column for Each Generator, by Plant) Plant Name EIA Plant Code Generator (a) Generator (b) Generator (c) Generator Identification Prime Mover Code Unit Code alulalw Ownership Code PART B. EXISTING GENERATORS (Complete One Column for Each Generator, by Plant) _ Maximum Generator Nameplate Capacity (Megawatts) Net Capacity | Summer (Megawatts) Winter Status Code Initial Date of Operation (Month- Year) Retirement Date (Month-Year) a Jul a fol wv Tested Heat Rate (Btu/Kilowatthour) Energy Source Code(s) in Btu Order by Predominance of use P| Bs Pale [Elo oe lel |= be = i Se] ee ae If Energy Source is Wind, Enter the Number of Turbines Combined Heat and Power Producer (Check Yes or No) [ ] Yes { ] No { ] Yes [ ]No [ ] Yes [ ]No 10 Do You Consider This to bea Distributed Generator (Check Yes or No) { 1¥es [ ] No { ] Yes [ J No [ ] Yes [ ]No 11 Mode of Transportation a. for Fuel b. PART C. PROPOSED GENERATOR (Complete One Column for Each Generator, by Plant) Maximum Generator Nameplate Capacity (Megawatts) Net Capacity | Summer (Megawatts) Winter Status Code Planned Original Effective Date _(Month-Year) Planned Current Effective Date (Month-Year) Energy Source Code(s) in Btu Order by Predominance of use c | BS Ble lo )P io | eh i? mis 3 de be |e If Energy Source is Wind (enter the number of turbines) Combined Heat and Power Producer (Check Yes or No) [ ] Yes | No { ] Yes { ]No [J No Do You Consider This to be a Distributed Generator (Check Yes or No) Mode of Transportation ta REPORT FOR: < respondent name {eponwest id> REPORTING PERIOD: As of Jam EIA Plant Code PART D. PROPOSED CHANGES TO EXISTING GENERATORS (Complete One Column for Each Generator, by Plant) Planned Original Effective Date lonth-Y ear) Planned Current Effective Date lonth-Year) a. b a. 6 Energy Source Code(s) in 2 %. Be % Btu Order by - > Predominance of use > 7 e. k. e k f. L f. L 7 New Prime Mover Code REPORT FOR: < respondent name > ORTING PERIOD: Generator Identification noe ooh Plant Name EIA Plant Code : PART E. FEDERAL ENERGY REGULATORY COMMISSION GENERATOR STATUS Federal Energy Regulatory Commission LINE GENERATOR STATUS Docket Number NO. (Check) (AP for Application Pending, N/A for Not 7 (a) Applicable ) b) Combined Heat and Power Producer Federal Energy Regulatory Commission Qualifying Cogenerator Federal Energy Regulatory Commission Qualifying Small Power Producer Federal Energy Regulatory Commission Qualifying Exempt Wholesale Generator alufalwl nr fe Other Specify: x Date of Sale, If Sold (Month-Year) Unregulated Entit 1 Generator Identification Combined Heat and Power Producer Federal Energy Regulatory Commission Qualifying Cogenerator Federal Energy Regulatory Commission Qualifying Small Power Producer Other Specify: Date of Sale, If Sold (Month-Year) 2 3 4 5 Federal Energy Regulatory Commission Qualifying Exempt Wholesale Generator 6 7 8 Generator Identification Regulated [ ] Unregulated [ ] Combined Heat and Power Producer Federal Energy Regulatory Commission Qualifying Cogenerator Federal Energy Regulatory Commission Qualifying Small Power Producer Other Specify: Date of Sale, If Sold (Month-Year) 2 3 4 5 Federal Energy Regulatory Commission Qualifying Exempt Wholesale Generator 6 ir 8 Sale to Regulated or Unregulated Entity, if Sold (Check Box) Regulated [{ ] Unregulated[{ ] Tees ee ANNUAL ELECTRIC GENERATOR REPORT | PLANT NAME (a) EIA PLANT CODE (b) GENERATOR IDENTIFICATION | JOINT OWNER NAME AND CONTACT INFORMATION (d) JOINT OWNER 1: NAME JOINT OWNER 6: NAME % OWNED (): = Ancaess AND ere) EIA CODE: JOINT OWNER 2: NAME % OWNED (c): | _ MAILING ADDRESS AND = EIA CODE EIA CODE: JOINT OWNER 3: NAME % OWNED (e): MAILING ADDRESS AND : EIA CODE EIA CODE: |_JOINT OWNER 4: NAME ; % OWNED (e): MAILING ADDRESS AND EIA CODE EIA CODE: JOINT OWNER 5: NAME % OWNED (¢): MAILING ADDRESS AND EIA CODE EIA CODE: ee | %OWNED(): |__| MAILING ADDRESS AND EIA CODE JOINT OWNER 7: NAME EIA CODE: % OWNED (¢): MAILING ADDRESS AND EIA CODE JOINT OWNER 8: NAME a | EIA CODE: MAILING ADDRESS AND %OWNED(c):| | EIA CODE JOINT OWNER 9: NAME % OWNED _ EIA CODE: MAILING ADDRESS AND EIA CODE JOINT OWNER 10: NAME a ELA CODE: % OWNED (¢): MAILING ADDRESS AND EIA CODE JOINT OWNER 11: NAME aa ee EY MAILING ADDRESS AND EIA CODE: % OWNED (¢): EIA CODE rm ANNUAL ELECTRIC GENERATOR REPORT FOR: < respondent name> __<respondent id> REPORT REPORTING PERIOD: As of January |, 2003 fenas an ee ee UCOSCHEDULE 5. FOOTNOTES 0. an SCHEDULE LINE NUMBER NUMBER NOTES (a) (b) ee Wa nd ANNUAL ELECTRIC GENERATOR REPORT The respondent authorizes the agent designated below to submit on its behalf, the Form ELA-860, Annual Electric Generator Report, to the U.S. Department of Energy. Respondents have the option either to submit this completed form to the EIA or to designate an agent or agents (¢.g., regional electric reliability council, North American Electric Reliability Council (NERC), or other groups) to submit this information to the ELA on its behalf. Each respondent is encouraged to designate its regional electric reliability council(s) as its agent(s) to report to the ELA on the respondent’s behalf. The designated agent(s) must specify the electric generator for which it is submitting information. The respondent (electric generator) has the ultimate responsibility for submitting all these data or any data not submitted on its behalf by its designated agent(s). AUTHORIZED AGENT LINE NO. 1 Agent Name 2 Agent Contact Person 3 Agent Address 4 Agent Telephone RESPONDENT AUTHORIZING OFFICIAL 5 Respondent Authorizing Official Name 6 Respondent Authorizing Official Title uf Respondent Authorizing Official Telephone 8 Respondent Authorizing Official Signature 9 Date ANNUAL ELECTRIC POWER INDUSTRY REPORT £3 yh z “* NOTICE: The timely submission of Form EIJA-861 by those required t to report is mandatory under Section 13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as amended. Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation, or a fine of not more than $5,000 per day for each criminal violation. The government may bring a civil action to prohibit reporting violations, which may result in a temporary restraining order or a preliminary or permanent injunction without bond. In such civil action, the court may also issue mandatory injunctions commanding any person to comply with these reporting requirements. A person is not required to respond to collection of information unless the form displays a valid OMB number. The data reported on the Form EIA-861 not specifically stated in this section as confidential are not considered to be confidential. Title 18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements as to any matter within its jurisdiction. SURVEY CONTACTS: Persons to contact with questions about this form. | RESPONSE DUE DATE; Please submit by April 30th, following the close of the calendar year. Contact Person 1: Title: 7 REPORT FOR (Company Name): Telephone: ( ) FAX( ) E-mail: REPORTING PERIOD: 20xx Contact Person 2: Telephone: [CATION 1 Legal Name of Industry Participant 2 Current Address of Principal Business Office 3 Preparer's Legal Name (if Different Than Line 1) Current Address of Preparer's Office 4 (if Different Than Line 2) [ ] Federal [ ] State { ] Political Subdivision { ] Municipal 5 Respondent Type (check one) { ] Municipal Marketing Authority [ ] Investor-owned { ] Cooperative [ ] Power Marketer (or Energy Service Provider) { ] Independent Power Producer or Qualifying Facility coo rot —_ ANNUAL ELECTRIC POWER INDUSTRY REPORT | REPORT FOR (Company Name) REPORTING PERIOD: [ ]ECAR [ ]) MAIN I ) SERC SPP 1 | North American Electric Reliability Council. [—"1pncot { 1MAPP fo (for power marketers, Not Applicable) { |] FRCC { ] NPCC { ) WECC { ]MaAac 2 (For EIA Use Only) Identify the North American Electric Reliability Council where you are physically located 3 Enter Control Area Operator(s) Responsible for Your Oversight 4 | Did Your Company Operate Generating Plant(s)? (check | [ — ] Yes [| No one) { ] Generation from company owned plant { ] pe distribution on other electrical Identify the Activities Your Company Was Engaged in [ | Transmission l 1 Whelesate power marketing 5 During the Year (check appropriate activities) [ 1 Buying transmission services on other [ ] Retail power marketing : electrical systems I ] prea using owned/eased electrical { ] Bundled Services (electricity plus other services) it Hi Ek Peak S: Demand Semmes Mogerntt) 6 Highest 1 fourly Electrical Peak System Deman Winter (Megawatts) Did Your Company Operate Alternative-Fueled Vehicles . During the Year? Or Does Your Company Plan to [ | Yes { ] No Operate Such Vehicles During the Coming Year? 7 Name: If "Yes", Please Provide Additional Contact Information. [“Tigje; Telephone:( ) Fax: ( ) E-mail address: | REPORT FOR (Company Name): REPORTING PERIOD: ANNUAL ELECTRIC POWER INDUSTRY REPORT Total Sources (sum of lines 1, 2, 5, 8, and 9) ae t SOURCE OF ENERGY MEGAWATTHOURS Woe DISPOSITION OF ENERGY MEGAWATTHOURS 1 Net Generation 1 Retail Sales to Ultimate Customers 2 Purchases from Electricity Suppliers 12 Sales for Resale 3 Exchanges Received (In) 13 Energy Furnished Without Charge 4 Exchanges Delivered (Out) 14 Energy Consumed By Respondent Without Charge 5 Exchanges (Net) 15 Energy Consumed by Facility (Independent Power Producer or | Qualifying Facility) 6 Wheeled Received (In) 16 Total Energy Losses (positive number) a Wheeled Delivered (Out) 8 Wheeled (Net) 9 Transmission by Others Losses (negative number) 10 17 Total Disposition (sum of lines 11, 12, 13, 14, 15, and 16) NUMBER OF CUSTOMERS BY CUSTOMER CLASS TYPE OF CUSTOMER SERVICE PROGRAMS COMMERCIAL INDUSTRIAL OTHER TOTAL STATE @) ) © @) © o Green Pricing Net Metering Green Pricing Net Metering TYPE OF OPERATING REVENUE Electric Operating Revenue From Retail Sales to Ultimate Customers (Schedule 4 , Parts A and B) Revenue From Unbundled (Delivery) Customers 2 Schedule 4, Part C) 3 Electric Operating Revenue from Sales for Resale 4 Electric Credits/Other Adjustments 5 Other Electric Operating Revenue 7 Total Electric Operating Revenue ‘sum of lines 1, 2, 3, 4, and ANNUAL ELECTRIC POWER INDUSTRY REPORT REPORT FOR (Company Name): REPORTING PERIOD: 'O ULTIMATE C RS, FULL SERVICE = 1 YER SUNDLED) = r COMMERCIAL INDUSTRIAL OTHER TOTAL (a) (b) (©) (4) (©) STATE / TERRITORY Revenue (thousand dollars) Megawatthours Sold and Delivered Number of Customers STATE L Revenue (thousand dollars) Megawatthours Sold and Delivered Number of Customers | STATE Revenue (thousand dollars) Megawatthours Sold and Delivered Number of Customers STATE | Revenue (thousand dollars) Megawatthours Sold and Delivered Number of Customers STATE Revenue (thousand dollars) Megawatthours Sold and Delivered Number of Customers F | | RESIDENTIAL (a) COMMERCIAL (b) Revenue (thousand dollars) Megawatthours Sold Number of Customers STATE | Revenue (thousand dollars) Megawatthours Sold Number of Customers fat STATE I Revenue (thousand dollars) Megawatthours Sold Number of Customers STATE Revenue (thousand dollars) Megawatthours Sold =| — Number of Customers STATE Revenue (thousand dollars) Megawatthours Sold Number of Customers ANNUAL ELECTRIC POWER INDUSTRY REPORT © Revenue (thousand dollars) Megawatthours Delivered Number of Customers STATE | Revenue (thousand dollars) Megawatthours Delivered Number of Customers STATE | Revenue (thousand dollars) Megawatthours Delivered Number of Customers STATE Revenue (thousand dollars) Megawatthours Delivered Number of Customers STATE l Revenue (thousand dollars) Megawatthours Delivered Number of Customers ANNUAL ELECTRIC POWER INDUSTRY REPORT 1 Do you have company administered Demand-Side Management [ Programs? (check Yes or No) 2 If your Demand-Side Management activities are reported on Schedule 5 of another company, identify the company. 1¥es [ ]No If you answered "No," to Line 1 or another Company Reports your Demand-Side Management Activities on their Schedule 5, do not complete the rest of this Schedule. sea Potential Peak Reduction (megawatts) Actual Peak Reduction (megawatts) Direct Costs - Load Management Indirect Costs Total Cost Ser of lines 8, 9, and 10) | Have there been any major changes to your - Demand-Side Management programs ee: jerminated programs, new information or financing programs, d ora shift to programs with dual load building objectives and energy efficiency objectives), program tracking procedures, program evaluations, or reporting { ] Yes { ]No methods that impact the demand-side management data reported on this schedule? (check Yes or No) Does your company currently have a program to increase the amount of “price responsive” customer load, (i.e., load that responds dynamically to higher or [ly [No lower prices for wholesale electricity)? (check Yes or No} j If the answer to line 13 is “Yes”, please disclose the number of participating customers by class, Residential | | Commercial | | Industrial | | Other 14 ANNUAL ELECTRIC POWER INDUSTRY REPORT REPORT FOR (Company Name): EIA ID: REPORTING PERIOD: cs If your company owns a distribution system, please identify the names of the counties (parish, etc.) by State in which the electric wire/equipment are located. STATE STATE . (U.S. POSTAL COUNTY (U.S. POSTAL COUNTY LINE | ABBREVIATION) (PARISH, ETC.) LINE | ABBREVIATION) (PARISH, ETC.) NO. (a) () NO. _) 1 20 2 1 3 2 4 23 5 24 6 25 1 6 8 27 9 28 10 29 | ll 30 | 2 a | | 13 32 | 4 33 | | 15 34 | | 16 35 | | 7 36 18 37 19 38 POWER PLANT REPORT PURPOSE Form EIA-906 collects information from all regulated and unregulated electric power plants and combined heat and power (CHP) facilities in the United States. Data collected on this form include electric power generation, fuel consumption, fuel heat content, fossil fuel stocks, and useful thermal output at combined heat and power plants. These are used to monitor the current status and trends of the electric power industry. Further information can be found at www.eia.doe.gov. REQUIRED The monthly Form EIA-906 is a sample of electric power plants and combined heat and power RESPONDENTS facilities. Electric power plants and combined heat and power facilities that are not selected to respond monthly must file annually on this form. RESPONSE DUE Monthly data are due to EIA by the 10” working day following the close of the calendar month. _— Annual data are due to EIA three weeks after the receipt of the form. METHODS OF Secure methods of electronically transmitting survey information are the web-based form FILING RESPONSE option (Option 1). With this option, EIA uses security protocols to protect the information against unauthorized access during transmission. Facsimile and e-mail transmissions (including files attached to e-mail messages) travel over ordinary telephone lines and are not considered secure electronic methods of transmitting survey data. Option 1 is the preferred method for filing. . Option 1: Submit your data electronically over the Internet using a web-based form. Log on to www.eia.doe.gov/electricity/edc for system validation instructions. Option 2: FAX your Form EIA-906 to the following FAX number: Unregulated: (202) 287-1943 or 1962 Regulated: (202) 287-1585 Option 3: Mail your Form EIA-906 to the EIA at the following address: U.S. Department of Energy Energy Information Administration, El-53 Mail Station: BG-076 (Form EIA-906) 1000 Independence Avenue, S.W. Washington, D.C. 20077-5651 Note: If you choose reporting Option 1 (Internet) or Option 2 (FAX), you are not required to submit your form by mail. Retain a completed copy of this form for your files. CONTACTS For questions regarding the Form EIA-906 or additional information contact: Unregulated: Channele Carner Regulated: Melvin E. Johnson Telephone: (202) 287-1928 ‘ Telephone: (202) 287-1754 FAX: (202) 287-1943 FAX: (202) 287-1585 Email: channele.carner@eia.doe.gov Email: melvin.johnson@eia.doe.gov | Form Approve OMB No. 1905-0 GENERAL INSTRUCTIONS roval Ex: Additional Forms. Additional copies of the form can be downloaded from the EIA web site at http:/Iwww.eia.doe.gov/cneaf/electricity/page/forms.html Data Reporting e Report data for all generators by prime mover. For example, report aggregated data for all steam turbines under ST. e Report data for all generating units that are operable, including those using renewable or alternative energy sources. e Report generation and fuel consumption for each prime mover at the plant. e Report heat content for each fuel consumed. e Report stocks and useful thermal output at the plant level. Form Revisions. Submit revisions to data previously reported as soon as possible after the error or omission is discovered. Do not wait until the next reporting month's form is due to send resubmission(s). A resubmission should be completed for each revised page. A photocopy of the original submission that clearly shows any changes to the data is acceptable. Draw a line through the incorrect data. Write the correct data above the incorrect data. The revised page will be treated as a replacement for the original page. Fax or mail one copy of the resubmission. Electronic submissions can be modified on the data entry screen. ITEM-BY-ITEM INSTRUCTIONS Page 1 Survey Contacts: Verify information, contact person(s) name, title, telephone number, fax number, and e-mail address. If incorrect, draw a line through the incorrect entry and provide the correct information. Provide any missing information. Typed or legible handwritten entries are acceptable. Electronic submissions can be modified on the data entry screen. Reporting For: Verify report month, respondent name, and address. If incorrect, draw a line through the incorrect entry and provide the correct information. State codes are two-character postal abbreviations. Provide any missing information. Typed or legible handwritten entries are acceptable. Note that respondent ID is assigned by EIA and should not be changed. Electronic submissions can be modified on the data entry screen. Respondent name, operator code, plant name, plant code, plant capacity, and state are pre- printed using data reported on Form EIA-860, “Annual Electric Generator Report.” Any changes to these data must be consistent with data reported on Form EIA-860. Operator and plant codes are assigned by EIA and can not be changed. Comments and Special Information: Use this section as space to provide data that does not fit elsewhere on the form. For example, if a plant began to use several new fuels during the month and there is not room to put them all in the blank lines provided. Also use this space to explain unusual circumstances regarding the reported data. Examples include: e Unusual occurrences that significantly altered the operations of the plant (e.g., scheduled and unscheduled outages, weather); Adjustments from the previous reporting period; Transfer of stocks or inventory adjustments; Values that had to be estimated due to equipment failure or other factors; and/or Adjustments to generators affecting maximum generator nameplate capacity. ii ITEM-BY-TEM INSTRUCTIONS Page 2 a Na respondent name and reporting period. If incorrect, draw a line eras the incorrect entry and provide the correct information. Electronic submissions can be modified on the data entry screen. Note that respondent ID is assigned by EIA and can not be altered. Type of Respondent: Indicate, by checking the appropriate space, whether the respondent is a regulated or unregulated generator. Write in the Comments Section if the plant is being transferred from a regulated to unregulated entity. Include the names of the regulated and unregulated operating companies. Plant Name: column a. Provide an explanation of name changes in the Comments Section, located on page 1 of the form. Plant ID: column b. Plant ID may not be changed. If you have questions regarding the Plant ID, please call or email the appropriate contact identified on page i. State: column c. Ifthe State listed is the incorrect location for the plant, cross out the pre- printed information. Use the U.S. Postal abbreviation to show the State in which the plant is physically located. Prime Mover Type: column d. Ifthe information is incorrect, cross through the code and provide the correct prime mover code. If you added a generator with a new prime mover code, please include it. Electronic submissions can be modified on the data entry screen. * Provide additional codes in column d if omitted from the pre-print. ¢ Provide the required information in columns e through h, and column j. ¢ Please coordinate with the Form EIA-860 data submission for your plant. Use the prime mover codes from the following list: Prime Mover Type Prime Mover Description ST Steam Turbine, including nuclear, geothermal and solar steam (does not include combined cycle) GT Combustion (Gas) Turbine (includes jet engine design) IC Internal Combustion (diesel, piston) Engine CT Combined Cycle Combustion — Turbine Part CA Combined Cycle — Steam Part cs Combined Cycle Single Shaft (combustion turbine and steam turbine share a single generator) cc Combined Cycle Total Unit — Planned plants only, for which specific generator details cannot be provided. HY Hydraulic Turbine (includes turbines associated with delivery of water by pipeline) PS Hydraulic Turbine — Reversible (pumped storage) PV Photovoltaic WT Wind Turbine CE Compressed Air Energy Storage FC Fuel Cell OT Other — Specify in Comments Section. NA Unknown at this time. Use only for plants/generators that are in planning stage, for which specific generator details cannot be provided. ul POWER PLANT REPORT Energy Source: column e. If your plant/facility uses an energy source that is not preprinted, INSTRUCTIONS provide the data for the additional energy sources in Column e. Use the Comments Section on continued page 1 if you run out of space. Include start-up and flame stabilization fuels. If the fuel codes for the plant include Other Biomass Solids, Liquids, or Gasses (OBS, OBL, or OBG codes), or the Other code (OTH), please specify the energy source in the Comments Section located on page 1 of the form. Use additional pages if necessary. If the pre-printed energy source is incorrect, please cross through the code and provide the correct code. Electronic submissions can be modified on the data entry screen. For each additional energy source provide: * Quantity consumed by prime mover in column h; « Heat content for each fuel in column j; and ¢ Stocks for coal and petroleum fuels for the entire plant in column i. iv POWER PLANT REPORT ITEM-BY-ITEM Use the following energy source codes and unit labels: pbb hiantetd a Energy Source Code Unit Label Energy Source Description BIT tons Anthracite Coal and Bituminous Coal ENERGY SOURCE LIG tons Lignite Coal CODES SUB tons Subbituminous Coal WC tons Waste/Other Coal (includes anthacite culm, bituminous gob, fine coal, lignite waste, waste coal) sc tons Coal-based Synfuel, including briquettes, pellets, or extrusions, which are formed by binding materials or processes that recycle materials PC tons Petroleum Coke AB tons Agricultural Crop Byproducts/Straw/Energy Crops BLQ tons Black Liquor MSW tons Municipal Solid Waste OBS tons Other Biomass Solids (specify in Comments) SLW tons Sludge Waste TDF tons Tire-derived Fuels WDS tons Wood/Wood Waste Solids (paper pellets, railroad ties, utility poles, wood chips, bark, and other wood waste solids) DFO barrels Distillate Fuel Oil (Diesel, No. 1, No. 2, and No. 4 Fuel Oils) JF barrels Jet Fuel KER barrels Kerosene RFO barrels Residual Fuel Oil (No. 5, No. 6 Fuel Oils, and Bunker C Fuel Oil) WO barrels Waste/Other Oil (including Crude Oil, Liquid Butane, Liquid Propane, Oil Waste, Re-Refined Motor Oil, Sludge Oil, Tar Oil, or other petroleum-based liquid wastes) OBL barrels Other Biomass Liquids (specify in Comments) WDL barrels Wood Waste Liquids excluding Black Liquor (BLQ) (includes red liquor, sludge wood, spent sulfite liquor, and other wood-based liquids) NG Mcf Natural Gas BFG Mcf Blast Furnace Gas OG Mcf Other Gas (specify in Comments) PG Mcf Gaseous Propane LFG Mcf Landfill Gas OBG Mcf Other Biomass Gas (Specify in Comments) (includes digester gas, methane, and other biomass gases) PUR MMBtu Purchased Steam WH MMBtu Waste heat not directly attributed to a fuel source. Note that WH should only be reported where the fuel source for the waste heat is undetermined, and for combined cycle steam turbines that are not supplementary fired PS WAT MWh Electricity used for pumping at a Pumped Storage Hydroelectric Facility NUC N/A Nuclear Fission (Uranium, Plutonium, Thorium) GEO N/A Geothermal SUN N/A Solar HY WAT N/A Water at a Conventional Hydroelectric Turbine WND N/A Wind OTH Specify in Comments Section Approval Expires ” POWER PLANT REPORT jee jo. 1905-012 . Maximum Generator Nameplate Capacity: column f. This column contains pre-printed data INSTRUCTIONS based on the information reported by your company on Form EIA-860, "Annual Electric continued Generator Report." If the information is incorrect, cross through the value and provide the correct value in megawatts. Electronic submissions can be modified on the data entry screen. Please coordinate with the Form EIA-860 data submission for your plant. Generation: column g. Energy Source Consumption: column h. Report a single generation value for each prime mover, regardless of the number of energy sources for that prime mover. For example, all generation from your steam turbines with multiple energy sources should be reported as one number under the primary energy source. Combined heat and power facilities should provide gross generation for each prime mover. Electric power plants should provide net generation. Data must be reported in megawatthours (MWh), rounded to whole numbers, no decimals. Enter zero when a plant has no generation for a prime mover. For electric power plants only: Note that whenever the normal station service electrical energy utilization exceeds the gross electrical output of the plant, a negative number should be reported for net generation. Indicate negative amounts by using a minus sign before the number. Combined Cycle Units: Report generation for the combustion turbine (CT) and the steam turbine (CA) separately. If multiple energy sources are used, report each energy source separately. Report supplemental firing fuels in duct burners and/or auxiliary boilers under steam turbine code (CA). Pumped Storage Plants: Report net generation as a negative number in column g and report pumping energy in megawatthours in column h. Note that the net generation is equal to gross generation minus pumping energy. Combined heat and power facilities should report all fuels consumed by the cogeneration system for all purposes — power, useful heat, and losses. See the Glossary (page viii) for definitions of combined heat and power plants, cogeneration system and consumption of energy. All other entities should be reporting fuel.used only for the production of electric power. Include start-up and flame stabilization fuels. Report actual values or, if necessary, report estimated values and state in the Comments Section (located on page 1 of the form) that the value is an estimate. Enter zero when a plant has no fuel consumption. If a prime mover uses an energy source that is not pre-printed, write in the additional fuel codes and report all fuel consumed. Please refer to the unit conversion chart (page x), when necessary, to convert your units to the required units. , Combined Cycle Units: Report generation for the combustion turbine (CT) and the steam turbine (CA) separately. If multiple energy sources are used, report each energy source separately. Report supplemental firing fuels in duct burners and/or auxiliary boilers under steam turbine code (CA). Pumped Storage Plants: Report net generation as a negative number in column g and report pumping energy in megawatthours in column h. Note that the net generation is equal to gross generation minus pumping energy. vi POWER PLANT REPORT ITEM-BY-ITEM INSTRUCTIONS continued ¢ Fuel consumption must be reported in the following units: - Solids - Tons - Liquids — Barrels - Gases — Thousands of cubic feet e See table of unit conversion factors on page x. Stocks at End of Reporting Month: column i. e Report stocks only for the following fuels: - Coal; and - Petroleum products including petroleum coke. e Include start-up and flame stabilization fuels. Make sure to report in the required units. See list of energy source codes and unit labels on page v. e Report stocks at the plant level. e Enter zero if a plant has no stocks. « Fossil fuel stocks quantities held off-site that cannot be assigned to an individual plant are to be reported as stocks held at a central storage site. Each central storage site must be reported separately. New sites should be indicated in the Comments Section, located on page 1 of the form. Heat Content Per Unit of Fuel: column j. e Enter the gross or higher heating value per unit of fuel as burned. See the glossary for the definition of higher heating value. See the table of heating value tanges for each fuel (page x). e If the fuel heat content cannot be reported "as burned," data may be obtained from the fuel supplier on an "as received” basis. If this is the case, please state so in the . Comments Section. Useful Thermal Output: column k. e This column should only be completed by combined heat and power facilities. e Useful Thermal Output (UTO) is the useful thermal energy produced by a cogeneration system that is used in a process other than the generation of electricity. UTO is measured in millions of Btus. Only combined heat and power facilities that produce both electricity and heat or steam for other purposes should report UTO data. ¢ The energy input (fuels) into a cogeneration system must equal the energy outputs (electricity, UTO, and losses). This can be expressed as: Total Energy Input in million Btus = million Btus of Fuel Consumed for Power Generation + million Btus of Useful Thermal Output + million Btus of Losses e — If not directly metered, UTO can be estimated given the heat rate of the power generation unit within the cogeneration system when treated as a stand-alone unit, and the efficiency with which the UTO is produced. Given this information, UTO can be estimated using the following equation: Total Energy Input = (Heat Rate x Kilowatthours generated) + (UTO'+ Boiler Efficiency) + Other Losses, where Total Energy Input is the combined heat value of all fuels consumed in the cogeneration system. vii | Energy | ti Form ElA-906 ae we POWER PLANT REPORT GLOSSARY Alternative Resource: A resource that the boiler is capable of burning but is not normally used. Alternative Energy Source: An energy source that is not normally used, but may be from time to time. Report consumption and heating values for all alternative energy sources actually used. Report zero when the energy source is not used. Btu: British Thermal Unit. The amount of energy required to raise the temperature of one pound of water by one degree Fahrenheit. Cogeneration: The production of electrical energy and another form of useful energy (such as heat or steam) through the sequential use of energy. Cogeneration System: A system using a common energy source to produce both electricity and steam for other uses, resulting in increased fuel efficiency. Combined Cycle: An electric generating technology in which electricity is produced from otherwise lost waste heat exiting from one or more gas (combustion) turbines. The exiting heat is routed to a conventional boiler or to a heat recovery steam generator for utilization by a steam turbine in the production of electricity. This process increases the efficiency of the electric generating unit. Combined Heat and Power (CHP): Simultaneous production of electric power and other useful thermal energy (heat) for an industrial process, heating/cooling, or steam sales. Also referred to as cogeneration. Combined Heat and Power (CHP) Plant: A plant designed to produce both heat and electricity from a single heat source. Note: This term is being used in place of the term "cogenerator" that was used by EIA in the past. CHP better describes the facilities because some of the plants included do not produce heat and power in a sequential fashion and, as a result, do not meet the legal definition of cogeneration specified in the Public Utility Regulatory Policies Act (PURPA). Consumption of Energy: The amount of a combustible fuel burned at an electric power plant or a combined heat and power plant. Also, for pumped storage facilities, the amount of pumping energy used (megawatthours), and for purchased steam or waste heat utilized, the Btu equivalent value. Consumption of Fuel: The amount of fuel used for gross generation, providing standby service, start-up and/or flame stabilization. Electric Power: The rate at which electric energy is transferred. Electric power is measured by capacity and is commonly expressed in megawatts (MW). Electricity: A form of energy characterized by the presence and motion of elementary charged particles generated by friction, induction, or chemical change. Electricity Generation: The process of producing electric energy or the amount of electric energy produced by transforming other forms of energy, commonly expressed in kilowatthours (kWh) or megawatthours (MWh). Electric Power Plant: A station containing prime movers, electric generators, and auxiliary equipment for converting mechanical, chemical, and/or fission energy into electric energy. Energy Source: Any substance or natural phenomenon that can be consumed or transformed to supply heat or power. Examples include petroleum, coal, natural gas, nuclear, biomass, electricity, wind, sunlight, geothermal, water movement, and hydrogen in fuel cells. See the list of energy sources on page v. Generator Nameplate Capacity (installed): The maximum rated output of a generator, prime mover, or other electric power production equipment under specific conditions designated by the manufacturer. Installed generator nameplate capacity is commonly expressed in megawatts and is usually indicated on a nameplate physically attached to the generator. Gross Generation: The total amount of electric energy produced by generating units and measured at the generating terminal in kilowatthours or megawatthours. Heat Content: The amount or number of British thermal units (Btu) produced by the combustion of fuel, measured in Btu/unit of measure. viii continued kilowatthour of electricity. Commonly expressed as Btu per kilowatthour. Higher (gross) Heating Value (HHV): The amount of heat produced in combustion, assuming the products (carbon dioxide and water) to be cooled to the initial temperature, so that the water is condensed to liquid. The lower heating value (LLV) is the HHV minus the latent heat of vaporization of the water. Mcf: One thousand cubic feet. MMBtu: One million Btu. Net Generation: The amount of gross generation less the electrical energy consumed at the generating station(s) for station service or auxiliaries. Note: Electricity required for pumping at pumped-storage plants is regarded as electricity for station service and is deducted from gross generation. Operable Unit: A unit that is available to provide electric power. Operating Unit: A unit that is in operation at the beginning of the reporting period. Prime Mover: The engine, turbine, water wheel, or similar machine that drives an electric generator; or, for reporting purposes, a device that converts energy to electricity directly (e.g., photovoltaic solar and fuel cells). Process Steam: Steam used at an industrial combined heat and power plant, such as paper and pulp mills, refineries, and chemical plants for manufacturing processes. Regulated Entity: For the purpose of EIA's data collection efforts, entities that either provide electricity within a designated franchised service area and/or file forms listed in the Code of Federal Regulations, Title 18, part 141 are considered regulated entities. This includes investor-owned electric utilities that are subject to rate regulation, municipal utilities, federal and state power authorities, and rural electric cooperatives. Facilities that qualify as cogenerators or small power producers under the Public Utility Regulatory Power Act (PURPA) are not considered regulated entities. Renewable Energy Resource: Energy resources that are naturally replenishing but flow- limited. They are virtually inexhaustible in duration but limited in the amount of energy that is available per unit of time. Renewable energy resources include: biomass, hydro, geothermal, solar, wind, ocean thermal, wave action, and tidal action. Self-Generator: A plant whose primary product is not electric power, but does generate electricity for its own use or for sale on the grid; for example, industrial combined heat and power plants. Start-up/Flame Stabilization Fuels: Any fuel used to initiate or sustain combustion or used to stabilize the height of flames once combustion is underway. Steam for heating/cooling: Steam produced at a combined heat and power plant for the purpose of heating and/or cooling space, such as district heating systems. Stocks of Fuel: A supply of fuel accumulated for future use. This includes coal and fuel oil stocks at the plant site, in coal cars, tanks, or barges at the plant site, or in separate storage sites. Unregulated Entity: For the purpose of EIA's data collection efforts, entities that do not have a designated franchised service area and that do not file forms listed in the Code of Federal Regulations, Title 18, part 141 are considered unregulated entities. This includes qualifying cogenerators, qualifying small power producers, and other generators that are not subject to rate regulation such as independent power producers. Useful Thermal Output: The thermal energy made available in a combined-heat-and-power system for use in any industrial or commercial process, heating or cooling application, or delivered to other end users, i.e., total thermal energy made available for processes and applications other than electrical generation. Watthour (Wh): The electrical energy unit of measure equal to one watt of power supplied to, or taken from, an electric circuit steadily for one hour. ix Form EIA-906 (2003) UNIT CONVERSION The following table provides conversion factors from common units of measure to tons, barrels CHART and thousands of cubic feet. To convert to the indicated required unit from your units, multiply by the number in the multiplier column. For example, to convert from metric tons to tons, multiply by 0.9072. Original Unit Multiplier Required Unit Thousand tons 1000 tons Metric tons 0.9072 tons Pounds 0.0005 tons Barrels Petroleum Coke 0.2 tons Thousand barrels 1000 barrels Therms (Natural Gas Only) 0.0971 thousand cubic feet (Mcf) Cubic feet 0.001 thousand cubic feet (Mcf) Million cubic feet 1000 thousand cubic feet (Mcf) Decatherms 0.971 thousand cubic feet (Mcf) Btus 0.000001 million Btu (MMBtu) Kilowatthour 0.001 megawatthour Barrels black liquor 0.231 tons black liquor Gallons black liquor 0.021 tons black liquor HEATING VALUE Fuel Type Description BTU Low BTU High RANGES AB Agricultural Byproducts/Straw/ 9.8 16.6 Energy Crops BFG Blast-Furnance Gas 0.07 0.12 BIT Bituminous Coal 20 29 BL Black Liquor 10 14 DFO Distillate Fuel Oil 55 6.2 GEO Geothermal 0 0 JF Jet Fuel 5 6 KER Kerosene 5.6 6.1 LFG Landfill Gas 0.3 0.6 LIG Lignite 55 16.6 MSW Municipal Solid Waste 9 12 NA Not Available 0 0 NG Natural Gas 0.8 vat NUC Nuclear 0 0 OBG Other BioMass Gases 0.36 1.6 OBL Other BioMass Liquids 3.5 4 OBS Other BioMass Solids 8 25 OG Other Gas 0.32 3.3 oOo Other Oil 4 5.8 OTH Other 0 0 PC Petroleum Coke 24 30 PG Propane 2.5 275) RFO Residual Fuel Oil 5.8 6.8 sc . Coal Based Synfuel 10 35 SLW Sludge Waste 10 16 SUB Subbituminous Coal 15 23 SUN Solar 0 0 TDF Tires 16 32 WAT Water 0 0 WDL Wood/Wood Waste Liquids 8 14 WDS Wood/Wood Waste Solids it 18 WH Waste Heat 0 0 WND Wind 0 0 Wo — Waste Oil 4 5.8 WOC Waste/Other Coal 5.5 30 ei SANCTIONS REPORTING BURDEN CONFIDENTIALITY The timely submission of Form EIA-906 by those required to report is mandatory under Section 13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as amended. Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation, or a fine of not more than $5,000 per day for each criminal violation. The government may bring a civil action to prohibit reporting violations, which may result in a temporary restraining order or a preliminary or permanent injunction without bond. In such civil action, the court may also issue mandatory injunctions commanding any person to comply with these reporting requirements. Title 18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements as to any matter within its jurisdiction. = Public reporting burden for this collection of information is estimated to average 1.4 hours per response for monthly respondents and 1.5 hours per response for annual respondents, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data needed, and completing and reviewing the collection of information. Send comments regarding this burden estimate or any other aspect of this collection of information, including suggestions for reducing this burden, to the Energy Information Administration, Statistics and Methods Group, El-70, 1000 Independence Avenue S.W., Forrestal Building, Washington, D.C. 20585-0670; and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, D.C. 20503. A person is not required to respond to the collection of information unless the form displays a valid OMB number. The EIA's provisions for confidentiality of the data elements are as follows: 1. The EIA is required to provide company-specific data to the Department of Justice, or to any other Federal Agency when requested for official use, which may include enforcement of Federal law. The information may also be made available, upon request, to another component of the Department of Energy (DOE); to any Committee of Congress; the General Accounting Office; or to Congressional agencies authorized by law to receive such information. A court of competent jurisdiction may obtain this information in response to an order. 2. The information will be kept confidential and not disclosed to the public to the extent that it satisfies the criteria for exemption in the Freedom of Information Act (FOIA), 5 U.S.C. §552, the DOE regulations 10 C.F.R. §1004.11, implementing the FOIA, and the Trade Secrets Act, 18 U.S.C. §1905. Upon receipt of a request for this information under the FOIA, the DOE shall make a final determination whether the information is exempt from disclosure in accordance with the procedures and criteria provided in the regulations. Respondents may be asked for additional information on how release of the designated confidential information would be likely to cause substantial competitive harm. The respondents are encouraged to provide a letter with their submission of data that explains (on an element-by-element basis) the reasons why the confidential information would be likely to cause the respondent substantial competitive harm if released to the public. The letter would be kept on file to respond to requests for the information under the FOIA. A new justification is not needed each time information is submitted on an EIA form if the justification has not changed. The information contained on this form relating to column i, Stocks at End of Reporting Period, will be kept confidential and not disclosed to the public to the extent that it satisfies the criteria for exemption under the Freedom of Information Act (FOIA), 5 U.S.C. §552, the DOE Regulations, 10 C.F.R. §1004.11, implementing the FOIA, and the Trade Secrets Act, 18 U.S.C., §1905. The data reported on the Form EIA-906 not specifically stated in this section as confidential are not considered to be confidential. xi U.S. Department of Energy Form Approved Energy Information Administration POWER PLANT REPORT OMB No. 1905-0129 Form E1A-906 (2003) Approval Expires 11/30/04 NOTICE: The timely submission of Form EIA-906 by those required to report is mandatory under Section 13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as amended. Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation, or a fine of not more than $5,000 per day for each criminal violation. The government may bring a civil action to prohibit reporting violations, which may result in a temporary restraining order or a preliminary or permanent injunction without bond. In such civil action, the court may also issue mandatory injunctions commanding any person to comply with these reporting requirements. A person is not required to respond to collection of information unless the form displays a valid OMB number. Data reported in Column i, Stocks at End of Reporting Period, will be kept confidential. All other data are not confidential. Title 18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements as to any matter within its jurisdiction. RESPONSE DUE DATE: Please submit within three weeks after the receipt of the form. SURVEY CONTACTS: Persons to contact with questions about this form. Contact Person 1: Title: Telephone: Fax: E-mail: Contact Person 2: Title: Telephone: Fax: E-mail: REPORT FOR: RESPONDENT } NAME: RESPONDENT ID: ADDRESS LINE 1: ADDRESS LINE 2: CITY: STATE: ZIPCODE: COMMENTS AND SPECIAL INFORMATION Insert below your comments and information on unusual values and special developments, such as the sale of a facility, or information that will not fit in the data entry areas. DO YOU HAVE COMMENTS, QUESTIONS, OR CONCERNS? THEN CONTACT EIA BEFORE SUBMITTING THIS FORM. Non-Regulated: Contact Channele Carner at 202-287-1928 or Channele.Carner@eia.doe.gov Regulated: Contact Melvin Johnson at 202-287-1754 or Melvin. Johnson@eia.doe.gov my t U.S. Department of Energy Form Approved Energy Information Administration POWER PLANT REPORT OMB No. 1905-0129 Form EIA-906 (2003) Approval Expires 11/30/04 RESPONDENT NAME: I RESPONDENT ID: REPORTING PERIOD: TYPE OF RESPONDENT: REGULATED GENERATOR ( ) UNREGULATED GENERATOR (__) ANNUAL SUBMISSION COGENERATORS ONLY ENERGY SOURCE USEFUL THERMAL OUTPUT FOR CONSUMED STOCKS AT PROCESSES PRIME GENERATOR DURING END OF HEAT OTHER THAN PLANT MOVER ENERGY NAMEPLATE REPORTING REPORTING | CONTENT PER POWER PLANT NAME ID STATE TYPE SOURCE CAPACITY GENERATION YEAR YEAR UNIT OF FUEL GENERATION (a) (b) (c) (d) (e) (f (g) (h) (i) @) (k) If you used Report in Cogenerators: If a pre-printed Report stocks E ll : at a fuel that is Megawatts. Report gross fuel was not used, | at the plant Reporting units: Report in million not pre- generation. enter a zero (0). | level, notatthe | sojids: Million Btu. printed, Report one (1) . i prime mover Bu per ton Report only one (1) report it in value for each Al Others: Reporting units: level. ti i value per plant. the blank prime mover. ‘eport net Solids = Tons Liquids: Million row. generation Liquids'= Barrels Btu per barrel Not sure what to associated Report in Gases = leas report? Contact: with each Macaeanbcre Thousands of Gases: MiBon prime 'g cubic feet Btu per Channele Carner reek one (1) value for thousand cubic 202-287-1928 i each prime mover feet channele.carner@ eia.doe.gov + 4 { Page of U.S. Department of Energy Form Approved Energy Information Administration POWER PLANT REPORT OMB No. 1905-0129 Form EIA-906 (2003) Approval Expires 11/30/04 NOTICE: The timely submission of Form EIA-906 by those required to report is mandatory under Section 13(b) of the Federal Energy Administration Act of 1974 (FEAA) (Public Law 93-275), as amended. Failure to respond may result in a penalty of not more than $2,750 per day for each civil violation, or a fine of not more than $5,000 per day for each criminal violation. The government may bring a civil action to prohibit reporting violations, which may result in a temporary restraining order or a preliminary or permanent injunction without bond. In such civil action, the court may also issue mandatory injunctions commanding any person to comply with these reporting requirements. A person is not required to respond to collection of information unless the form displays a valid OMB number. Data reported in Column i, Stocks at End of Reporting Period, will be kept confidential. All other data are not confidential. Title 18 U.S.C. 1001 makes it a criminal offense for any person knowingly and willingly to make to any Agency or Department of the United States any false, fictitious, or fraudulent statements as to any matter within its jurisdiction. RESPONSE DUE DATE: Please submit by the 10" working day following the close of the calendar month. SURVEY CONTACTS: Persons to contact with questions about this form. Contact Person 1: Title: Telephone: Fax: E-mail: Contact Person 2: Title: Telephone: Fax: E-mail: REPORT FOR: RESPONDENT | NAME: RESPONDENT ID: ADDRESS LINE 1: ADDRESS LINE 2: CITY: STATE: ZIPCODE: COMMENTS AND SPECIAL INFORMATION Insert below your comments and information on unusual values and special developments, such as the sale of a facility, or information that will not fit in the data entry areas. DO YOU HAVE COMMENTS, QUESTIONS, OR CONCERNS? THEN CONTACT EIA BEFORE SUBMITTING THIS FORM. Non-Regulated: Contact Channele Carner at 202-287-1928 or Channele.Carner@eia.doe.qov Regulated: Contact Melvin Johnson at 202-287-1754 or Melvin. Johnson@eia.doe.gov r r = oo U.S. Department of Energy Form Approved Energy Information Administration POWER PLANT REPORT OMB No. 1905-0129 Form EIA-906 (2003) Approval Expires 11/30/04 RESPONDENT NAME: I RESPONDENT ID: REPORTING PERIOD: TYPE OF RESPONDENT: REGULATED GENERATOR ( ) UNREGULATED GENERATOR (_ ) MONTHLY SUBMISSION COGENERATORS ONLY ENERGY SOURCE USEFUL THERMAL OUTPUT FOR CONSUMED STOCKS AT PROCESSES PRIME GENERATOR DURING END OF HEAT OTHER THAN PLANT MOVER | ENERGY NAMEPLATE REPORTING REPORTING | CONTENT PER POWER PLANT NAME ID STATE TYPE SOURCE CAPACITY GENERATION MONTH MONTH UNIT OF FUEL GENERATION (a) | () (c) (d) (e) ( (g) (h) @) 0] (k) If you used Report in Cogenerators: If a pre-printed Report stocks ° ten sorccciees a fuel that is Megawatts. Report gross fuel was not used, at the plant Reporting units: Report in million not pre- generation. enter a zero (0). | level, not at the Solids: Million Btu. printed, Report one (1) . prime mover Btu per ton Report only one (1) report it in value for each All Others: Reporting units: level. ; the blank prime mover. Report net Solids = Tons a Liquids: Million webieiper pent iow generation Liquids = Barrels Btu per barrel | Not sure what to associated Report ii Gases = aia report? Contact: with each M saatihen . Thousands of Gases: Million 7 egawatthours; bic feet Btu per Channele Carner pame one (1) value for Are Je thousand cubic | 202-287-1928 NS: each prime mover feet channele.carner@ eia.doe.gov Page of ALASKA ELECTRIC POWER STATISTICS Appendix G. DATA SOURCES FOR ENERGY BALANCE Alaska Oil and Gas Conservation Commission, 2000, 2001, and 2002 Annual Reports. Anchorage International Airport — Statistics System, Fue/ Sellers Report — Gallons Sold, FY 02, 01, 00, and 99, 2003. Booz Allen and Hamilton, Inc and Homan-McDowell, Pacific Polar Rims, and NORTEC, State of Alaska Long Term Energy Plan: Appendix, prepared for Division of Energy and Power Development, Department of Commerce and Economic Development, 1982. Department of the Army Corps of Engineers, Waterborne Commerce of the United States Calendar Year 2001: Part 4 — Waterways and Harbors Pacific Coast, Alaska, and Hawaii, 2003. Division of Oil and Gas, Department of Natural Resources, 2000 Annual Report.2000. Division of Oil and Gas, Department of Natural Resources, 2002 Annual Report Tables and Graphs Edition, December 2002. Energy Information Administration, US Department of Energy, State Energy Data 2000: Prices and Expenditures Technical Notes, 2002 Energy Information Administration, US Department of Energy, State Energy Data 2000: Consumption Technical Notes, 2002. Energy Information Administration, Office of Coal, Nuclear, Electric, and Alternate Fuels, US Department of Energy, Annual Coal Report 2001, June 2002 Energy Information Administration, Office of Oil and Gas, US Department of Energy, Petroleum Supply Annual 2001, June 2002 Energy Information Administration, Office of Oil and Gas, US Department of Energy, Fuel Oil and Kerosene Sales 2001, November 2002 G-1 Energy Information Administration, US Department of Energy, Summary Web Page of EIA Data for Alaska, http://www.eia.doe.gov/emeu/states/main_ak.html, 2003. Miller, Kent and Scott Goldsmith, Energy Consumption in Alaska: Estimate and Forecast, prepared for Division of Energy and Power Development, Alaska Department of Commerce and Economic Development, January 1977. Miller, Kent and Scott Goldsmith, Energy Intensive Industry for Alaska: Phase |: Background Data, prepared for Division of Energy and Power Development, Department of Commerce and Economic Development, April 1978. Tax Division, Alaska Department of Revenue, “Motor Fuel Exemption Activity For the Period 7/01/99 — 6/30/00.” May 2001. Tax Division, Alaska Department of Revenue, “Table 6: Taxable Motor Fuel Gallons Sold in Alaska for the Fiscal Year Ended June 30, 2000.” May 2001. http://www.tax.state.ak.us/MOTORFUEL/FY2000 motor fuel_stats.pdf US Census Division, US Census of Population 2000, Summary File 3. Usibelli Coal Mine web page http://www.usibelli.com/who.html G-2