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Alaska_Energy_Statistics_Final_Report_1960-2008_AEA_ISER_May_2011
Alaska Energy Statistics 1960-2008 By Ginny Fay, Alejandra Villalobos Melendez, Ben Saylor and Sarah Christine Gerd Institute of Social and Economic Research University of Alaska Anchorage for Alaska Energy Authority May 2011 Acknowledgments We sincerely appreciate the time and effort of numerous electric utilities, AEA program managers and staff, and many other colleagues who shared information, reviewed this report and provided valuable feedback. Suggested citation: Fay, Ginny, Alejandra Villalobos Melendez, Ben Saylor and Sarah Gerd, 2011, Alaska Energy Statistics, prepared for Alaska Energy Authority, May 2011, 184 pages. ALASKA ENERGY STATISTICS TABLE OF CONTENTS INTRODUCTION..........................................................................................................................................6 REPORTHIGHLIGHTS...............................................................................................................................8 ELECTRICPOWER STATISTICS................................................................................................................11 Part1. SUMMARY TABLES..........................................................................................................12 Table 1.a Utility Installed Capacity: by Type of Utility..................................................12 Table 1.b Utility Net Generation: by Type of Utility......................................................13 Table 1.c Utility Sales, Revenues, and Customers by Type of Utility....................14-16 Part2. ELECTRIC UTILITIES TABLES............................................................................................17 INSTALLEDCAPACITY..................................................................................................................17 Table 2.1a Installed Capacity by Prime Mover by Plant..................................................17 Table 2.1b Installed Capacity by Prime Mover (Percent Distribution)..........................32 DISPOSITION.................................................................................................................................41 Table 2.2 Net Generation and Total Disposition(MWH)..............................................41 NETGENERATION........................................................................................................................46 Table 2.3a Net Generation by Prime Mover.....................................................................46 Table 2.3b Net Generation by Fuel Type and Fuel Use...................................................56 Table 2.3c Net Generation, Fuel Use, and Fuel Cost by Plant........................................66 REVENUEAND CUSTOMERS......................................................................................................76 Table 2.4a Utility Sales, Revenue, and Customers...........................................................76 Table 2.4b Average Annual Energy Use and Cost............................................................86 Table 2.4c Pro Forma Monthly Residential Electric Bills.................................................94 Part 3. ALASKA INDUSTRIAL ELECTRICITY STATISTICS............................................................99 Table 3.1 Installed Capacity..............................................................................................99 Table3.2 Net Generation..............................................................................................100 Table3.3 Fuel Use............................................................................................................101 2 Part 4. ALASKA MILITARY ELECTRICITY STATISTICS.............................................................102 Table 4.1 Installed Capacity............................................................................................102 Table 4.2 Net Generation................................................................................................102 Part 5. ELECTRIC UTILITY HISTORICAL TABLES......................................................................103 Table 5.1 Utility Installed Capacity by Prime Mover...................................................103 Table 5.2 Utility Installed Capacity by Region..............................................................105 Table 5.3 Utility Net Generation by Fuel......................................................................107 Table 5.4 Utility Net Generation by Region..................................................................109 Table 5.5 Utility Sales, Revenue, and Customers.........................................................111 Table 5.6 Average Annual Energy Use and Cost..........................................................113 Part 6. CO2 EMISSIONS FROM ELECTRIC GENERATION.......................................................115 Table 6.1 Utility CO2 Emissions......................................................................................115 Figure 6.1 Utility Potential CO2 Reductions from Efficiency Gains ............................128 Figure 6.2 Utility Potential Fuel Energy Savings from Efficiency Gains......................128 Table 6.2 Industrial CO2 Emissions................................................................................129 Figure 6.3 Industry Potential CO2 Reductions from Efficiency Gains ........................130 Figure 6.4 Industry Potential Fuel Energy Savings from Efficiency Gains.................130 ALASKARAILBELT...............................................................................................................................131 Table 7.1 Railbelt Installed Capacity..............................................................................132 Table 7.2 Railbelt Hydroelectric Generation Plants....................................................133 Table 7.3 Hydroelectric Monthly and Annual Energy(MWh)....................................133 ALASKA RENEWABLE ENERGY..........................................................................................................134 Figure 8.1 Funding for Renewable Energy Fund Projects, by Type ............................134 Table 8.1 Four Dam Pool Hydroelectric Projects.........................................................135 Table 8.2 Bradley Lake Hydroelectric Utility Shares....................................................135 Table 8.3 Installed Hydroelectric Capacity in Alaska...................................................136 Table 8.4 Planned New Hydroelectric Capacity in Alaska..........................................137 Table 8.5 Commercial and Institutional Ground -Source Heat Pumps......................137 Table 8.6 Geothermal Electricity Production...............................................................138 Table 8.7 Community -Level Biomass Thermal Installations.......................................139 Table 8.8 Community -Level Biomass Combined Heat and Power Installations ...... 140 Table 8.9 Installed Wind Capacity..................................................................................141 3 ALASKAENERGY BALANCE...............................................................................................................142 Table 9.1 Summary of Energy Balance in Alaska (2008, Btu)...................................144 Figure9.1 Alaska Energy Flow.........................................................................................146 Figure 9.2 Composition of Total Energy Extracted.......................................................148 Figure 9.3 Utility Electricity Generation by Fuel Type..................................................148 Table 9.2 Summary of Energy Balance in Alaska (2008, Commodity Units) ............ 150 Figure 9.4 Consumption per Capita of Energy in Alaska..............................................152 Figure 9.5 Average Price of Natural Gas for All Consumers in Alaska ........................153 Figure 9.6 Average Price of Electricity for All Consumers in Alaska ...........................153 Figure 9.7 Average Price of Petroleum Products in Alaska..........................................154 Figure 9.8 Price for Electricity Over Time by Community............................................155 Figure 9.9 Price of a Gallon of Heating Oil over Time by Community ........................155 Figure 9.10 Price of a Gallon of Gasoline over Time by Community ............................156 Figure 9.11 Price of Propane over Time by Community.................................................156 Table 9.3 Percent of Housing Units within Each Region Using Each Type of Fuel..158 Figure 9.12 Percent of Housing Units within Each Region Using Each Type of Fuel..158 Table 9.4 Percent of Housing Units within Each Region with Number of Rooms ... 158 Table 9.5 Heating Degree Days in Select Places in Alaska.........................................159 Table 9.6 Conversion Factors (Commodity Units to BTU)..........................................161 APPENDICES.......................................................................................................................................162 A. Glossary of Terms...............................................................................................................162 B. Utility List............................................................................................................................170 C. Maps of Energy Regions....................................................................................................179 D. Data sources for Electric Power Statistics.......................................................................181 E. Reporting Requirements...................................................................................................183 4 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 Alaska Department of Community and Regional Affairs, Division of Energy. After the 1995 report, no further reports were published until 2003 when a report was prepared by the Institute of Social and Economic Research (ISER), University of Alaska Anchorage (UAA), with funding provided by the Alaska Energy Authority (AEA), the Regulatory Commission of Alaska (RCA), and the Denali Commission. This twenty-third edition of the Alaska Electric Energy Statistics was prepared by the Institute of Social and Economic Research. Information on utility, industry, and military electricity capacity, generation, and other characteristics was gathered primarily from reports filed with the U.S. Department of Energy (DOE), Energy Information Administration (EIA) and made available on their website. This was supplemented by data collected by the Alaska Energy Authority through the Power Cost Equalization (PCE) program and a limited number of direct contacts with electric power producers in the state. This is a similar methodology used to develop information for the 2003 report. All producers of electricity with installed capacity greater than one megawatt are required by law to report their operations to the federal government. A number of utilities in Alaska fall below that installed capacity threshold. Information for these smaller utilities came primarily from the PCE program. The installed capacity table (Table 2.1a) includes all utilities for which data are available. 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 one megawatt of installed capacity was not complete. For the first time we also used selected information from the Alaska Department of Environmental Conservation's AIRTOOLS database of stationary facilities with air emission permits to help identify industrial producers. This information allowed better identification of industrial facilities, especially if they are energy self -generators. As a result, we believe these tables contain more complete information than previous editions. In addition to the AIRTOOLS database, we attempted to fill in the blanks for the largest producers with interviews, 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 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 6 they account for the vast majority of non -utility electricity capacity and generation, they probably underestimate the true totals. The data are 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. Information is also presented by the regions used in the AEA Energy Pathway publication and by census areas. Map illustrating these regions are in Appendix C. In addition to being included in the final published report, the data tables are also available on the ISER website (http://www.iser.uaa.alaska.edu/Publications/AlaskaEnergvStatistics20ll.pdf) and the AEA website(http:/Lwww.akenerpyauthoritv.orp,/). 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. New in this report is a section on renewable energy and changes to geographic regions in which the data are presented. We also included an expanded glossary of terms. The new section added to the 2003 report that describes the production and consumption of energy, Alaska Energy Balance, was updated. It is important to note, that this publication is meant to serve as general reference and broad overview of electric power and other energy in the state. Because data comes from various sources and imperfections of the source data, the reader may find inconsistencies across different tables. Data in different tables may include different cases, or may be guided by slightly different concept definitions depending on the source. However, the authors of this report feel that the data presented provide a reasonable and valuable overview of electric power and energy across Alaska. F Summary and Highlights The purpose of this report is to present electric power and energy reference data for Alaska; it is not intended to provide detailed analysis of energy production, consumption or uses. Nevertheless, this section highlights information that may be of particular interest to the reader. Scope of Report The Alaska Energy Authority contracted with the Institute of Social and Economic Research at the University of Alaska Anchorage to prepare this report, which primarily presents 2008 data on electricity in Alaska, including summary and detailed tables showing: • Installed capacity by: ➢ type of utility, ➢ prime mover ➢ and plant • Fuel ➢ use ➢ cost ➢ CO2emissions The report also includes information on: • Net generation: ➢ type of utility ➢ prime mover ➢ and fuel type • Utility ➢ sales ➢ revenue ➢ customers ■ average annual electricity use ■ average annual electricity price • Changes in electric utility statistics over time, as far back as the early 1960s when possible • The contribution of hydropower, wind, and other renewable energy sources to generating electricity (and in a few cases also space heat) A final section of the report provides an overall picture of Alaska energy: how much energy (oil, natural gas, coal, hydroelectric, wind, and biomass) was produced in the state in 2008; how much was consumed; and how it was used (transportation, commercial, industrial, and residential uses). Report Highlights Electricity Generation and Cost • As of 2008, Alaska had about 2,155 megawatts of utility installed capacity and that year it generated over 6.5 million megawatt -hours. • Natural gas generated about 61% of electricity in Alaska in 2008, oil products 16%, hydroelectric 17%, coal 6%, and wind only about 0.1%. But that statewide picture varies sharply by region. • The Railbelt region has most of the state's population and uses most (about 80%) of the electricity. Natural gas generates most of the electricity for the Railbelt, but it also has some hydroelectricity. How Did Alaska Generate Electricity in 2008? (In Megawatt -Hours) Wind: Less than 0.1 % Oil Railbelt products Loaf 6% 16% 61°a Natural gas Southeast 11 2008 total: 6.5 Million Megawatt -Hours 8 • Many (but not all) communities in Southeast Alaska get electricity from hydroelectric facilities; some rely on diesel. • Rural communities in western and interior Alaska rely mostly on diesel to generate electricity, but wind power is being added in a growing number of rural places, financed largely by the state's Renewable Energy Fund. About 80% of wind -power capacity has been added just since 2008, and so isn't reflected in 2008 figures. • Wood generates both heat and electricity in community -level thermal facilities in about ten communities, mostly in Southeast. • The average annual residential use of electricity statewide in 2008 was about 7,700 kilowatt- hours —but that ranged from around 2,500 kilowatt-hours in places where electricity is most expensive to more than 12,000 where it is cheapest. The national average annual use is about 11,000 kilowatt-hours. Communities in Southeast Alaska that rely primarily on hydroelectric power to generate electricity have the lowest rates (as little as 10 cents per kilowatt-hour in 2008). Residents of Anchorage and other places in Southcentral Alaska that rely mostly on natural gas for generation paid around 15 cents per kilowatt hour in 2008. Alaskans in small remote rural places that rely on diesel have the most expensive electricity (from roughly 50 cents to $1 per kilowatt hour in 2008). The state subsidizes part of electricity costs in most of those communities, through the Power Cost Equalization program, but electric bills remain much higher in remote rural areas than in urban places. Energy Produced and Consumed • About 90% of the energy Alaska produced in 2008—as measured in energy -equivalent units — was crude oil. About 8% was natural gas,' 2% coal, and less than 0.5% wind and hydropower. • Total energy produced in Alaska in 2008 was almost 2,000 trillion Btus. • About 85% of the oil and a third of the coal produced in Alaska is exported, but most the natural gas is used in -state. • An estimated 444 trillion Btus of energy were consumed in Alaska in 2008, but nearly a third of that was in jet fuel —most of which is consumed not by Alaskans but by national and international passenger and cargo carriers flying into and out of Alaska's largest airport • Another third of the energy used in Alaska in 2008 was in diesel, gasoline, and other petroleum products; 11% natural gas; 5% electricity; and 2% coal. • Around 10% of the energy consumed in 2008 was used producing electricity —generating electricity in fact uses more energy than it produces in electricity. A final 10% of consumption was natural gas and coal produced in Alaska, but we weren't able to trace how it was consumed.) Energy Consumed in Alaska for Transportation, Commercial, Industrial, and Residential Uses Electricity 5% 2% Coal Natural gas Diesel, gasoline, other petroleum products Used in producing20% (excluding jet fuel) electridtyar unaccounted for 30% Jet fuel 200BTotal: 444Trillion Btus SoumecAedwr estimates Energy Produced in Alaska coal Hydro/wind/wood 2%/ Less than1% Natural gas* Crude Oil and NGLs 88% 2008 Total: 1,726 Trillion Btus •Indudes onlygwwW on themarkg adudes3.109 trnNws BTUs ofNurth slope gas idnje WIrtotlmWuuWand2%trilonBnisusedfwNoahSlopeopeatlons. Source AuthodeWmaaes 1 That figure for natural gas produced does not include large quantities of natural gas that are extracted along with oil on the North Slope but are reinjected into the ground to increase oil production. 9 Changes in Energy Use and Prices The table below shows per capita use of energy, by type, in Alaska in 1960 (or in 1975, if earlier data are not available) and 2008. Keep in mind that the population of Alaska tripled during that time, growing from 226,000 to 682,000. The figures may reflect not only shifts in the amounts of energy used per resident, but also whether the supply of specific energy types kept pace with a growing population. For example, although hydropower still generates only a small share of electricity in Alaska, per capita use of hydroelectricity increased even as the population grew —indicating that construction of hydropower facilities kept up with population growth. The biggest change was the huge increase in per capita use of natural gas. It was only after 1960 that natural gas from Cook Inlet became available in Southcentral Alaska, and today that gas is used to generate electricity for Anchorage and the Railbelt south of the Alaska Range. Jet fuel use in Alaska also increased sharply, as the number of flights into and out of the state increased. Per capita consumption of diesel and gasoline was also up sharply —but use of electricity actually declined, possibly reflecting increased energy efficiency. The second table shows changing energy prices since 1970, taking into account the effects of inflation. The real (inflation -adjusted) price of almost all energy types is up, but of particular importance for rural Alaskans is the near quadrupling of diesel prices. The real price of electricity actually dropped nearly 15 percent, possibly because natural gas and to a much smaller extent hydropower replaced some of the diesel previously used to generate electricity. Alaska Per Capita Annual Energy Use, 1960 and 2008 Category 1960 2008 P�Change entage Population 226,000 681,977 202% Natural Gas (Mcf) 9 --- 491------------- 5,504%_ ------------------------------ Coal(ShortTons)--------- 2----------- 1 ------------------ 32%-- Distillate Fuel (Gallons) 490 793 62% ----------------------------------------------------------------- - Jet Fuel (Gallons) 348 1,467 --------------- 321% Motor Gasoline (Gallons) ______________308 _______410 33% _ Other Petroleum - - Products (Gallons) 344 339 -1% ---------------------------------------------------------------------------------------------------- Electricity from Hydro (kWh) 1975 1,553 1,719 11% ------------------------------------------------- ------------------------- Electricity from all sources (kWh) 1975 10,009 9,555 -5% Change in Energy Prices, 2008 Dollars 1970 1 2010 Percentage I Energy Type Nominal $ 2008 $ 2008$ Change Electricity (per kWh) ----------------------- 0.03 - ---- $0.17 - ------ $0.15 ----------------- -14% --- Natural Gas (per Mcf) -----.. 0.69 --------------------------- $3.82 $6.88 ----------- 80% -------- ----- ------------------- Distillate Fuel (per gallon) - - 0.16 ------------------------------------ $0.89 $3.91 341% Jet Fuel (per gallon) - - --------------- 0.10 ----------------------------------------- $0.55 $3.03 0 455/ Motor Gasoline (per gallon) 0.40 $2.21 $3.65 65% 10 ELECTRIC POWER STATISTICS 11 Electric Utilities Summary Tables Table la. Installed Capacity (KW), 2008 By Major Geographic Regions Region Non PCE PCEO) Total Percent of Total Arctic Northwest 22,207 83,197 105,404 _ ______5%0_ South Central 1,194,130 16,731 1,210,861 56% South East 364,840 46,490 411,330 19%a South West ---------------------------------------------------------------------------------------------------- 1,737 84,725 86,462 4% Yukon 305,382 35,800 341,182 16% Total 1,888,296 266,943 2,155,239 100% By AEA Energy Regions AEA EneM Regions Non PCE PCEO) Total Percent of Total Aleutians 24,245 24,245 1 %_ Bering Straits 34,312 34,312 2%0 _ Bristol Bay ----------------------------------------------------- 237 26,911 27,148 --------------------------------- 1% Copper River/Chugach 34,900 14,005 48,905 2% _ Kodiak_____-___--__________________________ _____ _ 2,726 56,156 _-_-___3% _ Lower Yukon-Kuskokwirn 1,500 48,432 49,932 2% North Slope 20,300---- 18,700____________ _______ ____ __________2% Northwest Arctic ---------------------------------------------------------------------------- 1,907 30,185 32,092 ------- _ _ _ _ _ _ _ _ _ _ _ 1 %o Railbelt 1,410,000 1,410,000 65% Southeast ----------------------- - 364,840 - 46,490 411,330 19% ----------------------- Yukon-Ko ukuk/U erTanana 1,182 20,937 22,119 1% Total 1,888,296 266,943 2,155,239 100% (1)PCE and Non-PCE categories are based on utility status and not customers. Highlights • Railbelt hydroelectric installed capacity is 13% of the Railbelt total Hydroelectric installed capacity is 20% of the statewide total • Railbelt total installed capacity is 65% of the statewide total Railbelt Hydroelectric: 185 MW Railbelt Total: 1,410 MW Alaska Hydroelectric: 440 MW Alaska Total: Z 155 MW 12 Table 1b. Net Generation (MWh), 2008 By Major Geographic Regions Region Non-PCE PCE Total Percent of Total Arctic Northwest ------------------------ -------- 50,410 ------------------ 124,595 ----------------------------------------- 175,005 3% South Central 4,486,658 28,118 4,514,776 69% South East 641,318 32,961 674,279 ----------------------- 10% South West ------------------------------- 2,140 ------------ ---------------------------------------------- 176,453 178,593 3/ Yukon 916,668 57,967 974,635 15% Total 6,097,194 420,094 6,517,288 100% By AEA Energy Regions Region Non-PCE PCE Total Percent of Total Aleutians 51,757 51,757 1% ---- BeringStraits---------------- 60,511 60,511 ___1%_ Bo--------------- 556 54,023 54,579 ------------ 1% Copper River/Chugach - - 79,675 27,263 ---------------- 106,938 2% Kodiak -------------------------------------- 142,178 ------------ 1,660 ------------------------------------------ 143,838 2% LowerYukon-Kuskokwim 1,584 91,590 93,175 1% North Slope ------------------------------------------- 47,412 ----------- 29,913 ----------------------------------------- 77,325 1% Northwest Arctic 2,998 34,171 37,169 1% Railbelt --------------------------------------- 5,180,388 ------------ ----------------------------------------- 5,180,388 79% Southeast ----------------------------------------------------------------- 641,318 32,961 674,279 -------- 10% Yukon-Koyukuk/Upper Tanana 1,085 36,244 37,329 1% _Total 6,097,194 420,094 6,517,288 100% (1)PCE and Non-PCE categories are based on utility status and not customers. Highlights • Railbelt hydroelectric net generation is 7% of the Railbelt total • Hydroelectric net generation is 17% of the statewide total • Railbelt total net generation is 79% of the statewide total Railbelt Hydroelectric: 361,000 MWh Railbelt Total: 5,180,000 MWh Alaska Hydroelectric: 1,133,000 MWh Alaska Total. 6,517,000 MWh 13 Table 1c. Sales (MWh), 2008 By Major Geographic Region Region Non-PCE PCE Total Percent of Total Arctic Northwest - - ------------------------------------------------------------------------ 135,497 30,701 166,198 3% South Central .-------------- 3,834,289 5,845 3,840,134 61% South East -- -.----------------------- 713,009 ------- 24,897 737,907 12% South West ---------------- - 126,860 44,889 171,749 3% Yukon 1,369,388 20,213 1,389,601 22% Total 6,179,043 126,545 6,305,589 100% By AEA Energy Region Region Non-PCE PCE Total Percent of Total Aleutians 44,588 8,108 52,696 1% Bering Straits ---------- 39,988 17,536 57,523 1% Bristol Bay 37,369 14,046 51,415 1% Copper River/Chugach -- 19,908 - 5,416 - - 25,324 0% --------------------- Kodiak --------------------------------- ---- - 137,395 780 138,175 2% Lower Yukon-Kuskokwim ----------------------------------------- 56,628 . -.- -- 30,686 -- - 87,314 1% NorthSlope 73,941 73,941 _-____ 1%_ Northwest Arctic -------------------------- ---------------------------------------- 21,568 13,165 34,733 ------------------------ 1% __Railbelt____________________-------- - ------------------- Southeast ------------------------- 713,009 24,897 737,907 12% Yukon-Koyukuk/Upper Tanana 22,393 11,911 34,304 1% Total 6,179,043 126,545 6,305,589 100% 14 Table 1c. Revenue ($000), 2008 By Major Geographic Region Non- Percent of Region PCE PCE Total Total Arctic Northwest ------------------------ --------------------------------------------------------- 37,938 13,485 51,424 5% South Central ---------------------------------------- 467,294 2,303 469,597 ------------------ 50% South East 91,153 8,433 99,586 11% South West ---------------------------------------------------------------------------------- 60,084 21,694 81,777 9% Yukon 230,293 10,559 240,852 26% Total 886,761 56,473 943,235 100% By AEA Energy Region Non- Percent of Region PCE PCE Total Total Aleutians 21,057 3,846 24,903 3% Bering Straits 15,253 7,148 22,400 2% Bristol Bay 16,024 6,010 22,033 2% Copper River/Chugach ...................... 7,829 2,183 --------------- 10,011 1% Kodiak - -------------------------------------------------------------------------------- 25,051 352 25,403 3% Lower Yukon-Kuskokwim 28,957 15,924 44,882 5% North Slope------------------ -- 12,158 ---------- 12,158---------------1%.- Northwest Arctic ---------------------------------------------------------------------------------- 10,528 6,338 16,865 2% Railbelt ---------------------------------------------------------------------------------- 647,115 647,115 69% Southeast -------------------------------------------------------------------------- 91,153 8,433 99,586 11% Yukon-Koyukuk/Upper Tanana 11,637 6,241 17,878 2% Total 886,761 56,473 943,235 100% 15 Table 1c. Customers (Accounts), 2008 Table 1c. Customers (Accounts) By Maior Geoaraphic Region Non- Percent of Region PCE PCE Total Total Arctic Northwest 5,061 5,326 10,387 3% South Central 2042381 1,134 205,515 64% South East --------------------- - 35,431 5,110 40,541 13% South West ------------------------------------------- 4,864 9,145 14,009 - - 4% Yukon 45,126 4,980 50,106 16% Total 294,863 25,695 320,558 100% By AEA's Enerav Reoion Non- Percent of Region PCE PCE Total Total Aleutians --- ----------------------------------------------- 882 1,722 2,604 -------------------------- 1% Straits Bering -----__ _ __-_______________902___3,--- _ _4,252 ___________-_1% Bristol_Bay 1,715 2,784 4,499 1% Copp!rRiver/Chugach_ _ _____743 1012 _1,755 --------------- 1%0_ Kodiak ---------------------- --- 5,925 -------- 230 6,155 2% Lower Yukon-Kuskokwim ---- ..._..-------------- ------------------------ 2,558 6,319 8,876 3% NorthSlope------------------------ 3,693--------------- 3,693 1% NoArctic 466 1,976 2,442 1 % Railbelt ----------------------------------------------------- 241,290 241,290 ____ ___ ___75%0__ Southeast ---------------------------------- 35,431 - 5,110 40,541 - 13% Yukon-Ko ukuk/U erTanana 1,259 3,191 4,450 1% Total 294,863 25,695 320,558 100% 16 Vf W J m Lr r D _U W J W N H a a 9 U Eo a U m 0 w d c_ d E C N �, F U qi �; N; Vim; T M N r1i S N R Nr r N. c y U to M , cor O Mr U U to -4-; o; 'm •2 O q N o00; tir N� c�p� Cl) E c o o y Lo � � F ar o 0 0 0 C N COO rr or Al co ?`+ m O' t0. 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C �' Lr b' L; N• N' tN6' R' 2' C' R' �, a' ' O,; C' C E; nr R X, �; C U, U, U, M 0) Tahlp 2.4c Pro Forma Monthlv Resident Electric Bills. 2008 Utility Name Community $IkWh before 250 kWh $ per month 500 kWh $ per month 750 kWh $ per month 1000 kWh $ per month Source PCE* State 0.16 39 79 118 157 -_Arctic Northwest------------- ------------ 0:35.._..------------------ -- ------ -----------------15 --- South Central Central--------------------------------------------------- 0.------------36-- -- - 73 - --- 1� South East .------------------------------------------------------0.14----------3-----------?1---- 106 141 -South West --------- -------------------------------------- 0.48--------- 121--------- 241--------- 362--------- 483---- Yukon 0.21 51 103 154 205 Arctic Northwest 0.35 87 174 261 348 Alaska Village Electric Coop Ambler ------- - 0.81 203 407 610 813 PCE Alaska Village Electric Coop Brevig Mission 0.51 128 256 383 511 PCE Alaska Village Electric Coop Elim 0.50 125 250 376 501 PCE Alaska Village Electric Coop _ _ Gambell 0.53 132 265 3- - - _ _ . - -PCE Alaska Village Electric Coop -------- Kiana ---- - 0.57 142 283 425. -. _ _ 566 PCE Alaska Village Electric Coop _ - - _ Ki - - - _ _ _ _ _ _ -0.57 _ _ _ - - - _ _ _ - _ _ _ - _ - - 429 _573------PCE Alaska ----llage----Electric ---- -- Kobuk _______ -____0.5-________128______---257_-_____385_______________-_PCE 514 Alaska Village Electric Coop, Noatak --------- 0.74 ------- 186 372 558 744 _ PCE Alaska Villa9e Electric Coop Noorvik 0.57 143 _ _ _ _ - _ - _ _ _ 430 _ _ _ _ _ 573 PCE Alaska Village Electric Coop_......... Saint Michael _ _ _ _ _ - - _ _ - 0.- - _ _ _ _ _ _ _ _ - - 252 _ _ _ _ - - 377 50-- PCE Alaska Village Electric Coop Savoonga 0.52 131 262 393 524 PCE Alaska Village Electric Coop_ - _ _ _ Selawik 0.54 135 271 406 542 PCE Ala§4VillageElectricCoop ______________ Shaktoolik ______--__-___0.50--_-_-_ -125--------- 249--------- 374------- __498 PCE Naska Village Electric Coop_ _ _ _ _ _ _ _ _ _ _ _ _ Shishmaref _ _ _ _ _ _ - _ _ _ _ 0.48--------- 119 - - _ _ _ 238 357 476 PCE Alaska Vllage Electric Coop Shungnak 0.73 182 365 547 730 PCE Alaska Villa9e Electric Coop Stebbins 0.52 130 _ _ _ -- _ _ _ 391 521 PCE Alaska VillageElectncCoop Teller___ _____ ___ ________ _ _i4- -__297 ____446 ____ - - PCE Alaska Village Electric Coop, Wales -- 0.53 132 263 395 526 PCE Barrow Utils8&ElectCoop_lnc ________ Barrow ----- 0.13 __--__--32 ____63 __ ---- 95..... _--- 126------- EIA Cityof 6uckland C/0 -- -- Buckland 0.46 116 _ 232 348 464 PCE City of White Mountain White Mountain ---- -------- 0.72 180 360 540 720 PCE Diomede Joint Utilities Diomede ____________----0.-- ____150.____-__300-____-______ ________600_____PCE Golovin Power Utilities ---------- ---._..-- -- ---- Golovin 0.58 145 290_ 435 580 PCE Ipnatchiag Electric Company Deering 0.63 158 316 474 632 PCE KobukVallegElectricCompany Kobuk ___Q0.72 ______181________-----___-___- _____--_724_ __ PCE Kotzebue Electric Association Kotzebue - - ------- 0.39 - - 98 196 293 391 PCE NomeJointUtilitySystem___________ ___ _ Nome.____________ ______0.33, 83 167 250 334 PCE North Slope Borough _ _ _ Ana ktuvuk Pass _ _ _ - _0.15_ _ _ _ _ _ _ ..38 _ _ _ _ _ _ _ _ 75_ 113 _ _ _ _ _ _ _ 150------- PCE North_Slope Borough _ _ _ _ _ Atgasuk 0.15 38 75 113 150 PCE North Slope Borough______________ Kaktovik_____ ------------- 0.15---------- 38--------- 75 113---------- 150_____ PCE North Slope Borough 0.15 _ _ 38 75 1- - _ _ _ 150- _ _ - -PCE _ North Slope Borough �Pqiqt Hope 0.15 38 75 113 - - -- _ - _PCE-. 94 Table 2.4c Pro Forma Monthly Resident Electric Bills, 2008 Utility Name Community $/kWh before 250 kWh $ 500 kWh $ 750 kWh $ 1000 kWh $ Source PCE" per month per month per month per month „North Slope Borough. _ _ North Slope Borough ... .... Point,Lay................. 0.15 38 75 113 150 PCE Wainwright 0.15 38 75 113 150 PCE Unalakleet Valley Electric Unalakleet 0.38 96 191 287 383 PCE South Central 0.15 36 73 109 145 P ska Village Electric Coop_ _ _ _ _ _ _ _ _ - _ - _ Old Harbor 0.50 124 248 372 496 PCE Alutiiq!!9 erCompany--------------------- Karluk --------------------- 0.60 ____ -150_________300 --------- 450--------- 600 PCE Anchorage Muniapal Light & Power _ _ _ _ _ _ _ MULTIPLE 0.10 26 -------- 52---------- 78- 104 EIA . Chenega lra Council _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Chenepa Bay ..... 0.43 108 217_ 325 . _ 434 PCE Chitina Electric Inc - - - -------------------------- Chitina --------------------- 0.56 ----------- 141 --------- 282 ---------- 423 --------- 564 -------.--.. PCE Chugach Electric Assn Inc________________ MULTIPLE ----------------- 0.14 36___ ___ _72_________107 ------ 143------- EIA gix9!Ouzinkie Ouzinkie 0.37 92 184 276 368 PCE --P_. Copper ValleyEIecAssnInc MULTIPLE 0.24 61 122 184 245 EIA Cordova Electric Cordova 0.38 94 188 282 376 PCE Homer Electric Assn Inc MULTIPLE 0.17 42 83 125 166 EIA Kodiak Electric Assn Inc MULTIPLE 0.19 48 96 144 192 EIA _Larsen Bay Utility Company_ _ Larsen Bay .......... 0.40 100 200_ 300 400 PCE Matanuska Electric Assn Inc MULTIPLE 0.14 36 71 107 143 EIA Seward Cityof----------------------_---Seward-------------------0.16-----_----4U----------81 6 1-- - EI A EI----------------- Tatitlek Village Ira Council Tatitlek 0.43 108 215 323 430 PCE South East 0.14 35 71 106 141 Alaska Electric Li ht & Power Co g - -- --------------------------------•-------- MULTIPLE 0.15 38 76_ 114 152 ---------- EIA Alaska Power &Telephone Company _ _ _ _ _ _ _ _ Coffman Cove 0.56 140 280 420 561 PCE Alaska Power &Telephone company_ Cram 0.23 58 116 174 232 -- - --------- PCE Alaska Power &Telephone Company _ _ Haines 0.22 54 ----- -- 108 162 -------------------- 217 PCE AlaskaPower&TelephoneCompany _______ Hollis___________________ 0.23---------- 58--------- 116--------- 174 --------- 232------- PCE Alaska Power & Telephone company _____ _ Hydaburg_________________ 0.23______-__ 57_________114____ ____171________-228------ PCE Alaska Power & Telephone Company Klawock 0.23 58 116 174 232 PCE Alaska Power & Telephone Company Naukati Bay 0.57 142 284 427 569 PCE Alaska Power& Telephone Company _......... Skagway------------------ 0.21 ---------- 54--------- 107--------- 161--------- 214 PCE Alaska Power&TelephoneCompany......... ThomeBay----------------- 0.23---------- 57--------- 114--------- 171 --------- 228------- PCE Alaska ----er &TelephoneCompany__ _ _Whale Pass______________ 0.58--------- 144--------- 288 432____ 577 PCE Cityofersbur-g___________ __________Petersb Pet urg----------------- 0.10---------- 25---------- 51 76 102 EIA Ciiy of Tenakee Springs Tenakee Springs 0.50 ------------------------------- 125 249 374 498 PCE -. CL_ Yo rangell------------------------ Wr I lI------------------ 0.11--------- 26----------53--------------------- 79 105-------EIA ElfinCov__eUtilityCommission Elfin Cove 0.53--------- 133--------- 265--------- 398--------- 531 PCE Gustavus Electric Co -------------------------------------------------------------------------------------------------------- Gustavus 0.74 184 368 552 736 ------------ PCE lp§ i_qe. Passage Electric _ _ _ _ _ _ _ Aggoon 0.57 -------- 144 44------ 287 431 574 ------- PCE- Inside Passa-qe Electric Haines 0.57 144 287_ 431 574 PCE InsidePassageElectric -------------------- Hoonah _ 0.57--------- 144--------- 287--------- 431_____ 574 PCE -_I----------de - Electric_ _ _______ -- -- _________ake _ _________ 0.57______ _144_________287____-__ 431_ -- 5-- PCE - InsidePas g_EjElectric-------------------- Klukwan _________ 0.58__ ___145--------- 290__------ 435--------- 579__-__ PCE 95 Tahle 2.4c Pro Forma Monthly Resident Electric Bills. 2008 Utility Name Community $/kWh before 250 kWh $ per month 500 kWh $ per month 750 kWh $ per month 1000 kWh $ per month Source PCE* Ketchikan Public Utilities -------- MULTIPLE ---------------------- 0.10 26 ------•--..--.--- 51 77 102 EIA MetlakatlaPower&Light --------------Metlakatla _._---_--_____-- 0.09 24 - 47 - 71 - 95 -___EIA Pelican Utility -- -- - -- Pelican------------------- 0.16_-------- 41----------82---------------------165-------EIA SitkaCity&Borcu'qhof _-----Sitka---------------- 0.10----------24----------48---__.__--71----------95-------EIA Yakutat Power Inc Yakutat 0.49 123 246 369 492 PCE South West 0.48 121 241 362 483 Akiachak Native Community ------ _ Akiachak -------- 0.57 143 285 428 571 _ PCE Akiak City Council ----------------------- Akiak--------------------- 0.59 --------- 146--------- 293--------- 439--------- 585------- PCE Alaska Village Electric Coop Eek_____________________0.54______-__136_____-___27P_____-___408_________5_44__ I— -------- Alaska Village Electric Coop Goodnews Bay _ _ _ _ _ _ _ _ _ _ _ 0.54 134 268 402 537 _ PCE Alaska Village Electric Coop Kalskag _ 0.49 123 245 368 490 PCE Alaska Village Electric Coop _._______ _____Kasigluk __ 0.44_____ __-09_________219____________ ___________ ___PCE_. Kaska Village Electric Coop Lower Kalskag _ . _ _ _ _ 0.49 122 244 --- - - - PCE AlaskaVillage Electric Coop Mekoryuk .............. 0.52......... 129-------- 259 388 --------- 518------- PCE Alaska Village Electric Coop New Stuyahok _ _ 0.54 134 _ 269 403 537 PCE Alaska Village Electric Coop tute ---------PCE _ ilageEectricCoop______________p_______________ --A-l-a-sk-a--V-l-................ unaithuk 0.44____-____------------------------------------------------- 10 219 329 438 PCE A aVillaeElectricCoo------------ Quinhagak_____________0.54 _______134 --------- 268------ _402_-------- 536 ___PCEAag Alaska Village Electric Coop_ . _ _ _ _ __ _ -- ....._. _ _ _ _ _ _ - Togiak _ ._ _ _ ---- _ _ _ _ _ 0.49 123 246_ _ _ 369 491 PCE AlaskaVillageElectricCoop - - _ToksookBay_______________ 0.42_________-05____-____210 _314_________419______ CE --- AlaskaVillageElectricCoop __________ - - ___Tununak___ _____________ --------- _______105 _______210 ______314________419_ ___PCE AniakLight&Power Aniak__-________0.73_________183_________367_ 550_________734_ __PCE Atmautivak Tribal Utilities ------------ Atmautivak 0.64 160 320_ 480 640 PCE BethelUtilities Corporation --- ___ Bethel --- - _Bethel _______________0.49_________-23____ ___246 _____370_-_______ -- ___PCE •- CityofChignik ___Chignik ___________ 0.45_________113_________227_________340_________454_____ --- t,m !K �a oon rawer uum higni :�. � _____ �. nm �a wn n 58 �.Y� 145 �� 291 436 - -- 582 - - PCE �- CitYofAkutan Akutan 0.32___-____ 81_________162 242_________323_____ PCE_. City of Atka . - --------------•----------- Atka 0.62 156 312_ 468 624 PCE Chignik Lake Electric UtiliSr --- Chignik Lake _ ------- 0.58 145 289 _ _ _ _ _ _ _ 434_ _ _ _ _ _ _ _ _ 579_ _ _ _ _ _PCE- . City of Ekwok ---- ----------------------------------- Ekwok 0.50 ---- --------- 125 250 375 500 PCE CityofKingCove________________________KingCove_ --------------- 0.24_--------- 60________ 120 --------- 180--------- 240------- PCE_, CiiyofNikolai - - Nikolai__ ______________ 0.64_________160________ 321___ _____481___ _____641______ CE ---- CityofPlatinum ---- ---------------- Platinum_______________-__ 0.50 ______- - _ ___250 375 500 PCE CityofUnalaska •---------------- Dutch Harbor _____ _____ 0.46 ____ 116 32 2-- 348__ _____464_-_____EIA CityofUnalaska Unalaska 0.46 _115 231 --------- 346--------- 462------- PCE EgegikLight& Power -Co __________________E,qeAik------ ------------- 0.72--------- 181--------- 361 ------- __542--------- 722------- PCE_. G & Klnc------------------------------- Cold Bay----------------- 0.68--------- 170--------- 339--------- 509--------- 679 ------- PCE_. IgiugigElectricCompany------------------- Igiugja -------------------- 0.61--------- 153--------- 306--------- 459--------- 612------- PCE Iliamna, Newhalen, I_N_NElectric Coop Inc ___________________ _____ton__ _____-__-___ 0.I- ________--- _-_____289_________422_________563_-____PCE KipnukLightPlant ------------- - -____ - ---- _____________ 0.49_ _____-_--- ____._-_243_________365___-_____487 _ PCE _Kokhanok Village Council Kokhanok 0.74 _ 184 369 553 738 PCE 96 Table 2.4c Pro Forma Monthly Resident Electric Bills, 2008 Utility Name Community $/kWh before 250 kWh $ 500 kWh $ 750 kWh $ 1000 kWh $ Source PCE * Per month per month per month per month Kwethluk incorporated - ------------ Kwethluk ----------- 0.45 113 227_ 340 453 PCE _ Kwlc,�ilin,qok Power Company Kwigillingok 0.50 , 125 250_ 375 500 PCE Lev_elock Electrical Coop ............ Levelock 0.52 129 258_ 388 517 PCE Lime Village Electric Utility________________ Lime Village________ ______1.17_________293_________585_________877________1170______ CE --- Manokotak Power Company Manokotak 0.40 99 198 296 395 PCE MograthLight&Power____________________McGrath-________________ 0.53--------- 133 --- 266 ---------- 399--------- 532 PCE Middle Kuskokwim Electric - -------------------------------------------------------------------------------------------- Chuathbaluk 0.77 194 387 581 -------------------------- 775 PCE Middle Kuskokwim Electric -- -------------------------------------------------------------------------------------- Crooked Creek 0.77 194 387 --------------------------------- 581 775 PGE Middle Kuskokwim Electric Red Devil 0.77 194 387 581 775 PCE Middle Kuskokwim Electric •------------------------------------------------------------------------------------------------------------------------------- Sleetmute 0.77 194 387 581 775 PCE MiddleKuskokwimElectric______________ _StonyRiv_er_______________ 0.77--------- 194 --------- 387--------- 581--------- 775- PCE Naknek Electric --------------------------------------------•---------------------------------------------------------------------------------- Naknek 0.41 102 203 305 407 PCE Na akiaklrcinra ____________ Napakiak 0.65 163 326_ 488 651 PCE Napaskiak Electric Utility Napaskiak 0.58 146 292_ 438 583 PCE NaterkagLiahtPlant---------------------- Chefomak _____ 0.58--------- 144--------- 288--------- 431--------- 575------ PCE_ Native Village of Perryville - ------- 0.40 101 201 302 -------------------------- 402 EIA Nelson Lagoon Electrical Coop_ _ _ _ _ _ _ _ _ _ --Perryville _ _ _ Nelson Lagoon ............ 0.52 130 - 260_ 390 520 PCE New KolanekIlage Council Koliganek _ 0.50 125 250 - 375 ------------------------------- 500 PCE NushagakElectric____ _________ Dillingham - -...........------ 0.37 ----------------------- 92 184_ 276 367 PCE --------- Pedro Bay Village Counal Pedro Bay 0.68 169 339_ 508 677 PCE Pilot Point Electric Utility Pilot Point 0.50 125 250 375 500 PCE Puvumaq Power Company_______________ Kongiganak______________ 0.51_________127_________ 254 ________381_________508_____ PCE St. Paul Municipal Electric_____ __________ Saint Paul------------------------- 0.54_________135-________270_________----__-_____540____ 405 PCE Takotna Communi Assoc lnc ----� ----- Takotna 0.76 189 ------------------- 379 568 758 PCE ------- TanalianElectricCooperative ---------------- Port Alsworth_____________ 0.68--------- 170--------- 340 --------- 510--------- 680------- PCE TDX Adak Generafinn I I C Adak 0.74 1 RR 379 F.4R 74d PCF TDX Corporation________________________ Sand Point___-____________ 0.57__________________ 142 285_________427 _________ 569 PCE Tuluksak Traditional Tuluksak 0.60 150 300 450 600 PCE Tuntutuliak Community _ _ _ _ _ _ _ _ _ _ _ _ __ Tuntutuliak 0.52 130 260 390 520 PCE Twin Hills Ullage Council ........ -------------------------------------------------------------------------------------------------- Twin Hills 0.55 138 275 413 550 PCE Umnak Power Company ......... -------------------------------------------------------------------------------------------------- Nikolski 0.58 144 288 431 575 PCE Ungusraq Power Company Newtok 0.76 189 378 567 756 PCE Yukon 0.21 51 103 154 205 Alaska Power & Telephone Company_ .. ----------------------------------------------------------------------------------------------- Allakaket 0.75 188 376 563 751 PCE Alaska Power&Telephont 9 pny_........ Bettles-------------------- 0.67--------- 167--------- 333--------- 500--------- 666------ PCE Alaska Power & Telephone Company _ _ Chistochina 0.66 164 328_ 492 657 PCE Alaska Power& Telephone Company_ ... Dot Lake 0.44 111 221 332 442 PCE Alaska Power& Telephone Company -_____ --------------------- 0.62--------- 156--------- 312___ 468 624 PCE Alaska Power & Telephone Company ........ Healy Lake.......... 0.78 195 390 585 780 PCE Alaska Power& Telephone Company ........ Mentasta Lake 0.74 184 368_ 553 737 PCE _ Alaska Power hone Company _____ Norlhway________________ 0.63--------- 158--------- 316--------- 474--------- 632 PCE Alaska Power & Telephone Company Slane 0.67 167 333 500 666 PCE 97 Tahip 2-4c Pro Forma Monthly Resident Electric Bills. 2008 Utility Name Community $[kWh before 250 kWh $ per month 500 kWh $ per month 750 kWh $ per month 1000 kWh $ per month Source PCE* Alaska Power i£ Telephone Company Tetlin -----------•----- 0.44 ill 221 332 442 PCE Alaska Power &TelephoneCompany Tok 0.44 111-------------------------- 332 _--------------------- PCE _ Alaska Village Electric Coop _ _ Alakanuk _ _ _ _ 0.53 131 263_ _ _ _ _ _ _ 394 526------- PCE Alaska Vllage Electric Coop Anv_ik 0.58 145 _289 _ _ _ _ _ _ _ _ 434--------- 579 PCE Alaska Village Electric Coop Chevak_____________._-____ 0.53_________132_________264_ _______396_________527_ ___PCE Alaska Village Electric Coop_____..-__-___Emmonak 0.51_______-_127_______-_254_ -______381_________-- PCE Alaska Village Electric Coop Grayling 0.58_________14__ ______ __ __________ 578 _____PCE A -1- - -- - -- ------------------- u„ h, r-- -- ---- - -- - n .5R 14n ___ - - - - 991 - 421 - 561 ---------------- PCE AlaskaVillageElectricCoop .__________.._HooperBay - _-____-____ 0.50________..125_________250 ________375_________500__-___PCE Alaska VillageElectncCoop a ____Huslia___ ____-___________ 0.55_________138_________276_ 414 _551_ ___PCE AlaskaVillaeElectricCoop ----- Kaltaq....... -------------- 0.53--------- 133---- ____266 399 _ 532 PCE Alaska ill q!egiectrgppop________________ Marshall___ ___ _______- 0.51128256384512 _________ _____-___ _________ _________ ______ ----- Alaska Vllage Electric Coop________________ _ _______________________ 0.49_ _______122 _245_____-___367 ________--- _ _ PCE Alaska Vllage Electric Coop Mountain Village 0.50 124 _ _ ___ 248 372 496 PCE Alaska Village Electric Coop_ .______,_____ -- - ____ ___________ _____ 0.--_____-_-140_________280_----- __41--_______559__-___PCE AlaskaVilla,qeElectric Poop_•_________ ---------- - ____Pilot Station_-____0.53_________--- -------- __ --- 264_____-___396_________528_ ___PCE Alaska Village Electric Coop PitkasPoint _ _ _ 0.50 126 252 378 505 PCE Alaska Village Electric CooCE -- p-___ -Russian Mission ____ _ 0.---___-- __129______-__ -- _--- __-____516______ --- Alaska Village Electric Coop _ .... Saint Marys ........... _ _ _ 0.50 _ 126 _ _ 252--------- 378--------- 505 PCE Alaska Village Electric Coop Scammon Bay _ _ _ 0.55 139 --------- 277_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 554- _ _ _ _PCE _ . Alaska Village -Electric Coop _______Shageluk ___- 0.62 _______156_________311_____ __467___-_____623__ -_-PCE _Beaver Joint Utilities ___ ____________ Beaver________ ________ 0.53 ------- 131---------- 263--------- 394 --------- 525------- PCE Birch Creek VillageElecUtil --EIA ---------------------- Birch Creek________ _0.61 -- ________152_______--305_____-___457______ __610____ ------ Ele_c-- lnc_______________________Central___-_._-______.-.___.0.56_________139______-__279_________-----___-____558_____ Central 418 PCE ChalkyitsikVillageCouncil ______-_Chalkyitsik 0.95 238--------- 475_________713_________950_____ PCE Circle Electric Utili ---------------- ---------------------- Circle ------------------------- 0.63 157 314 ----------------- 471 -628 PCE CityofGalena ________Galena ---- ----------------- -------------_______ 0.44_________110_________ __ ________329_________439______ CE --- City of Koyukuk Koyukuk 0.45 113 225 338 450 PCE City of Ruby---------- - - Ruby ------------------ 0.95--------- 238-------- 476--------- 714--------- 953----- PCE Golden Valley Elec Assn Inc _ _ MULTIPLE 0.18 46 92 139 185 _ EIA Gwitchyaa Zhee Utilities Co Fort Yukon 0.51 _ 127 255 382 510_ PCE Hughes Power & Wit -------------------- Hughes __________•__,__,_ 0.59 148 297_ 445_-_-_____593_____ PCE KotlikJointUtility __Kotlik_0.57_________143_________286_________428_ _______ --_-____PCE Manley Utilities______ -------------------Manle HotSPrIngs ______0.66_ 166____ ___332_________499_________665______ ---- NunamlquaElectricCompany______________ AqqEnjqqa_______________ 0.47--------- 117--------- 234 --------- 351--------- 468------- PCE Stevens VillagelraCouncil_________________StevensVilage -------------0.90 --------- 224--------- 448--------- 673--------- 897------- PCE Tanana Power Company Inc Tanana 0.57 143 285 428 570 PCE *Region totals are weighted averages by residential sales. 98 PART 3. ALASKA INDUSTRIAL ELECTRICITY STATISTICS Table 3.1 Alaska Industry Installed Capacity by Prime Mover (MW), 2008 Gas & I I FTotalGenerators Combustion Internal Steam No. of Facilit Turbine Combustion Turbine Wind Source State 839.6 503.6 13.0 675.0 1,056.3 216.0 Petroleum 839.6 142.4 982.0 170 Tesoro Alaska -Co ----------------------------------------------- 8.0------------------------------------- 8.0----------- 2 EIA Alyeska Pipeline Service Company 345.5_ 3.1 348.6 ------------------------ 32 AIRTOOLS BP Exploration (Alaska)_ Inc. _ _ _ _ _ _ _ 297.5 90.7 _ _ _ _ _ 388.2 71 AIRTOOLS ConocoPhillips Alaska, Inc. - ------------- -------------------------------------------------------------------------------------- 183.4 18.1 201.5 30 AIRTOOLS ---- Union Oil_Company of California (UOCC) (formerly UNOCAL 2.3 24.8 27.1 27 AIRTOOLS XTO Enerc , Inc. 3.0 5.7 8.6 8 AIRTOOLS Seafood 51.6 51.6 37 Ny_eska Seafoods Inc._ _ _ _ _ 5.5 5.5 6 AIRTOOLS Icicle -Seafoods, -Inc - 4.7 4.7 4 AIRTOOLS -te-PanSe foils PeterPan Seafoods ---------------- ----------------- _______------------------------ - - ------------- 3--A------S TridentSeafoods --------------------------------------------------------------------------- 16.0 -------------------------- 16.0 -------------- 15 ---- AIRTOOLS ----------- Unisea Inc 15.5 15.5 6 EIA Westward Seafoods Inc 6.6 6.6 3 EIA Other 309.6 13.0 675.0 22.6 9.0 University of Alaska 9.6 13.0 22.6 4 EIA POSS Cam [3 300.0 675.0 5 AEA Note: Installed capacity data in the AIRTOOLS database is presented in some cases in horse power units; the conversion factor of 1HP=0.7457 kW was used. 99 Table 3.2 Alaska Industry Net Generation by Prime Mover (MWh), 2008 Facility Combustion Turbine Internal Combustion Steam Turbine Total Source Natural Natural Gas Diesel Gas Diesel Coal Diesel State 1,485,464 753,803 184,036 934,826 44,380 4,376 3,406,886 Petroleum 1,485,464 753,803 184,036 805,232 3,228,536 Tesoro Alaska Co ------------ ----- 60,239 60,239 EIA AlYeskaPipelineServi----- any______________ _______281:904 __751,566 ________________ 81 ___________-_____- ----552_ AIRTOOLS--- BPExploraggq Inc. _____605_942 2,205 _ 7,748 615.894 AIRTOOLS ConocoPhillips Alaska, Inc. 502,333 32 13,488 515,853 AIRTOOLS Union gilqqmpany.qfjqqliforniajUOCC)(formerlyUNOCAL) 18,106 156,010 783,915 --------958,03-- AIRTOOLS------- XTO Energy, Inc. 16,940 28,026 44,966 AIRTOOLS Seafood 130,201 130,201 Alyeska Seafoods Inc. 11529 _ _11,529 AIRTOOLS Icicle Seafoods, Inc. 6 982 6,982 AIRTOOLS Peter Pan Seafoods Trident Seafoods Unisea Inc 11,633___ ____11,633 _AIRTOOLS _.49,813 _ 49,813 AIRTOOLS _____________ 31.554 __________________ 31,554_ EIA ------- Westward Seafoods Inc 18,690 18,690 EIA Other -608 44,380 4,376 48,148 Universil,ofAlaska -608 44,380 4,376 48,148 EIA Note: For cases with AIRTOOLS source, net generation was estimated based on fuel use; please see appendix D for details. Net generation data for POSS Camp was not available. 100 Table 3.3 Alaska Industry Fuel Use, 2008 Natural Gas Oil Coal Facility Billion Barrels Short Source Cubic Tons Feet State 19 2,816,958 73,374 Petroleum 19 2,570,067 Tesoro Alaska -Co ---------------------------- ---------------- - I---------8 ----------- EIA ------- AlyeskaPipelineSeryiceCompany_____ __ _________ _-__ 3--- 1,177,406__________ AIRTOOLS__ BP Exploration Alaska) Inc_ _ _ 7 16,821 AIRTOOLS ConocoPhillips Alaska, Inc. 6 23,321 AIRTOOLS Union qil Company of California �UOCC) (formerly UNOCAL) .... 2 1,352,511 _ _ _ _ _ AIRTOOLS XTO EneFgy, Inc. 0 AIRTOOLS Seafood 224,561 Alyeska Seafoods Inc----------------------------------------------------- 19,892 _ _ _ _ _ _ _ _ _ AIRTOOLS Icicle Seafoods, Inc . -------------------------------------- --- -- 12,047 AIRTOOLS --------------------------------------------------- Peter Pan Seafoods 20,071 AIRTOOLS Trident Seafoods -------------------------------------- ----------------------------------------------------------- 85,944 AIRTOOLS Unisea Inc 55,658 EIA Westward Seafoods Inc 30,950 EIA Other 22,330 73,374 University of Alaska 22,330 73,374 EIA Note: Fuel use data for POSS Camp was not available. 101 W 0 N PE� 0 5 v E L. .Q .m CL m U cl G. 4J E m Z a-i N ca H Q• Qr ¢� 0. .Lr �r �r Vi lA: r Cl. Or OOr C N N: N ap' Lr; O' N' O' C o; o� o' : O; ao: c Oc O r N' N' lnn �r Or , C ©' 4')' ao� a� c� m= W' l6' m. Lam. N t, C_c W; cb; ¢- o, C Or m; LL Y' a. N' yc w� w: W O G N t 3 0 a� E a` .Q 0 i OJ C ar N Z N d B m H Table 5.1 ALASKA UTILITY INSTALLED CAPACITY (kW) BY PRIME MOVER (1962-2008) Internal Combustion Combustion Gas H dro Steam Turbine diesel,piston) Turbine Combined Cycle Wind Turbine" % of % of % of % of % of % of Utility Net Utility Net Utility Net Utility Net Utility Net Utility Net I Utility I Year Total Ca ci Total Ca aci Total Ca ci Total capacity Total Capacity Total Capacitv Total 1962 169,968 82,300 48% 32,875 19% 41,993 25% 12,800 8% 1963 202,243 82,300 41% 32,875 16% 47,368 23% 39,700 20% 1964 218,582 82,300 38% 32,750 15% 49,482 23% 54,050 25% 1965 242,812 82,225 34% 32,750 13% 59,437 24% 68,400 28% 1966 254,148 82,225 32% 32,750 13% 69,273 27% 69,900 28% 1967 260,273 76,600 29% 32,750 13% 81.023 31% 69,900 27% 1968 339,688 78,700 23% 54,750 16% 89,538 26% 116,700 34% 1969 347,013 76,600 22% 54,750 16% 98,963 29% 116,700 34% 1970 406,596 76,600 19% 74,750 18% 123,256 30% 131,990 32% 1971 472,955 75,275 16% 68,250 14% 140,627 30% 188,803 40% 1972 533,639 74,275 14% 68,250 13% 144,975 27% 246,139 46% 1973 650,050 121,000 19% 68,250 10% 147,700 23% 313,100 48% 1974 723,638 122,260 17% 68,000 9% 148,054 20% 385,324 53% 1975 763,498 122,535 16% 68,000 9% 176,706 23% 396,257 52% 1976 971,799 123,235 13% 68,000 7% 205,110 21% 575,454 59% 1977 1,038,270 122,460 12% 68,000 7% 223,736 22% 624,074 60% 1978 1,132,590 122,460 11% 68,000 6% 221,516 20% 720,614 64% 1979 1,257,835 123,310 10% 101,000 8% 233,611 19% 799,914 64% 1980 1,285,237 123,360 10% 101,000 8% 237,703 18% 823,174 64% 1981 1,383,809 123,690 9% 158,000 11% 251,745 18% 850,374 61% 1982 1,418,344 154,280 11% 158,000 11% 255,790 18% 850,274 60% 1983 1,452,037 153,780 11% 158,000 11% 269,683 19% 870,574 60% 1984 1,605,485 222,990 14% 158,030 10% 276,841 17% 947,624 59% 1985 1,601,714 224,000 14% 144,500 9% 299,614 19% 933,600 58% 1986 1,669,200 225,600 14% 154,000 9% 317,500 19% 972,100 58% 1987 1,655,373 227,625 14% 145,600 9% 316,148 19% 966,000 58% 1988 1,603,684 228,360 14% 141,800 9% 325,924 20% 907,600 57% 1989 1,610,966 260,965 16% 141,800 9% 311,301 19% 896,900 56% 1990 1,604,767 255,907 16% 139,200 9% 312,760 19% 896,900 56% 1991 1,733,158 365,607 21% 139,200 8% 324,851 19% 903,500 52% 1992 1,739,890 365,632 21% 139,200 8% 328,758 19% 906,300 52% 1993 1,741,487 364,357 21% 139,200 8% 336,430 19% 901,500 52% 1994 1,771,065 365,482 21% 139,200 8% 345,383 20% 921,000 52% 1995 1,777,575 369,982 21% 139,200 8% 347,393 20% 921,000 52% 1996 2,078,865 364,461 18% 68,500 3% 418,449 20% 1,227,425 59% 1997 1,960,531 377,094 19% 53,500 3% 335,392 17% 1,194,350 61% 195 0.01% 1998 2,125,108 373,685 18% 68,500 3% 458,173 22% 1,224,425 58% 325 0.02% 1999 2,157,493 388,085 18% 68,500 3% 472,903 22% 1,227,225 57% 780 0.04% 2000 2,195,227 400,085 18% 68,500 3% 493,437 22% 1,232,425 56% 780 0.04% 103 Table 5.1 ALASKA UTILITY INSTALLED CAPACITY (M) RY PRIME MOVER (1962-20081 Internal Combustion Combustion Gas Hydro Steam Turbine diesel,piston) Turbine Combined Cycle Wind Turbine* % of % of % of % of % of I % of Year utility Total Net Capacity Utility Total Net Capacity Utility Total Net Capacity utility Total Net Capacity Utility Total Net Utility Carlarity Total Net Ca aci Utility Total 2001 2,259,108 443,442 20% 68,500 3% 475,736 21% 1,270,650 56% 780 0.03% 2002 2,078,380 400,100 19% 55,500 3% 317,300 15% 892,000 43% 412,600 20% 880 0.04% 2003 1,971,740 400,100 20% 55,500 3% 323,600 16% 778,800 39% 412,600 21% 1,140 0.06% 2004 1,971,740 400,100 20% 55,500 3% 323,600 16% 778,800 39% 412,600 21% 1,140 0.06% 2005 1,890.470 395,100 21% 55,500 3% 317,900 17% 732,000 39% 388,700 21% 1,270 0.07% 2006 1,910,455 396,300 21% 55,500 3% 325,500 17% 742,100 39% 388,700 20% 2,355 0.12% 2007 2,028,955 396,300 20% 55,500 3% 335,500 17% 850,600 42% 388,700 19% 2,355 0.12% 2008 2,056,730 399,300 19% 55,500 3% 359,300 17% 850,600 41% 388,700 19% 3,330 0.16% 1) Data before 2001 from the Alaska Energy Statistics Report 2003. a) From 1996 to 2001: Combustion Turbine (CT) includes Gas Turbine (GT) and Combined Cycle Turbines (CA) b) Wind Turbines (WT) included in net capacity value c) Data from 1996-2000 from EIA historic tables are not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. d) Data before 1996 from prior Alaska Energy Power Statistics reports. 2) Data from 2002-2008 from EIA Annual Electric Generator data file. e) Data from 2002-2008 not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. Wind data entries have been modified to reflect the best available wind data from the Alaska Energy Authority. Installed wind capacity is defined here as commissioned turbines. Installed wind capacity in 2009 was 8,754kW,• 11,924 kW in 2010 and 13,189 kW as of February of 2011. 104 Table 5.2 ALASKA UTILITY INSTALLED CAPACITY (M) BY REGION (1962-2008) % of % of % of % of % of Utility Utility South Utility South Utility South Utility Utility Year Notes Total Arctic Total Central Total East Total West Total Yukon Total 1962 2,g 169,968 1963 2,g 202,243 1964 2,g 218,582 1965 2,g 242,812 1966 2,g 254,148 1967 2,g 260,273 1968 2,g 339,688 1969 2,g 347,013 1970 2,g 406,596 1971 2,g 472,955 1972 2,g 533,639 1973 1,a 650,100 11,600 2% 369,800 57°% 126,300 19% 11,600 2% 130,800 20% 1974 1,b 724,200 12,100 2% 438,700 61% 129,600 18% 12,300 2% 131,500 18% 1975 1,b 763,500 14,700 2% 451,500 59% 136,900 18% 20,400 3% 140,000 18% 1976 1,c 971,700 18,200 2% 556,900 57% 139,700 14°% 23,400 2% 233,500 24% 1977 2,g 1,038,270 1978 2,g 1,132,590 1979 2,g 1,257,835 1980 1,c 1,283,054 27,576 2% 750,087 58% 176,732 14% 28,887 2% 299,772 23% 1981 1,c 1,373,734 34,769 3% 836,094 61% 175,502 13% 29,867 2% 297,502 22% 1982 1,c 1,412,504 38,374 3% 848,355 60% 192,802 14% 32,196 2% 300,777 21% 1983 1,c 1,447,752 41,104 3% 848,255 59% 215,747 15% 38,494 3% 304,152 21% 1984 1,c 1,605,485 43,789 3% 947,908 59% 272,392 17% 39,884 2% 301,512 19% 1985 1,c 1,601,714 48,696 3% 926,507 58% 279,995 17% 41,215 3% 305,301 19% 1986 1,c 1,683,641 47,975 3% 1,009,062 60% 289,487 17% 42,253 3% 294,864 18% 1987 1,c 1,655,373 51,337 3% 983,122 59% 288,238 17% 45,447 3% 287,229 17% 1988 1,c 1,603,984 52,784 3% 939,109 59% 291,911 18% 48,910 3% 271,270 17% 1989 1,c 1,610,966 51,967 3% 939,494 58% 317,846 20% 52,283 3% 249,376 15% 1990 1,c 1,604,767 58,285 4% 939,487 59% 309,318 19% 53,327 3% 244,350 15% 1991 1,c 1,733,158 64,115 4% 1,054,479 61% 314,006 18% 55,092 3% 245,466 14% 1992 1,c 1,739,890 67,227 4% 1,054,499 61% 314,011 18% 57,832 3% 246,321 14% 1993 1,c 1,734,468 62,323 4% 1,046,065 60% 316,936 18% 62,323 4% 246,821 14% 1994 1,d 1,771,065 70,107 4% 1,047,945 59% 341,471 19% 62,912 4% 248,630 14% 1995 1,d 1,777,575 72,336 4% 1,047,575 59% 344,093 19% 64,132 4% 249,439 14% 1996 i,e 2,078,865 82,394 4% 1,274,326 61% 351,316 17% 60,279 3% 310,550 15% 1997 1,e 1,960,366 64,829 3% 1,219,884 62% 343,139 18% 47,986 2% 284,528 15% 1998 1,e 2,124,813 86,440 4% 1,276,954 60°% 380,294 18% 64,772 3% 316,353 15% 1999 t,e 2,156,743 96,177 4% 1,292,639 60% 381,064 18% 66,451 3% 320,412 15% 2000 1,e 2,194,477 98,247 4% 1,322,809 60% 385,189 18% 66,680 3% 321,552 15% 2001 1,e 2,258,905 106,952 5% 1,351,937 60% 415,746 18% 69,141 3% 315,129 14% 2002 2 f 1,939,400 65,900 3% 1,241,400 B4% 350,400 18% 45,500 2% 236,200 12% 105 Table 5.2 ALASKA UTILITY INSTALLED CAPACITY (kW) BY REGION (1962-20081 %of %of %of %of %of Utility Utility South Utility South Utility South Utility Utility Year Notes Total Arctic Total Central Total East Total West Total Yukon Total 2003 2,f 1,946,400 70,600 4%1,241,400 64% 353,200 18%45,800 2% 235,400 12% 2004 2,f 1,876,000 73,700 4% 1,172,500 63% 349,300 19%0 45,100 2% 235,400 13% 2005 2,f 1,871,300 77,800 4% 1,162,400 62%0 351,100 19%p 44,400 2% 235,600 13% 2006 2,f 1,883,400 71,700 4% 1,161,200 62%0 364,900 19% 45,600 2% 240,000 13% 2007 2,f 2,002,000 82,600 4% 1,210,100 60% 365,900 18% 43,900 2% 299,500 15% 2008 2,f 2,028,800 94,700 5% 1,209,500 60% 369,500 18% 50,400 2% 304,700 15% 1) Data before 2001 from the Alaska Energy Statistics Report 2003 a) From AK Electric Power Statistics 1960-1973 b) From AK Electric Power Statistics 1974 c) From AK Electric Power Statistics 1960-1993 d) Data before 1996 from prior AK Power Statistics reports. e) Data from 1996-2000 from EIA historic tables. 2) Data from 2002-2008 from EIA Annual Electric Generator data file. f) Data from 2002-2008 not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. g) Utility totals from 1962 to 1972 and from 1977 to 1979 added to the table published in 2003. Data regarding regional details are not available. 106 Table 5.3 Utility Net Generation (GWh) By Fuel Tvoe (1962-20081 % Of % Of % Of I % Of % Of Utility Utility Utility Utility Utility Utility Year Notes Total Oil Total Gas Total Coal Total H dro Total Wind Total 1962 1963 1,b 325 1964 1,b 321 1965 1,b 350 1966 1,b 316 1967 1,b 363 1968 1,b 363 1969 t,b 340 1970 1,b 362 1971 1,b 1,071 195 18% 614 57% 262 24% 1972 1,a 1,207 193 16% 748 62% 266 22% 1973 1,a 1,406 189 13% 950 68% 267 19% 1974 1,c 1,868 203 11% 1,047 56% 299 16% 319 17% 1975 l,c 2,262 277 12% 1,311 58% 323 14% 351 16% 1976 1,c 2,502 351 14% 1,468 59% 314 13% 369 15% 1977 1,c 2,710 378 14% 1,537 57% 297 11% 498 18% 1978 t,c 2,864 388 14% 1,690 59% 323 11% 463 16% 1979 1,c 2,968 383 13% 1,827 62% 308 10% 450 15% 1980 1,c 3,034 368 12% 1,844 61% 290 10% 532 18% 1981 t,c 3,154 338 11% 1,897 60% 338 11% 581 18% 1982 1,c 3,607 466 13% 2,211 61% 354 10% 576 16% 1983 1,c 3,781 526 14% 2,338 62% 331 9% 586 15% 1984 1,c 4,057 541 13% 2,512 62% 308 8% 696 17% 1985 1,c,e 4,234 538 13% 2,631 62% 290 7% 775 18% 1986 1,c 4,411 535 12% 2,749 62% 272 6% 854 19% 1987 1,c 4,424 459 10% 2,790 63% 276 6% 898 20% 1988 1,c 4,502 451 10% 2,767 61% 295 7% 989 22% 1989 1,c 4,604 486 11% 2,875 62% 307 7% 935 20% 1990 t,c 4,675 449 10% 2,886 62% 316 7% 1,024 22% 1991 1,c 4,621 547 12% 2,666 58% 323 7% 1,085 23% 1992 1,c 4,737 530 11% 2,569 54% 302 6% 1,337 28% 1993 1,c 4,733 575 12% 2,476 52% 322 7% 1,359 29% 1994 1,c 4,924 593 12% 2,654 54% 294 6% 1,384 28% 1995 1,c 5,019 591 12% 2,660 53% 309 6% 1,459 29% 1996 1,d 4,982 643 13% 2,844 57% 229 5% 1,266 25% 1997 1,d 5,108 741 15% 3,031 59% 237 5% 1,099 22% 1998 1,d 4,590 757 16% 2,549 56% 171 4% 1,113 24% 1999 1,d 4,609 798 17% 2,838 62% 156 3% 817 18% 2000 1,d 4,938 557 11% 3,194 65% 185 4% 1,002 20% 2001 1,d 5,417 848 16% 3,028 56% 194 4% 1,346 25% 2002 2,f 5,472 875 16% 2,953 54% 205 4% 1,439 26% 107 1 0% Table 5.3 Utility Net Generation (GWh) Rv Fuel Tvne 11962-20081 % Of % Of % Of % Of % Of Utility Utility Utility Utility Utility Utility Year Notes Total oil Total Gas Total Coal Total Hydro Total Wino Total 2003 2,f 5,674 775 14% 3,148 55% 168 3% 1,583 28% 2004 2,f 5,866 682 12% 3,475 59% 211 4% 1,498 26% 2005 2,f 5,946 686 12% 3,577 60% 219 4% 1,464 25% 0.59 0% 2006 2,f 6,069 694 11% 3,940 65% 210 3% 1,224 20% 0.79 0% 2007 2,f 6,147 853 14% 3,788 62% 214 3% 1,291 21% 0% 2008 2,f 6,262 928 15% 3,942 63% 220 4% 1,172 19% 0.07 0% 1) Data before 2001 from the Alaska Energy Statistics Report 2003. a) From AK Electric Power Statistics (AKEPS) 1960-1973; Hydro generation not included. b) From AKEPS 1960-1970. c) From AKEPS 1960-2001. d) Data from 1996-2000 from EIA historic tables. e) Monthly data was not collected in 1985, so 1984 and 1986 figures were averaged to arrive at estimated 1985 figures. 2) Data from 2002-2008 from EIA Annual Electric Generator data file. f) Data from 2002-2008 not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. g) Even though wind installed capacity has been present in Alaska since 1997, there is little data regarding total net generation from wind turbines. 108 Table 5.4 Utility Net Generation (MWh) by Reeion (1963-20091 % of % of % of % of % of utility utility South Utility South Utility South Utility Utility Year Notes Total Arctic Total Central Total East Total West Total Yukon Total 1962 1 1963 1,a 574,000 14,000 2% 329,000 57% 129,000 22% 0% 102,000 18% 1964 1,a 628,000 15,000 2% 362,000 58% 141,000 22% 0% 110,000 18% 1965 1 733,926 9,126 1% 451,349 61% 148,121 20% 7,980 1% 117,350 16% 1966 1,a 822,000 20,000 2% 510,000 62% 160,000 19% 0% 132,000 16% 1967 t,a 891,000 22,000 2% 560,000 63% 156,000 18% 0% 145,000 16% 1968 1,a 1,008,000 25,000 2% 635,000 63% 177,000 18% 0% 171,000 17% 1969 1,a 1,120,000 29,000 3% 708,000 63% 185,000 17% 0% 198,000 18% 1970 1 1,281,310 15,836 1% 804,449 63% 201,952 16% 18,941 1% 240,132 19% 1971 1 1,491,351 18,367 1% 956,098 64% 217,336 15% 22,976 2% 276,574 19% 1972 1 1,624,744 20,278 1% 1,033,717 64% 232,465 14% 25,847 2% 312,437 19% 1973 1 1,789,281 22,415 1% 1,169,883 65% 247,700 14% 28,798 2% 320,485 18% 1974 1 1,935,126 22,755 1% 1,267,829 66% 263,521 14% 32,454 2% 348,567 18% 1975 1 2,288,220 28,813 1% 1,499,648 66% 289,031 13% 37,151 2% 433,577 19% 1976 1 2,572,104 37,032 1% 1,722,992 67% 305,796 12% 29,424 1% 476,860 19% 1977 1 2,828,083 44,908 2% 1,920,710 68% 318,514 11% 42,173 1% 501,778 18% 1978 1 2,960,038 47,701 2% 2,052,305 69% 326,083 11% 47,336 2% 486,613 16% 1979 1 3,084,915 51,404 2% 2,166,505 70% 346,457 11% 50,294 2% 470,255 15% 1980 1 3,181,484 63,936 2% 2,235,091 70% 365,443 11% 55,402 2% 461,612 15% 1981 1 3,281,429 71,666 2% 2,305,525 70% 394,724 12% 59,659 2% 449,855 14% 1982 1 3,714,277 86,813 2% 2,577,871 69% 475,011 13% 68,178 2% 506,404 14% 1983 1 3,856,013 94,981 2% 2,655,641 69% 507,253 13% 77,308 2% 520,830 14% 1984 1 4,146,039 100,906 2% 2,827,848 68% 567,608 14% 79,846 2% 569,831 14% 1985 1 4,473,992 107,467 2% 3,164,189 71% 579,250 13% 83,877 2% 539,209 12% 1986 1 4,410,431 112,398 3% 3,088,302 70% 568,241 13% 89,186 2% 552,304 13% 1987 1 4,423,875 113,700 3% 3,186,583 72% 580,705 13% 106,937 2% 435,950 10% 1988 1 4,502,221 119,138 3% 3,167,213 70% 636,945 14% 112,804 3% 466,121 10% 1989 1 4,603,964 126,988 3% 3,269,386 71% 626,705 14% 119,476 3% 461,409 10% 1990 1 4,674,565 135,768 3% 3,318,206 71% 651,226 14% 127,326 3% 442,039 9% 1991 1 4,621,212 162,135 4% 3,180,445 69% 660,607 14% 126,761 3% 491,264 11% 1992 1 4,736,792 163,449 3% 3,303,067 70% 670,609 14% 132,589 3% 467,078 10% 1993 1 4,733,185 155,026 3% 3,249,963 69% 659,553 14% 135,373 3% 533,270 11% 1994 1 4,924,864 157,381 3% 3,439,538 70% 687,221 14% 143,404 3% 497,320 10% 1995 _1 5,018,794 161,031 3% 3,501,178 70% 714,949 14% 139,087 3% 502,549 10% 1996 1,b,c 4,982,268 71,707 1% 3,609,022 72% 656,591 13% 91,476 2% 553,472 11% 1997 1,c 5,108,003 120,857 2% 3,594,688 70% 6132,150 12% 73,625 1% 686,683 13% 1998 1,c 4,590,270 122,432 3% 3,200,155 70% 529,577 12% 76,632 2% 661,474 14% 1999 1,C 4,609,315 128,838 3% 3,338,963 72% 398,387 9% 98,213 2% 644,914 14% 2000 1,C 4,937,687 126,766 3% 3,650,429 74% 552,457 11% 44,473 1% 563,562 11% 2001 1 5,646,290 179,162 3% 3,761,085 67% 704,468. 12% 167,057 3% 834,519 15% 2002 2,d 5,631,871 136,177 2% 3,859,370 69% 592,208 11% 97,834 2% 946,282 17% 109 Table 5.4 Utility Net Generation (MWh) by RPuinn (1963-200R) % of % of °% of I % of I % of Utility Utility South I. Utility South Utility South Utility Utility Year Notes Total Arctic Total Central Total East Total West Total Yukon Total 2003 2,d 6,079,380 138,647 2°%, 4,310,313 71% 686,021 11°% 121,774 2°% 822,626 14% 2004 2,d 6,048,565 136,395 2% 4,327,319 72°% 664,930 11% 125,679 2% 794,242 13% 2005 2,d 6,120,090 137,572 2% 4,397,481 72% 671,689 11% 123,761 2°% 789,587 13% 2006 2,d 6,255,896 135,213 2% 4,497,021 72% 726,890 12% 125,426 2% 771,346 12% 2007 2,d 6,436,366 133,349 2% 4,423,339 69% 745,073 12% 131,425 2% 1,003,180 16% 2008 2,d 6,439,254 151,346 2% 4,511,790 70% 704,079 11% 127,055 2% 944,984 15% 1) Data before 2001 from the Alaska Energy Statistics Report 2003. a) From AK Power Survey, 1976; Arctic value is "Remainder", inclusive of the Arctic, North-West and South- West. b) Barrow Natural Gas values missing for 1996. c) Data from 1996-2000 from EIA historic tables. 2) Data from 2002-2008 from EIA Annual Electric Utility data file. d) Data from 2002-2008 not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. 110 Table 5.5 Utility Sales, Revenue, and Customers (1962-2008) State Total Residential Commercial and Industrial Other Year Notes Sales Revenue Customers Sales Revenue Customers Sales Revenue Customers Sales I Revenue I Customers MWh $000 (accounts) MWh $000 accounts Wh $000 accountsl MWh $000 accounts 1962 1 440,000 $17,449 50,734 215,000 $8,774 43,112 201,000 ---- $7,812 7,157 24,000 $863 - - ----- 1963___ 1 _____516,000 - $18,065 ___ 54,174 - 233,000 - - - $8,553____ 46,239___ _256,000 $8,603 7,472 ----- 27,000 ---------- $907 _1964 _ 1_____562,000____----- ___ 57,738_____----- 0____ $8--- ____ 49,---____-----0_____----§ ...... 7,943_.... 25,000 $925____________ _ 1965 1 616,000 $20,851____ 59,986 277,000 $9,789_ 51056 312,000 $10,060 8,100----- 27,000 $1,002 __ 1966... 1 694,000 ---- $22,818 60,554 303,000 - - $10,548 52,019 - -357,000 $11,049 8,110 34,000 $1,221 --------- 1967 _ _ 1 _ _ _ _ _ 786,000_ _ $25,163 _ _ _ 62,917 _ _ 348,000_ _ _ _ $11,738 53,797 _ _ _ _ 391,000_ _ _ $11,965 _ _ 8,706 - _ _ _ 47,000 _ _ $1,460 _ _ _ _ _ _ _ _ _ _ _ _ 1968 1 841,000 $26,461____ 65,412..... 366,000---- $12,285____55,902_ 411,000 $12,381------ 9,058----- 64,000 ----- $1,795_____ __ ___ 1969 --------------------------- 1 956,000 $28,239 69,938 --------------------- 417,000 $13,048 59,967 - 470,000 $13,244 9,517 69,000 ---- $1,947------ 1970 _ _ _ 1 _ _ _ _ 1,054,000 - - $30,655 _ _ - _ 74,323 _ _ _ _ _ 465,000_ _ _ _ $14,015 _ _ _ 63,996 _ _ _513,000 _ _ _ _ $14,591 _ _ - _ _ _ 9,879 ------- 76,000 - ----------- $2,049 _ _ _ _ _ _ _ _ _ _ _ -- 1971 ----------------------------------------- 1972 ----------------------------------------- 1973 1974 1975 1 1,982,586 $62,676 1976..... 1 2,250,884 $85,810 1977 ----------------------------------------------------------------------------------------------------------- 103,523 910,638 $30,789 89,724 ___114,995_ 1,008,683 $38,854_.____98,520 1978 1979 1980 1 2,825,885 $145,643 144,558 - 1,277,257 $65,561 ---------------------------- 123,894 1,444,117 $71,556 18,679 --------------------------------------- 1981___ 1----- 2,912,588--- $179,361---- 151,815 1,290,616 - $76,704 129,795____1,501,272 - - $89,867_____19,320 ---------------------------------- 1982 ----- 1----- 3,24.3,776--- $220,120____164,087 1,460,183_ $100,168 140,769 1,694,845 $112,052___ 20,996 1983 1 3,404,361 $263,916 179,286 1,516,594 $121,690 154,639 -------------------- 1,757,507 $126,179 21,778 --------------------------------------- 1984___ 1..... 3,638,000--- $299,075---- 198,765----- 1,588,764_ $134,421___ - 170,470 ----------------------- 1,901,883 $147,733___ 24,678 --------------------------------------- 1985----- 1----- 3,133,696--- $327,823---- 207,812----- 1,659,526 _$142,454____171,889 12,266,920 $151,832---- 983,309 1986 1 4,041,658 $351.620 490.615 1,610.969 $148.852 190.401 2.169.522 -4------ $172.254 ------------------------------------------------------ 296;143 261.167 $30.514 4.071 1987___ 1 ..... 3,932,791--- $356,165---- 226,616----- 1,542,405__ $150,996___ 192,404 2198,897___$179,972___ 30,496___ 191,489___$25,197______3,716_ 1988 1 4,019,398 $366,322 227,020_ 1,578,933 $154,076 191,698 ------------------ 2,207,325 $180,297 30,855 233,140 $31,949 4,467 --- 1989 1 4,144,099 $381,926 228,552 1,636,796 $159,560 193,042 2,237,907 --- $188,288 31,117 -------------------- 269,396 $34,078 4,393 -- 1990 1 4,235,451 $402,043 229,897----- 12646,617 $166,009__ 193,443 2,307,933 _ _ _$201,250_ _ _ 31,817----- 280,901 _ _ _ $34,784------ 4,637 _ 1991 1_ 4,252,707 $418,382 233,394 ___ 1,613,758 $170,879 195,941_ 2,425,317 $221,318 32,708 213,632 $26,185 4,745 1992 1 4,326,067 $432,219 237,518 1,640,914 $177,586 199,250 2,467,751 $226,936 33,477 -------------------- 217,402 $27,697 4,791 ---------- 1993___ 1 ____4,368,172 $441,048 --- 241,929 ---------------------- 1,628,395 $180,749 203,218 2,538,044 - $238,638 34,598 201,734 $21,660_ 4,113 1994_ _ _ 1 _ _ _ _ 4,550,653 $465,995 _ _ _ _ 245,246 _ _ 12689,011 _ _ $191,397 _ _ _ _ 206,279 2,635,784 _ _ _ $248,265----- 34,962 _ _ _ 225,858 _ _ _ $26,333------ 4,005 1995 1 4,637,935 $472,891 _ _ _ _ 250,815 1,711,770_ $193,033 _ _ _ _ 210,870 2,7022302 _ _ _ $249,684----- 34,968 223,863 $30,174------ 4,977 1996____1,c 4,779,562 $489,489 256,103_ _ 1,766,184 $200,660 215,712 2,834,072 $264,912 36,194 179,306_ $23,917 4,197 1997 1,c 4,840,529 $487,620 254,991 ___1,725,834 $197,457 215,076 2,936,355 - $263,860 ------------------------ 35,008 178,340 $26,303 4,907 -------- 1998 1,c 5,094,584 $508,097 --- 265,185 1,767,992 $203,284 222,927 3,124,911 - --------------------•-------------- $277,217 36,935 201,681 $27,596 5,323 1999 1,c 5,292,615 $517,414 269,831 1,865,743 $208,179 227,247 3,229,036 $281,217 37,009 ------------------- 197,836 $28- - ,018 5,575 ----- 2000 _ _ _ _ 1,c 5,309,970 $535,246 _ _ _ _ 273,530 _ _ 1,854,968_ $212,474 _ _ _ _ 230,534 _ _ 3,273,104 _ _ _ $296,990 _ _ _ 38,928 _ _ 181,898 ... $25,782------ 4,068• _ _ _ 2001 1 5,419,836 $639,6251. __272,161--- 1,885,745_ $221,223 _ 237,110 3,2822876 $298,097___ 37,372 191,183 $27,432------ 5,256_-__ 111 Table 5.5 Utility Sales, Revenue, and Customers (1962-2008) State Total Residential Commercial and Industrial Other Year Notes Sales Revenue Customers Sales Revenue Customers Sales Revenue Customers Sales Revenue Customers MWh $000 accounts MWh $000 accounts MWh $000 accounts MWh $000 accounts 2002 2,d_ 5,465,489 $571,871 284,821 1,932,217 $232,769 239,822 3,326,091 $310,014 39,523 __ 207,181 $29,088 5,476 2003_ _ _ _2,d_ _ _ _ 5,563,682_ $584,243---- 290,842 _ 1,987,009 _$238,065---- 246,921_ _ _ _ _ 3,576,673 $346,178_ _ _43,921 _ _ _ _ _ _ _ 2004 _ _ 2,d_ _ . _ 5,788,484_ $636,008 _ _ _ 296,358 _ 2,061,905_ _ $256,461 _ _ _ _ 251,198 .... 3,726 579 $379,547 45,160 2005 2,d 5,912,571 $693,022 302,674 2,061,652 $274,152 ___256,717 3,850,919 __$418,870 45,957 2006 2,d 6,182,291 $794,064 308,575 2,120,254 $314,378 261,502 4,062,037 $479,686_ 47,073 2007 2,d6,_ _326,610$840,471 312,845 2,114,456_ _ $320,973_ _ _ _ 265,449 _4,212,154 _ _$519,498_ _ _ _ _47,396 _ 2008 2,d 6,324,855 $931,674 317,020 2,129,297 $352,364 268,638 4,195,558 $579,311 48,382 1) Data before 2001 from the Alaska Energy Statistics Report 2003. a)"Other" category for cost/kWh not listed before 1985 b) Total sales, revenue, and customers may exceed 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. c) Data from 1996-2000 from EIA historic tables. 2) Data from 2002-2008 from EIA Annual Electric Utility data file d) Data from 2002-2008 not consistent with prior years due to changes in reporting and utilities that failed to report to EIA. 112 Table 5.6 Average Annual Enerev Use and Cost (1962-2008) Total Residential Commercialllndustrial Other Cost cost Cost Cost IWhCustomer evenue per Sales per Revenue per Sales per Revenue per Sales per Revenue per per kWh Customer per kWh Customer per kWh Customer per kWh Year cents kWh Customer (centsl kWh Customer untsl IkWh Customer {cents 1962 8,673 $344 4.0 4,987 $204 4.1 28,084 $1,092 3.9 3.6 1963 9,525 $333 3.5 5,039 $185 3.7 34,261 $1,151 3.4 3.4 1964 9,734 $325 3.3 5,126 $178 3.5 35,755 $1,146 3.2 3.7 1965 10,269 $348 3.4 5,383 $190 3.5 38,519 $1,242 3.2 3.7 1966 11,461 $377 3.3 5,825 $203 3.5 44,020 $1,362 3.1 3.6 1967 12,493 $400 3.2 6,469 $218 3.4 44,912 $1,374 3.1 3.1 1968 12,857 $405 3.1 6,547 $220 3.4 45,374 $1,367 3.0 2.8 1969 13,669 $404 3.0 6,954 $218 3.1 49,385 $1,392 2.8 2.8 1970 14,181 $412 2.9 7,266 $219 3.0 51,928 $1,477 2.8 2.7 1971 1972 1973 1974 1975 19,151 $605 10,149 $343 1976 19,574 $746 3.8 10,238 $394 3.8 1977 1970 1979 1980 19,548 $1,008 5.2 10,309 $529 5.1 77,312 $3,831 5 1981 19,185 $1,181 4.0 9,943 $591 5.9 77,706 $4,652 6 1982 19,769 $1,341 6.8 10,373 $712 6.9 80,722 $5,337 6.6 1983 18,988 $1,472 7.8 9,807 $787 8.0 80,701 $5,794 7.2 1984 18,303 $1,505 8.2 9,320 $789 8.5 77,068 $5,986 7.8 1985 15,079 $1,577 9.5 9,655 $829 14.3 12,475 $154 9.2 1986 8,238 $717 9.6 8,461 $782 14.8 7,326 $582 9.5 64,153 $7,495 18.6 1987 17,354 $1,572 9.9 8,016 $785 10.6 72,104 $5,901 9.7 51,531 $6,781 18.1 1988 17,705 $1,614 9.9 8,237 $804 10.6 71,539 $5,843 9.6 52,192 $7,152 19.1 1989 18,132 $1,671 10.0 8,479 $827 10.7 71,919 $6,051 9.9 61,324 $7,757 16.3 1990 18,423 $1,749 9.5 8,512 $858 10.1 72,538 $6,325 8.7 60,578 $7,501 12.4 1991 18,221 $1,793 9.8 8,236 $872 10.6 74,151 $6,766 9.1 45,023 $5,518 12.2 1992 18,214 $1,820 10.0 8,235 $891 10.8 73,715 $6,779 9.2 45,377 $5,781 12.7 1993 18,056 $1,823 10.1 8,013 $889 11.1 73,358 $6,897 9.4 49,048 $5,266 10.7 1994 18,555 $1,900 10.2 8,188 $928 11.3 75,390 $7,101 9.4 56,394 $6,575 11.7 1995 18,491 $1,885 10.2 8,118 $915 11.3 77,279 $7,140 9.2 44,980 $6,063 13.5 1996 18,663 $1,911 10.2 8,188 $930 11.4 78,302 $7,319 9.3 42,722 $5,699 13.3 1997 18,983 $1,912 10.1 8,024 $918 11.4 83,877 $7,537 9.0 36,344 $5,360 14.7 1998 19,211 $1,916 10.0 7,931 $912 11.5 84,606 $7,506 8.9 37,889 $5,184 13.7 1999 19,615 $1,918 9.8 8,210 $916 11.2 87,250 $7,599 8.7 35,486 $5,026 14.2 2000 19,413 $1,957 10.1 8,046 $922 11.5 84,081 $7,629 9.1 44,714 $6,338 14.2 2001 19,914 $2,350 11.8 7,953 $933 11.7 87,844 $7,977 9.1 36,372 $5,219 14.3 2002 19,189 $2,008 10.5 8,057 $971 12.0 84,156 $7,844 9.3 37,834 $5,312 14.0 113 Tnhip 5_F, AveraQe Annual Enerev Use and Cost (1962-2008) Total Residential Commercial/Industrial Other Cost Cost Cost Cost Sales per Revenue per Sales per Revenue per Sales per Revenue per Sales per Revenue per Customer per kWh Customer per kWh Customer per kWh Customer per kWh Year(kWh) Customer cents kWh Customer cents kWhl Customer (cents) {kWh) Customer ;cents 2003 19,130 $2,009 10.5 8,047 $964 12.0 81,434 $7,882 9.7 2004 19,532 $2,146 11.0 8,208 $1,021 12.4. 82,519 $8,404 10.2 2005 19,534 $2,290 11.7 8,031 $1,068 13.3 83,794 $9,114 10.9 2006 20,035 $2,573 12.8 8,108 $1,202 14.8 86,292 $10,190 11.8 2007 20,223 $2,687 13.3 7,966 $1,209 15.2 88,872 $10,961 12.3 2006 19,951 $2,939 14.7 7,926 $1,312 _ 16.5 86,717 $11,974 13.8 1) Data before 2001 from the Alaska Energy Statistics Report 2003. a) "Other" category for cost/kWh not listed before 1985 b) Total sales, revenue, and customers may exceed the sum of Residential and Commercial/Industrial. 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Five of the utilities are located in the Southcentral region while one, Golden Valley Electric Association, is located in the historic Alaska Electric Power Statistics, Yukon region. The six are: • Anchorage Municipality Light and Power (ML&P) • Chugach Electric Association (CEA) • Golden Valley Electric Association (GVEA) • Homer Electric Association (HEA) • Matanuska Electric Association (MEA) • Seward Electric System (SES) Anchorage Municipality Light and Power is responsible for producing much of its own electricity, about 94% percent. ML&P operates 11 generators between two power plants, which operate on natural gas (9) and diesel (2). The utility also operates two hydro -generators and transmits the power from the Eklutna Lake hydroelectric facility from which it keeps 53.3%, and gets a share of 25.9% from Bradley Lake. Some power is purchased from CEA, if needed. Chugach Electric Association, the largest electric utility in Alaska, is responsible for just over 36% percent of total statewide electric power generation. Chugach operates 13 generators fueled with natural gas between three power plants: Bernice, Beluga and International. CEA has about 512 megawatts of installed capacity of which 15MW (two 7.5MW generators) or about 3% is hydroelectric power from Cooper Lake. In addition, CEA purchases power from several sources: Eklutna Lake (30% share) and Bradley Lake (30.4% share). It also sells to, or buys from ML&P when necessary. Of the total available energy (2,409,006: 96% generated, 4% purchased), roughly 53% to 64% is sold for resale to other Railbelt utilities. Included in this is electricity delivered to GVEA in Fairbanks through the state-owned Intertie system. Golden Valley Electric Association provides electric power in and around the Fairbanks area. The utility generates approximately 52% percent of its total sales. GVEA's generating capability of 276 MW is supplied by four generating facilities. The Healy Power Plant is a 27 MW coal-fired unit located adjacent to the Usibelli Coal Mine. GVEA's 180 MW North Pole Power Plant is fired with diesel and naphtha, and built next to the Flint Hills refinery. The oil -fired Zehnder Power Plant in Fairbanks has an installed capacity of 42 MW. The Delta Power Plant (DPP), formerly the Chena 6 Power Plant, has an installed capacity of 27 MW. Demand is also met through 131 purchases from Aurora Energy (a private company), ML&P and CEA, and GVEA's share of Bradley Lake (16.9%). The purchases from ML&P and CEA and Bradley Lake power are transmitted via interties. Homer Electric Association has a small amount of its own generation equipment but purchases most of its power from CEA to meet customer demands. Homer Electric Association owns the Nikiski natural gas combustion turbine. During the summer months it provides 39 MW of peaking capacity and in the winter provides 42 MW. Primarily to meet commercial demand, HEA purchases their share of the Bradley Lake output (12%). Also, HEA operates and maintains the Bradley Lake facility under contract with the AEA. Matanuska Electric Association does not generate power; it purchases 100% of its power. Their power sales are from their share of the Eklutna (16.7% or less than 10,000 MWh), Bradley Lake output (13%, or about 41,000 MWh), and mostly power purchases of about 650,000 MWh from CEA. Chugach Electric Association purchases MEA's share of the Bradley Lake output then sells it back to them for distribution. Seward Electric System has its own backup and standby generation facility with six internal combustion generators with a total capacity of 13.3 MW, but primarily purchases power from CEA. In 2008, SES generated about 1,000 MWh. Chugach Electric Association purchases SES's share of Bradley Lake output (1%) and sells it back to them, similar to their role with MEA. The installed thermal capacity and share of hydroelectric units is shown in Table 7.1. 7.1 Railbelt Installed Capacity Thermal Bradley Eklutna Cooper utility Existing Lake Lake Lake Total Capacity Capacity* Capacity Capacity MEA 0 16.1 6.7 0 22.8 HEA 42 14 0 0 56 CEA 500.5 35.6 12 20 568.1 GVEA 278.1 19.8 0 0 297.9 ML&P 278.3 30.3 21.3 0 329.9 SES 0 1.2 0 0 1.2 Total 1,098.9 117 40 20 1,275.9 *Nameplate rating for Bradley Lake is 126 MW with 90 MW dispotchable and 27 MW for spinning reserve under normal conditions. Source: Black and Veatch, 2010, Railbelt Integrated Resource Plan, February. Hydroelectric Resources Currently, each of the utilities in the Railbelt region has full or partial ownership in existing hydroelectric generation facilities (Table 7.1). The hydroelectric generation plants include Bradley Lake (a 120 MW hydroelectric plant that under normal conditions dispatches up to 90 132 Table 7.2 Railbelt Hydroelectric Generation Plants Bradley Lake Eklutna Lake Cooper Lake Annual Spinning Annual Annual Percent Energy Capacity Reserves Percent Energy Capacity Percent Engery Capacity Utility Allocation (MWh) (MW) (MW) Allocation (MWh) (MW) Allocation (MWh) (MW) MEA 13.8 54,383 12.4 3.7 16.7 26,056 6.7 0 0 0 HEA 12 47,289 10.8 3.2 0 0 0 0 0 0 CEA 30.4 119,800 27.4 8.2 30 46,806 12 100 41,342 20 GVEA 16.9 66,599 15.2 4.6 0 0 0 0 0 0 ML&P 25.9 102,066 23.3 7 53.3 83,159 21.3 0 0 0 SES 1 3,941 0.9 0.3 0 0 0 0 0 0 Total 100 394,078 90 27 100 156,021 40 100 41,342 20 *Nameplate rating for Bradley Lake is 126 MW with 90 MW dispatchoble and 27 MW for spinning reserve under normal conditions. _ _ _ _ _ Source: Black and Veatch, 2010, Railbelt Integrated Resource Plan, February. MW and provides an additional 27 MW of spinning reserves), Eklutna Lake hydroelectric facility (maximum capacity of 40 MW), and Cooper Lake hydroelectric facility (20 MW of capacity). Table 7.2 gives the percent ownership, average annual energy, and capacity for each utility for each of the existing hydroelectric plants. In the existing system, hydroelectric capacity and energy allocations are based on percent ownership. The annual and monthly energy is based on the average historical energy generated at each plant for the previous nine to ten years (depending on historical plant data provided) and is presented in Table 7.3. Table 7.3 Hydroelectric Monthly and Annual Energy (MWh) Month Bradley Eklutna Cooper Lake Lake Lake January 28,688 11,153 3,696 February 29,448 10,653 3,421 March 31,737 12,374 3,967 April 28,829 12,039 3,687 May 28,643 10,094 3,854 June 31,586 13,425 4,072 July 35,372 14,547 4,361 August 37,881 17,954 3,328 September 37,728 17,494 3,388 October 37,654 14,102 2,421 November 34,152 11,452 2,198 December 32,360 10,734 2,951 Total 394,078 156,021 41,344 Source: Black and Veatch, 2010, Railbelt Integrated Resource Plan, February. 133 ALASKA RENEWABLE ENERGY Alaska has a significant renewable electrical energy portfolio (approximately 17%), consisting primarily of hydroelectric capacity in Southcentral and Southeast Alaska. The type and quantity of renewable energy generation is increasing.) The Alaska State Legislature created the Renewable Energy Fund (REF) in 2008, with the intent to appropriate $50 million annually for five years. This legislation placed Alaska near the forefront of the 50 states in funding for renewable energy. The Legislature authorized the AEA to manage the REF project application process, project evaluations, recommendations, completion of grant agreements and disbursement of funds to grantees. Since fall of 2008, AEA received more than 350 applications requesting more than $985 million for rounds one through three grant solicitation S2. Figure 8.1 shows the amount of funding allocated by type of project for rounds one through three. Figure 8.1. Funding for renewable energy fund projects, rounds 1-3, by type ($ millions r �.� Heat Recovery Biomass $11.0 $16.4 I �1.Geother Ocean/River Wind $66.0 = -- - Other $3.1 $Z'Z i Solar $0.8 Hydro $39.0 Other $0.1 Transmission $5.5 Source: Alaska Energy Authority, REF program data. Note: Includes "Round 0" $7 million funded by the Denali Commission and AEA. Hydroelectric The reporting of installed capacity of hydroelectric facilities is complicated by the ownership structure of the larger units, since they have changed over time and the reporting by different entities has not always been consistent. However, Table 8.3 includes most of the hydroelectric facilities operating in Alaska. 1 For more details and maps on Alaska renewable energy resources, see the Alaska Renewable Energy Atlas, 2009, www. akenergyauthorit .or Re ports and Presentations/EnergyAtias2OO9.ridf z Alaska Energy Authority, Renewable Energy Fund fact sheet: www.akenergyauthority.orRIFactSheets/AEA ProeramF5 ReFUND.odf 134 Between 1981 and 1985 four hydroelectric facilities were placed into service by AEA to provide power to communities in Southeast and South Central Alaska. These facilities were known as the Four Dam Pool (Table 8.1). Table 8.1 Four Dam Pool hydroelectric projects j Facility Name Communities Served Swan Lake Ketchikan Tyee _Wrangell and Petersburg Terror Lake Kodiak Solomon Gulch Source: AEA, 2010. Valdez and Glennallen In 2002 these facilities were sold by AEA to a joint agency composed of member utilities that purchased the hydropower output from these projects. In 2009, the Terror Lake and Solomon Gulch projects were sold or transferred to the respective operating utilities, and ownership of the Swan and Tyee projects was changed to a new agency entitled the Southeast Alaska Power Agency (SEAPA). Interconnection of the Swan and Tyee projects was also completed with the construction of a 57 mile intertie by SEAPA in late 2009. Also in Southeast Alaska, the Snetlisham hydroelectric facility, providing power to Juneau, was owned by the federal government until Alaska Industrial Development and Export Authority (AIDEA) took it over in 1998. Alaska Electric Light and Power operates the facility and sells its power to its ratepayers. They completed the construction of the Lake Dorothy hydroelectric plant in 2009. The City of Sitka operates two hydroelectric plants at Blue Lake and Green Lake. In Southcentral Alaska the largest hydroelectric facility in Alaska is at Bradley Lake, which is owned by AEA but operated by Homer Electric Association. The power from Bradley Lake is shared among the Railbelt utilities via the intertie according to a formal sharing agreement (Table 8.2). Table 8.2 Bradley Lake hydroelectric utility shares Utility J Share of Bradley Lake j Chugach Electric Association 30.4% Anchorage Municipal Light & Power 25.9% _ Homer Electric Association _ 12.0% Matanuska Electric Utility 13.8% Seward Electric Utility 1.0% Golden Vallev Electric Association 16.9% Source: AEA, 2010. The Eklutna hydroelectric facility was owned by the federal government until 1997 when it was jointly purchased by Anchorage Municipal Light and Power, Chugach Electric Association and Matanuska Electric Association. The facility ownership stakes are 53.3%, 30% and 16.7%, respectively. The Cooper Lake hydroelectric facility is owned and operated by Chugach Electric Association. 135 Table 8.3. Installed Hydroelectric Capacity in Alaska Name Service Area utilityr Installed Capacity (kW) Annex Creek Juneau AELP 3,600 Beaver Falls Ketchikan KEA 5,400 Black Bear Lake Prince of Wales AP&T 4,500 Blind Slough Petersburg Petersburg 2,000 Blue Lake Sitka Sitka 6,000 Bradley Lake Railbelt Shared 119,700 Chester Lake Metlakatla Metlakatla 1,000 Cooper Lake Railbelt Shared 19,400 Dewey Lakes Skagway AP&T 900 Eklutna Railbelt Shared 47,000 Falls Creek Gustavus Gustavus 800 Goat Lake Upper Lynn Canal AP&T 4,000 Gold Creek Juneau AELP 1,600 Green Lake Sitka Sitka 18,600 Humpback Creek Cordova CEC 1,250 Kasidaya Creek Skagway AP&T 3,000 Ketchikan Lakes Ketchikan Ketchikan 4,200 King Cove King Cove King Cove 850 Lake Dorothy Juneau AELP 14,300 __Larson Bay Larson Bay Larson Bay 500 Lutak Haines AP&T 250 Ouzinkie Ouzinkie Ouzinkie 150 Pelican Pelican Pelican 700 Power Creek Cordova CEC 6,000 Purple Lake Metlakatla Metlakatla 3,900 Salmon Creek Juneau AELP 6,700 Silvis Ketchikan Ketchikan 2,100 Snettisham Juneau AELP 78,200 Solomon Gulch Glen nallen-Valdez CVEA 12,000 South Fork Black Bear Prince of Wales AP&T 2,000 Swan Lake Wrang/Pet/Ketch SEAPA 22,600 Tazimina Iliamna INNEC 800 10 Mile Haines IPEC 550 Terror Lake Kodiak KEA 20,000 Town Creek Akutan Akutan 105 Tyee Wrang/Pet/Ketch SEAPA 20,000 Total operating installed capacity 434,655 Source: AEA, 2010. 136 Table 8.4. Planned New Hydroelectric Capacity in Alaska* Installed Capacity Name Service Area I Utility (kW) Chuniisax Creek Atka Atka 271 Reynolds Creek Prince of Wales AP&T 5,000 Total 5,271 *Projects with secured construction financing and all permits and final design are completed Source: AEA, 2010. 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 (Tables 8.3 and 8.4). Geothermal Ground -Source Heat Pumps Used in many other parts of the US and the world, ground -source heat pumps (GSHPs) are less common in Alaska (Table 8.5). Heat pumps operate on the same principles as refrigeration or air conditioning systems, using electricity to 'pump' heat from a cold temperature source, such as the ground or a body of water, into a warmer area such as the inside of a home. Essentially, heat pumps take advantage of the moderate temperatures in the ground to boost efficiency and reduce the operational costs of heating and/or cooling systems. Disadvantages are the high capital cost associated with installing the system, either as a series of wells or buried horizontal loops, and lower efficiency in Alaska due to the relatively cool ground temperatures. Nonetheless, several designs developed for cooler northern climes are now on the market and combined with higher expected fuel costs this technology may be becoming more viable for the Alaska market. Table 8.5. Commercial and institutional ground -source heat pumps Year Heating Capacity Location Installer I Installed (MMBtu) AEL&P Lemon Cr. Operations Center, Alaska Electric Light & 1996 —1,000 Juneau Power Juneau Airport City and Bureau of Juneau 2009-2011 1,056 Juneau Aquatic Center City and Bureau of Juneau 2010-2011 1,240 Total 3,296 Source: Alaska Energy Authority, geothermal program manager, 2010. Geothermal Electricity Production Geothermal power is a mature technology and can provide base load power with a very high availability and capacity factor. However, given the current level of technology, it is very site specific and limited to areas with an elevated geothermal gradient that is typically evidenced by hot springs, geysers and fumaroles at or near the site. To produce electricity from geothermal resources, the heat of the earth is transferred to the surface by a fluid —generally water — where its heat is used to drive a turbine. Depending on the temperature of the resource, 137 different power cycles are used to convert the heat into electricity. In moderate- to high - temperature resources (greater than—400'F) the geothermal fluid is flashed to steam before being sent through a turbine to produce electricity; this is referred to as a flash plant. In lower temperature resources, the geothermal fluid is sent through a heat exchanger, which transfers the heat to a fluid with a lower boiling point than water. In this binary cycle, the secondary fluid is then flashed to a vapor which is then used to drive a turbine. Geothermal Direct Use In cases where the geothermal resource is not sufficiently hot, or as a cascading use of spent geothermal fluid from a power plant, the geothermal fluid can be used directly for its heat content. The available direct uses for the geothermal fluid are temperature dependent, with higher temperature fluids being suitable for a greater array of purposes. For example, steam greater than 300 *F may be used to help process paper pulp, but since the pulp processing will not use all of the available heat, the steam may still be used for other industrial purposes, space heating, greenhouses, or mariculture. Currently in Alaska, there is only one developed geothermal resource by direct use method. It is operated by Chena Power in Fairbanks with an installed capacity of 400kw (Table 8.6). Aside from the traditional use of baths, geothermal fluids are used for space heating, refrigeration, and food production for which it produces and consumes about 15.5 billion BTUs. Table 8.6. Geothermal electricity production Location Installer I Year Installed Capacity Average Output Chena Hot Springs Chena Power 2006 400kW 266kWh Source: Alaska Energy Authority, geothermal program manager, 2010. Biomass Biomass energy, in the form of heat and power, is created by the combustion or gasification of carbon -based plant matter (Table 8.7). Alaska's major biomass energy resources are wood, sawmill residue, fish processing byproducts, agricultural crops and waste, and municipal waste. Biomass energy is generally considered a firm energy source, available as/when needed. Woody biomass is the most commonly used form of biomass fuel. It is used directly as firewood, or it can be processed into woodchips or densified into pellets or bricks. Processing biomass ranges from the simple (bucking logs into suitable lengths), to chipping or chunking (chippers are commonly available machinery), to the more complex (densification that involves chipping, drying, and compressing biomass into pellets, bricks, or logs). As the levels of complexity rise, the benefits of proper handling and storage of the fuel become more pronounced. Densification, however, increased the heat per volume ratio potentially reducing transportation and handling costs per Btu. Burning wood is a traditional form of home heating in Alaska. Conventional wood stoves can be found in homes and community buildings across the state. Recent technological advances have resulted in a new generation of efficient wood -fired heating systems. These hydronic (hot water) systems work by producing heat through combustion directly, or by creating 138 transportable heat by capturing the heat from burning wood in a heat -storage medium such as water. This type of system can be used to heat multiple adjacent buildings by piping heated water through an interconnected or "district" loop. This system can reduce or even eliminate the amount of heating oil needed in each building. Table 8.7. Community -level biomass thermal installations Installed Estimated Year Capacity Annual Usage Location Owner Installed MMBtu/hr MMBtu/yr Technology Dot Lake Village of Dot Lake 1998 0.95 690 Garn - cordwood - Dry Creek ----•------------------ Logging and Milling 2004 ----------- 1.2 3,500 -------------------- Decton -chip ------------------------------------------------------------------------------------------------------------------------------ Associates Tanana --------------------------------- City of Tanana 2007 0.85 1,380 Garn (2) - cordwood Copper --------------------------------------------------------------------------------------------- Regal Enterprise 2007 1.5 7,000 Decton - chip Center ------------ Craig -------------------------------------- City of Craig 2008 4 4,830 Chiptech - chip ------------------------------------------------------------------------------------------------------------------------------ Ionia Village of Ionia 2008 1 1,380 Garn (2) - cordwood --------- Homer ------------------ Barrow Mechanical ------------------------------ 2008 0.425 1,800 -- --------------- Garn - cordwood ----------------------------------------------------------------------------------------------------- Tok Alaska Gateway School 2010 4.5 8,640 ------------------------ Messersmith - chip District Gulkana Gulkana Village Council 2010 1 2,278 Garn — cordwood ---------------------------------------------------------• Tarm — pellet Haines Chilkoot Indian Association 2010 ------------ 0.37 ----------------------------------- 570 Pellergy (2) - pellet Source: Alaska Energy Authority, biomass program manager, 2010. Combined Heat and Power Combined Heat and Power (CHP) is the concurrent production of electricity or mechanical power and useful thermal energy from a single source of energy. Most applications in Alaska utilize heat recovered from diesel generators. CHIP may be regarded as a supply-side energy efficiency measure. Typical applications for heat recovery are environmental space heat for community buildings and augmented electric power generation. The most efficient use of recovered heat is to use it directly as heat. This avoids efficiency losses that occur when heat is transformed to another kind of energy. Heat recovery may use one or all of the diesel generator's waste heat sources including the exhaust stack, jacket water, and charge air. The recovered heat can be used for space heating, domestic hot water, or for tempering municipal water supplies to prevent freezing and facilitate treatment. There are promising methods for recovered heat to electric power conversion: Organic Rankine Cycle (ORC), Kalina cycle, exhaust gas turbine, and direct thermoelectric conversion systems. The Organic Rankine Cycle and Kalina cycle systems may be preferred because of their availability, ease of installation, and efficiency (Table 8.8). 139 Table 8.8. Community -level Location I Installer North Pole Chena Power biomass combined heat and power installations Year Installed Installed Capacity Technology 2010-2011 500 M Biomass fired ORC Source: Alaska Energy Authority, biomass program manager, 201a Diesel Heat Recovery Rural Alaska relies heavily on diesel engine technology as the main energy source for producing electricity and fuel oil as the predominant supply for space heating. Recovery of "waste" heat from diesel generation has great economic potential for remote Alaska communities. Typical applications for heat recovery are space heating for community buildings and augmented electric power generation. The most efficient use of waste heat is to use it directly as heat. This avoids efficiency losses that occur when heat is transformed to another kind of energy. The recovered heat can be used for space heating, domestic hot water, chilling and ice making, or for tempering municipal water supplies to prevent freezing and facilitate treatment. In Alaska, there are over 90 operational systems using recovered heat from diesel generators for space heating and water heating needs. A database is in development by the Alaska Energy Authority to document the status of all heat recovery systems. Wind Wind energy, which is abundant in Alaska, is being incorporated into more community energy systems, moving from the initial demonstration phase toward a technology being considered for many communities. Alaska's first utility wind farm was installed in 1997, when three Entegrity (formerly Atlantic Orient Corporation or AOC) turbines were erected in Kotzebue. In the next six years, the Kotzebue farm increased its capacity from 195 kW to 1.14 MW. Kotzebue was the proving ground for many of the technological challenges that Alaskans faced as additional wind turbines were erected over the next ten years. Since that first installation, significant development and innovations have occurred. The Alaska Village Electric Cooperative (AVEC) is incorporating wind systems into a number of their power systems in western Alaska. As of February 2011, 21 wind projects were completed in communities around the state (Table 8.9), but only three (in Kotzebue, Wales, and Saint Paul Island) have been operating for more than a few years. Initial funding for Kotzebue and Wales came from the U.S. Department of Energy (DOE). Beginning in 2004, the Denali Commission funded projects in five communities (Selawik, Hooper Bay, Kasigluk, Savoonga, and Toksook Bay). In 2008, the Alaska State Legislature created the Renewable Energy Fund, a competitive program established to invest in renewable energy. Wind projects have received a substantial portion of the funds available through this program, which the Alaska Energy Authority administers (Figure 8.1). The total installed capacity in these projects is approximately 13.1 MW. An additional 4 MW are currently under construction. 140 Table 8.9. Installed wind capacity. February 2011 Installed Capacity Location Installer Year Installed (M) Type of Turbines (15) Entegrity; (1) Kotzebue KotzebueEA- 1997 1,140 Vestas; (1) Northwind St. Paul Island TDX Power 1998 - 675 - (3) Vestas V-27 AVEC, KEA, and Wales NREL 2002 130 (2) Entegrity - ----------------------------------------- Port Sustainable Heiden/Pilot Energy Com. of Point AK Peninsula 2004 20 (2) 10 kW Bergey Kasigluk - -------------------- AVEC 2006 ----------------------------- 300 (3) Northwind 100 --------------------- Bering Straits Native Corp. and Nome Sitnasuak 2010 1,170 (18) Entegrity (1) Northwind 100 (1) Delta AEP 2008(100)/2010(900) 1,000 EWT 900 Native Village of Perryville-__--___---Perryville_--__-----_----2 ------------------ ------------ (10) Skystream 3------- Healy AEP 12 (5) Skystream 3.7 Tin City - •----------•.--------------------------------------------------------------------------------------- TDX Power 2008 225 Vestas V-27 Hooper Bay AVEC 2009 300 (3) Northwind 100 Kodiak Kodiak EA 2009 _ 4,500-------------- (3) GE 1.5---------- Selawik ------- --------------- AVEC ---------------------- 2003 ----------------- 260 -------------- (4)Entegrity ------------------ Toksook Bay - ------------ AVEC 2006(300)/2010(100) 400 (4) Northwind 100 ------------------ AVEC -•---------------------------------------------------------------------------------- 2009 200 (2) Northwind 100 Unalakleet UVEC 2009 600 (6) Northwind 100 - --------------------------- Gambell ----------------------------------- AVEC 2010 ---------------------------------------------------- 300 (3) Northwind 100B Chevak AVEC 2010 400 (4) Northwind 1006 Quinhagak ------------------------------------------------------------------------------------------------------------------ AVEC 2010 300 (3) Northwind 100E Mekoryuk ---------------------------------------------------------------------------------------------------------------- AVEC 2011 200 (2) Northwind 1006 Nikolski Umnak Power 2011 ------- 65 (1) Vestas V-15 --------- Aleutian Wind Sand Point Energy 2011 1,000 (2) Vestas V-39 Source: AEA wind program data, 2011. 141 DRAFT ALASKA ENERGY BALANCE A. Overview Table 9.1 and Figure 9.1 summarize the amount of energy extracted, produced, exported, or used in Alaska in 2008. 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. Compared to the 2001 Energy Statistics report, a number of data sources are no longer available. In particular, details regarding exports and imports are not presented. However, the available data still provide a reasonable snapshot of the energy flow in Alaska. Total extraction: Energy in Alaska amounted to the equivalent of about 5,090 trillion Btus in 2008. This extracted energy was in the form of coal, natural gas, crude oil, natural gas liquids, wood, waste, geothermal and water and wind power. Net Extraction: About 3,105 trillion Btus of the 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, almost 260 trillion Btus of natural gas and crude oil was used during extraction and processing of oil and gas operations. 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 just over 1,725 trillion Btus in 2008. Figure 9.2 summarizes the composition of total and net extraction of energy in Alaska. About 88% of the net energy extracted in Alaska is in the form of crude oil that is either processed in Alaska or exported. Processed Products: Alaska currently has six petroleum refineries and one natural gas processing plant that process crude oil and natural gas.4 These plants and refineries produced liquid natural gas, jet fuel, motor gasoline, and diesel. Agrium Inc. produced ammonia and urea in Alaska, but curtailed its production operations in 2007 due to limited availability of natural gas; production for 2007 was about 325,000 tonnes. Petroleum and natural gas products amount to the energy equivalent of about 365 trillion Btus. Exports: Alaska exported 1,238 trillion Btus of raw energy products, including crude oil and coal. In addition, about 75 trillion Btus of energy in the form of refined petroleum products were exported from the state. Crude oil contributed the largest share, about 90% of energy exports from the state. Electric Power: As discussed in other parts of this report, electric utilities used energy inputs to generate electricity. The utilities used as total inputs the energy equivalent of about 67 trillion Btus of coal, natural gas, liquid petroleum fuels. In addition, the equivalent of about 4 trillion 4 Alaska's six refineries are: BP Exploration Alaska Inc, Prudoe Bay; Conoco Phillips Alaska Inc., Prudoe Bay; Flint Hills Resources Alaska, LLC, North Pole; Petro Star Inc., North Pole, Valdez; Tesoro Alaska Petroleum Co., Kenai. Natural Gas terminal: Conoco Philips, Kenai Alaska LNG. 142 1*1 7140% Btus of electricity was produced from waterpower and wind. In the process of generating electricity, utilities used 45 trillion Btus of energy. The utilities generated as output the energy equivalent of 22 trillion Btus of generated electric power for sales to consumers.s As shown in Figure 9.3, most of the electric power generated by utilities was produced from natural gas. Imports: Alaska imported a variety of refined petroleum products. These products were shipped from California (13%), Washington (41%), Canada (27%) and other foreign locations (18%). The equivalent of about 23 trillion Btus was imported in the form of refined petroleum products. Net Domestic Consumption is composed of five components: residential, commercial, industrial, transportation and electric sector consumption. Notably, net domestic consumption does not include energy used by utilities for electric power generation or energy used during petroleum product processing. Net domestic consumption in Alaska amounted to 444 trillion Btus in 2008. Transportation consumption was by far the largest component of net domestic consumption and amounted to 215 trillion Btus, followed by the electric sector which used 67 trillion Btus as inputs to produce electricity. Residential consumption totaled about 33 trillion Btus. Commercial consumption was about 38 trillion Btus. Industrial consumption (including military bases) totaled 51 trillion Btus. About 41 trillion Btus were consumed in the state but we were unable to attribute them to a particular sector. 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: • Transportation use: The single largest consumption in transportation was in the form of jet fuel which consumed the energy equivalent of 135 trillion Btus (24 million barrels). A distant second was consumption of about 41 trillion Btus (7 million barrels) of distillate fuel. Motor Gasoline consumption was about 34 trillion Btus (7 million barrels). Consumption of other petroleum products amounted to about 3 trillion Btus. Industrial uses: Alaska industries (other than oil and gas extraction or processing) used 51 trillion Btus 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. • Electric Sector: Electric utilities in Alaska consumed about 67 trillion Btus and generated about 6.5 million megawatt -hours of electricity. Other uses: After accounting for transportation and industrial uses, the remaining 71 trillion Btus were used primarily by residential and commercial consumers for a variety of uses. Also, about 41 trillion Btus were consumed in the state but we were unable to attribute them to a particular sector. 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. 143 G ■ § 2 ~ / � Q 04 2 § � o, f � /2 � � \\ 0 2\ § �kk §� _e K �2 » 3 Cl! a f ) \ \ \ &§§ R§] \_ � \k _ ^ /� �) \\CO � LO 'U- u \ kj 2 _ _ 2))cq k \k @ mr g e - f7¥7 e1I2 � § 0 :E Do f § § § \ / & CR E} ® ]o - h=�t# 2 §C4 - L EJ U- a ) § kƒ / k 2 � * / g \ � � * \k 42 \ CL k / LLJ / k § 2 ) / Lo ) IL 8 ) \ \ \ / § E R ) { / f - 1 k/ Iui & I 0 a a'■ )_{ m / 7\ . £ - - a k § § k ■ 2 « 3 3 ; \ \ \ ƒ % \ + § & ) ] f ) / d 6 / § CO � / 2 » k W O Z 40 o a o 0 0 o o Mo o a c c Z c o0 o 0-a h a -o Q, a, u a M a a o O Z3 p 0 U U kD kn C.)O O Ln O N O C p -Q `� O 4 W �.; O C ° a° ° -Q Qj L- � o. w °o o '� a Cl u i O i a m u o q,� c a 3 � U a s o O o 3 a Ln 3 �, a o ui Ln— a QJ a' 41 i -� i Lr) Q M U = 0 a) +, 00tn OOi Q� in N ap, a., Ln a p N 4 u O= O O O �, M v p p +r 4 p 0�QjO O CJ O i o v i u -a +, i O v a -Q o 0 a o a Q, v Q, O Q v s Q, ° o °' v o a ° ion a �o�Q, o•w� z v a u Q, _ ° a a W aLn o o c a o a Qj M �=' � a, o o N 13 Q z o Q c � aQj o °a Q�i �� O i a Ln N a Q, i O h en a 00 a° °' h °�' � a a o Q N Ln QJ v v Q, H � 'a Ln Ln n�, Q a O a a = 4� ti o a uQj Q a s c a v� 3 u U W o a �, +r a ° o C W o c rn o a-Q Q; v Q v C.)o� u a v o w c Q, > O o° o a W t°� v n`, o Qj Ln v,` i v 3 a � >.o° Z o o a o a a o z i .Q a o Q, _ Ln LnU tn .Q ate+ U N f� j r+ UN -C3 'a a +—, O C O QO p33 0'WaWk a i 'u x pteQi � �a.k k O Qj 'uvO 4 O- N 1pON4- a ,++ 3 W y o o .Q c v� cx w o o a o, o a a a° '� h fi y 4 'ate' o> o � `� Qom' o� a u o c W O Q v o a o� o Ln i +, � O a— CJ C h O i aJ O C al i 0 a W Ou a 'pi., C N O a q~ W `~ Q L ti a 13) a o 2 a a o a c o �� •� O a `vvQj � 4 v Lnma a` v> o E o a s cc� Q- oo, ? zz 0- �..� z O O' O O co LD § 0 k Ln � 2 2 0 0 = 3 3 n m o C,4 m O q c� cn R 0 o M Ln t C,� C,� o o cy� -, C)) A r, v-i r, a) o Ln 00-) LnC14 N. r- c r- � � t 6 aj . 0 a 2 U Z U R w 0(D I a � § q \ k CL © Q k o% - & $) \ O @ C3 f k k o§ 0 3 K / \ \ & Ln ? k k k 3 } o a o "n-6 m® U f 2» avj ® r f , & \ k \ \ 5 \ \ \ k/ % k K \ Q) a i %/ E $ E § /) \ o u / m a -r- 2 Z3 b \ £ 7 { £ o 0 e = / & \ ¢ \ 7 d \ L- k ( § k { & ° E I G ] ° $ $ 2 . 12Z3 In t r t3 » E \ k § \ \ o E / \ @ � / 2 ` @ � § k E o o c ® % G\ k X @'/ & -a(\ In� m § E zi & \ § � / k � 7 § B \ k m § a \ ( Qj CS /(k � t \ / -C3 e ± � « C3 « a , C3 00 \ � $ k/ C\%s-- Q«Qj 7 e } @ ®o § t o 7 Ino ,/$ 2 2 a G§ 2 E o G § B \ \ / § \) k / \ 2 § \ z «% . @ a 2 I % - o ) � E Qj% G�2233332« 2 Q, u Q 2 a 2 e« _o \ ° ® § § 2 2 § 2@ 00 Oj b§ 4 o 8 3[£/ o § \ \ \ o \ .) \ \ �£ mas2 FIGURE 9.2 Composition of total energy extracted Composition of Total Energy Extracted Hydro & Wind Electric Power Coal 0% 1% Gas Used during ----. Extraction ~ 5% Coal Net Oil Extraction 30% Net Oil Extraction Net Gas Extraction Reinjected Gas Gas Used during Extraction Net Gas Extraction Hydro & Wind Electric 3% Power Reinjected Gas 61% Source: ISER Calculations Figure 9.3 Utility electricity generation by fuel type Wind Hydro p% Oil 17% 16% Coal 6% Source: ISER Calculations 148 Gas 61% ❑ Oil Gas Coal Hydro Wind B. Commodities Table 9.2 summarizes the quantities of energy commodities extracted, processed, exported, or used in Alaska. Coal: In 2008, about 1,538,000 short tons of coal were extracted from the Usibelli Coal Mine near Healy, Alaska. About 427,000 short tons were used as inputs for electric power generation in Alaska. About 579,000 short tons were shipped through the Port of Seward to mostly South Korea and some sporadic exports to Chile. Also, 558,000 short tons were sold to industrial and commercial customers, including Eielson Air Force Base and the University of Alaska Fairbanks.6 Doyon Utilities consumed about 240,000 short tons of coal to provide Fort Greely, Fort Richardson and Fort Wainwright heating and electric services. Other consumers also used the coal for heating and power generation. Natural Gas: Almost 3,400 billion cubic feet of natural gas were extracted in 2008 from the North Slope and Cook Inlet. About 89% of this gas was re -injected into the ground to assist with lifting oil to the surface on the North Slope. Another 252 billion cubic feet were used to produce power and heat for North Slope facilities and the TAPS pump stations. The Phillips Petroleum gas -to -liquids plant near Nikiski processed natural gas from Cook Inlet into liquid natural gas and exported 27 billion cubic feet. About 43 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 46 billion cubic feet of natural gas, much of it for heating. Petroleum: In 2008, 250 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 61 million barrels into refined products. All of the crude oil that was not refined in state was exported to the Lower 48 or Pacific Rim markets, about 211 barrels. Most of the jet fuel refined in the state is used as fuel for international air carriers flying through the state. Alaska consumers use about 12 million barrels of distillate fuel, 24 million barrels of jet fuel, and 7 million barrels of motor gasoline. Most of these petroleum products come from Alaska refiners. However, Alaska also imported about 4 million barrels of refined petroleum products. Alaska refineries also export some motor gasoline. Electricity: Other chapters in this report discuss the generation and use of electricity in more detail. Residential and commercial consumers use most of the 6.5 million megawatt hours of electric power generated in Alaska. Alaska neither exports nor imports electric power. 6 From Usibelli Coal Mine web page http://www.usibelli.com/who.html 149 co Q Q m ƒ � 3 0 E E 0 Q c 2 � 3 k 2 m tv ui 0 � E E � q � � cc u%@ - - 2 \ 0&ƒ 3 F- _ 7\E/ - 2 2 _0 2 � % - £14 &± \ - a \ k\ r �§p �k2 o §j IIL kƒ k\ } - e // CD \ /m 7\ƒ m G 2� w% N 2�3 = -gf2 ±/ 2 ,4 2\ \ /k CM / co 'n e m ^ % m - » c _ Q \ _- \jƒ m \d � - - � � )2 &/ E < 2 a CL q 7 = § E o \ \ 2 © UJ § \ - \ d k# 2- k/ f 2 b 3 2» k k / \ w / � f § k « ( # \ 7 d \ E LLI2 ° Fo � \ E k § } k k\ƒ p �0 o/ \ \ f + .a } 13 7 & m 5 � / k \ Ln o �; a o i 0 c, o L o �'a o o v= a 0 3 Q a Q o a a v a C3 va- d vC•k-r%j O Qj .�a aO. ;Q Oc,o� 0�U CC Ii o o p a�^ .Q�. �va N N v CZa)i C = to) N C O h am., V N Q O U N Ui U 4iul Ln w i a a., a C 4� C 4- '- a) Q. °i v Q o o° 0 0 u a v� a, v Qj c, h a C� C o h o U n, ° a a Ln v c v ti o� h� E Q .� W o�, o c o n Q. 4, o a c LL, o= - o a a C� Qj o Ln ° H� a v v V a g o o a u a — 4-Q CCO NOp tL Oaat Q a N 3o Ln W �-N v aaW 0 p Ln L LL° I Lo N E i u Cu o c, >., CL Ln a Cp CL C Ina� Q LLLJ o voi C0 .Q °�' O °' M o vas °) •� CL ° E o o o o a a 4- LL ° a O° C o c va � a 4 n, ° aULn v' v o o° ,o Z i k6 0 a v o `L � a a C- QjcV,13 a Q O N a y O >. Q� O i {=' O �. u u � u o O O z— E a G° O a W +.. O ++ `ti ` +, p . V Lnj N i O p�j N >, y vLf) O u p a a N 41 W A N yp O � Qj ° O O O W U Z C 3 O Z N a.; O O° a 4 LL o`", o a a c t a a a a _O - `ate `a 3 u`, LCC u Eo LL,CaO ac� � v o o o a o 0 o a a o a a a c p c U Z O; U U 'C U U O O U Z Z Z a U I� O .� l6 O ti N M Ct Ln °z~ 14 Ln C. 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 1960s, shown below in Figure 9.4. When oil and gas production began on the North Slope in the late 1970s, natural gas consumption by industrial users increased dramatically because its use 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 9.4 Consumption per capita of energy in Alaska M a M V Gl G m c 0 2 1,400.000 1,200.000 1,000.000 800.000 600.000 400.000 { 200.000 0.000 O M LO 0) N Ln W ri cf I, O M Lo M N Ln W Lo Lo LD l0 r� r- N W W W Ol 0) M 0) O O O M 01 M M M 0) M M M 0) 0) M 0) 0) O O O a-1 ri —1 1-I r-I a 4 ri -i ri rl ci -4 a--4 a-q N N N Natural Gas Coal Motor Gasoline Distillate Fuel Jet Fuel Other Petroleum Products Renewable Note: The US Energy Information Agency estimates of energy consumption include energy consumed during oil and gas extraction. Source: US Energy Information Agency. Natural gas has consistently been the least expensive form of energy and averaged about $3.27 per million Btu (Figure 9.5). However, prices have risen sharply over the last decade. Since 2000, natural gas prices averaged $4.30 per million Btu. Electricity became less expensive over time as more power was generated from relatively cheaper natural gas (Figure 152 9.6). The price of petroleum products closely follows the price of crude oil over time (Figure 9.7). FIGURE 9.5. Average price of natural gas for all consumers in Alaska $/.00 $6.50 $6.00 m $5.50 c $5.00 E $4.50 a $4.00 Vl $3.50 0 $3.00 o $2.50 N c $2.00 R c $1.50 Q $1.00 $0.50 $0.00 'AO KV n� # 1b 4a0 cb1 �D 'b10 'b(b oi0 '4V oi1k �10 oi�b o0 61- OP` OHO O� -y5 4) y� y� ,yam y0 y� y�i ti°� ya .,� ti° yam, 4 ,yam, 10 43 1) ,y0 -P Source: US Energy Information Agency FIGURE 9.6 Average price of electricity for all consumers $60 r-- c 0 $50 L d y $40 o m $30 w 0 N $20 Y C H $10 c 0 u $0 �O ^`�' ^O ^(° ^`b 4Q� rV ' Cb - , �b`b �O 0`1 0j0 �(o o`b o0 01 Q Q z ti 49 31 ti� ly ti� ly y 1�1 ti� * * 1�1 Source: US Energy Information Agency 153 FIGURE 9.7 Average prices of petroleum products in Alaska $35 $30 m c $25 L c $20 L m $5 ^�i ^�i ti ti ti H ti ti ti ti "�i ^�i N ti ti N ti ti N N Source: US Energy Information Administration Motor Gasoline —4o4 Distiallate Fuel -- Jet Fuel Prices of energy vary significantly throughout the state. The Cooperative Extension Service of the University of Alaska Fairbanks has conducted the Alaska Food Cost Survey since 1996. The survey includes prices for different types of energy that households depend on for electricity and space heating. The Figures 9.8 to 9.12 show prices overtime in four selected Alaska communities, Anchorage, Bethel, Juneau and Nome, for electricity, heating oil, gasoline, and propane. Prices for electricity remained relatively stable for Anchorage and Juneau, which obtain their electricity mostly from natural gas and hydroelectric generation, respectively. On the other hand, prices for Bethel and Nome were more variable as the prices of crude and diesel fluctuate; these communities also have significantly higher prices.' Heating oil, gasoline and propane follow very similar trends though gasoline has slightly higher prices than heating oil. Both types of fuel have sharply and steadily increase over the last decade and are expected to continue rising over time. 1 UAF Cooperative Extension Service data include PCE subsidies. 154 FIGURE 9.8 Price for electricity over time by community $0.40 $0.35 $0.30 a $0.25 -a $0.20 c 'A° $0.15 c 0 $0.10 0 o $0.05 N $0.00 05 0^ 0) �� O° O~ Ory O� O� Oh OHO O^ O� O� N Anchorage Juneau Nome Bethel Source: Alaska Food Cost Survey, Cooperative Extension Services at the University of Alaska Fairbanks. Nome and Bethel prices include PCE subsidy offsets. FIGURE 9.9 Price of a gallon of heating oil over time by community 7 6 m 5 0 0 c 4 c 3 0 U w 0 2 0 N 1 0 '0 do e° ti� ti� ti� do ,yo ,yo ,yo ,yo yo yo ,yo ,yo ,yo ,yo Anchorage —+ Bethel Nome Juneau Source: Alaska Food Cost Survey, Cooperative Extension Services at the University of Alaska Fairbanks. 155 FIGURE 9.10 Price of a gallon of gasoline over time by community $6 $5 $1 $0 Cp' A ��s ��� O00 O0'y DO`L OZb OOA OOh OO"o 0�A OO�b OOoi OyO ti ti ti ti ti ti ti ti ti ti ti ti ti ti ti Anchorage Bethel Nome Juneau Source: Alaska Food Cost Survey, Cooperative Extension Services at the University of Alaska Fairbanks. FIGURE 9.11 Price of a gallon of propane over time by community 9 8 7 fA L 1d 6 0 G c 5 M c 4 0 U 0 3 0 N I] 1 -0ti�OO�OOO� O� ti0 ,- - - 0OO� � & yti0 ti qti* * * * * * 40 * Anchorage �-r Bethel Juneau Nome Source: Alaska Food Cost Survey, Cooperative Extension Services at the University of Alaska Fairbanks. 156 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 Usibelli 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 railroad, barge and/or road. A small amount of petroleum products are flown to remote rural villages. We found insufficient 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: Two of the primary determinants of residential consumption of energy are housing characteristics and heating degree days. Residents use a number of different fuels for space and water heating (Table 9.13). Variations in housing stock characteristics across the state partially explain regional variations in energy use. Since the 2010 Census data are not yet available, the information below is from the 2000 US Census is the same as in the previous report. 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 9.13 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 9.14 summarizes the number of heating degree-days for selected places in Alaska as an indication of the variation in space heating requirements in different regions of Alaska. 157 Table 9.3. Percent of housing units within each region using each type of fuel Region NG/Propane Fuel oil Electricity I Wood I Other" Alaska ------------ 50% -------------- 34% ..-------------------------------------- 10% 4% ------- 1% ------ Railbelt 63% 23% 10% 3% 2% ------- --------------------------------------------------------------------------------------- Southeast --------------------------------------------- 4% 70% 16% 9% 1% Rest of state 8% 79% 3% 10% 1% Source: American Community Survey, 5 year average from 2005-2009. Figure 9.12. Percent of housing units within each region using each type of fuel 90 % 80% 70% 60% 50% 40% 30% 20% 10% 0% NG/Propane Fuel oil Electricity Wood Other" Alaska Railbelt Southeast Rest of state Source: American Community Survey, 5 year average from 2005-2009. Table A-iL- percent of housing units within each region with number of rooms Region None One Two Three Four or Five a More Mean Total Railbelt 4% ---------o 13% ---------o 27% ---------o 37% ---------o 14% ----------------------------- 4% 3 212,590 -- ------------------- Southeast ----------------------------------------------------- o 5/ 17/ 27/ 35% 12/ — ------------------------------------------ 4/0 2 34,358 Other 12% 16% 29% 30% 10% 3% 2 33,238 State 5% 14% 28% 36% 13% 4% 2 280,186 Source: American Community Survey, 5 year average from 2005-2009. 158 Table 9'5:Heatima deareedavmmmom%hiv averaeainselect uimmesin Alaska Region Place I Heating Degree Days (base of 65 Degrees F) Anchorage _________ _____1U�13__ Fairbanks ---------- B�O -- -------------- RaiUbmlt Homer �����_���_�_�_ 9,�6 --------------'-----------------------_---� Ta|kemtna -----------'--- 113S2 -' --' --------------'--- Valdez 10,530 Annette Southeast-------------'-'-----'----------------------- Yakutat 6�� 9,346 0urn�� -------------------'----'------------------------- 1�967 Beth --------------------'------------------------- ��927 Be�les --------------'- -'----------- ��S82 - --'---- --' --- ___8igDeka___________________13,427-------------- Cold �� -------------------------------------------- 97� Gu|�na �7� Other-------------'-------------------------------' Kin8Sahnon____._____________11�47_______________ Kodiak ---------------------' 8,646 -'-------------------- Kotzebue - -------------------------- ��707 -----------'- ---- McGrath -----'--------'----------------------' ��2O4 Nome ------------------------------------ 14I8U ------------------------------------- 159 F. Sources of Data Extraction: Data for the amounts of natural gas, and natural gas liquid extraction and re- injection are from the Alaska Department of Natural Resources, Division of Oil and Gas, 2009 Annual Report. Coal extraction is from the US Energy Information Administration, Annual Coal Report. Previous estimates of crude oil and natural gas used during extraction were available from Division of Oil and Gas Annual Reports but are not available for more recent years. Exports: Estimates of exports are available from the US Army Corps of Engineers, Waterborne Commerce of the US. Figures for crude oil and refined petroleum products are given in short tons. Conversion factors from metric tons to barrels of crude oil range from 6.95 to 7.33 barrels per metric ton. For this energy balance estimate we used 7 barrels per metric ton. Conversion factors for refined petroleum products vary by product type; we used a conversion factor of 8.03 barrels per Metric Ton, an average of the conversion factors for diesel, motor gasoline and jet fuel. For these conversion factors, we used the Environmental Science & Technology Centre, Environment Canada Spills Technology Databases, Oil Properties database, http:liwww.etc-cte.ec.gc.ca/databases/OiI Pro pertiesloiI A e.html. LNG Exports were obtained from 2008 Conoco Phillips Fact Book. Petroleum Refining and Natural Gas Processing: As mentioned above, the Department of Natural Resources, Division of Oil and Gas Annual Report no longer includes statistics that provide estimates of energy used in refining and processing. Consumption data from the Energy Information agency provides information on industry consumption of Natural Gas and fuel used as lease and plant fuel and as pipeline fuel. EIA's estimate for pipeline fuel was used as estimate for 'processing use'. Petroleum Product Sales: In the 2003 report, petroleum products sales by refiners were estimated using a combination of data from the US Energy Information Agency, Annual Petroleum Report and the Department of Natural Resources, Division of Oil and Gas, Annual Report for 2000 "Fuel Consumption History." The DNR report contained data from the Alaska Department of Revenue "Motor Fuel Activity Reports" that included detailed sales information about fuel sold in Alaska; however that information is no longer available. Only data from the US Energy Information Agency are still available but alone are insufficient to estimate refinery petroleum product sales by type of fuel. Electricity: See the Appendix D of this report for sources details. Consumption by sector was obtained from the US Energy Information Agency, State Energy Data System. Final Consumption: Final consumption of all commodities was obtained through the US Energy Information Agency, State Energy Data System. Conversion Factors: The conversion factors for converting commodity units (such as short tons, barrels, and cubic feet) to Btus are from the U.S. Energy Information Administration, 160 which estimates conversion factors for each commodity for each state and year. The conversion factors used in our calculations appear along the bottom of Table 9.1 and also in Table 9.6 below. Table 9.6: Conversion Factors Used to Convert Commodity Units to Btus Commodity Conversion Factor I Units Coal - ---------------------- 19.9880 --------------------- Million Btu per short ton ------------------------------- Natural Gas --------------------------- 1.028 Thousand Btu per cubic foot Petroleum ------------------------------------------------------------------------------------------------ 5.8 Million Btu per barrel Crude Oil --- -------------------------------------- 5.8 -.--_-------------_------------ Million Btu per barrel Natural Gas Liquids --------------------------------------------- 3.7040 --- Million Btu per barrel Distillate Fuel Disti-liat-e-Fuel ------------------------------ --------------------- 5.825 -------------------- -------------------------- Million Btu per barrel Fuel ------------------------------------------------------------------------------------------------- 5.670 Million Btu per barrel Motor Gasoline ----- -- --- -- - -------------------------------- 5.230 Million Btu per barrel Other Petroleum ----- ------------------------------------ Products -------- ---- 6.0650 Million Btu per barrel ----------------- Naphtha --------------------------------- ------------------------ 114,692 --------------------------- Btu ergall-on Heavy Atmospheric Gas Oil ------- 139,822 ----------------------------------------------------------- Btu per gallon Wood --------------------- 20.0000 Million Btu per thousand cord Electricity ----- - -- ------------------------------------------- 3.4120 Btu per kWh Source: Energy Information Agency, 2008 161 Appendix A Glossary of TerMS2 Alaska Energy Authority (AEA): A public corporation of the state with a separate and independent legal existence with the mission to construct, acquire, finance, and operate power projects and facilities that utilize Alaska's natural resources to produce electricity and heat. http:llwww.akenerguauthority.org/ Auxiliary Generator: A generator at the electric plant site that provides power for the operation of the electrical generating equipment itself, including related demands such as plant lighting, during periods when the electric plant is not operating and power is unavailable from the grid. A black start generator used to start main central station generators is considered to be an auxiliary generator. Backup (Standby) Generator: A generator that is used only for test purposes, or in the event of an emergency, such as a shortage of power needed to meet customer load requirements. Barrel (bbl): A unit of volume equal to 42 U.S. gallons. Bituminous coal: A dense coal, usually black, sometimes dark brown, often with well-defined bands of bright and dull material, used primarily as fuel in steam -electric power generation, with substantial quantities also used for heat and power applications in manufacturing and to make coke. Bituminous coal is the most abundant coal in active U.S. mining regions. Its moisture content usually is less than 20%. The heat content of bituminous coal ranges from 21 to 30 million BTU per ton on a moist, mineral -matter -free basis. The heat content of bituminous coal consumed in the United States averages 24 million BTU per ton, on the as - received basis (i.e. containing both inherent moisture and mineral matter). British Thermal Unit: The British thermal unit (BTU or Btu) is a traditional unit of energy equal to about 1.06 kilojoules. It is approximately the amount of energy needed to heat 1 pound (0.454 kg) of waterl OF (0.556 *Q. It is used in the power, steam generation, heating and air conditioning industries. In North America, the term "BTU" is used to describe the heat value (energy content) of fuels, and also to describe the power of heating and cooling systems. When used as a unit of power, BTU per hour (BTU/h) is the correct unit, though this is often abbreviated to just "BTU". Capital Cost: The cost of field development, plant construction, and the equipment required for industry operations. 2 U.S. Energy Information Administration glossary posted at www.eia.doe.gov/ plus multiple sources for additional Alaska specific terms. 162 Climate Change: A term used to refer to all forms of climatic inconsistency, but especially to significant change from one prevailing climatic condition to another. In some cases, "climate change" has been used synonymously with the term "global warming"; scientists, however, tend to use the term in a wider sense inclusive of natural changes in climate, including climatic cooling. Coal: A readily combustible black or brownish -black rock whose composition, including inherent moisture, consists of more than 50% by weight and more than 70% by volume of carbonaceous material. It is formed from plant remains that have been compacted, hardened, chemically altered, and metamorphosed by heat and pressure over geologic time. It is estimated that Alaska holds about 15% of the world's coal resources, amounting to 170 billion identified short tons. Major coal provinces include Northern Alaska, the Nenana area, Cook Inlet — Matanuska Valley, the Alaska Peninsula, and in the Gulf of Alaska and the Bering River. Alaska coals exhibit low metallic trace elements, good ash -fusion characteristics, and low nitrogen content making them favorable for meeting environmental constraints on combustion in power plants. Cogeneration system: A system using a common energy source to produce both electricity and thermal energy 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. Combustion: Chemical oxidation accompanied by the generation of light and heat. Commercial Sector: An energy -consuming sector that consists of service -providing facilities and equipment of businesses; Federal, State, and local governments; and other private and public organizations, such as religious, social, or fraternal groups. The commercial sector includes institutional living quarters. It also includes sewage treatment facilities. Common uses of energy associated with this sector include space heating, water heating, air conditioning, lighting, refrigeration, cooking, and running a wide variety of other equipment. Note: This sector includes generators that produce electricity and/or useful thermal output primarily to support the activities of the above -mentioned commercial establishments. Consumer (energy): Any individually metered dwelling, building, establishment, or location. Diesel #1: Also known as DF1 or Jet A. Diesel #1 is commonly used as heating fuel throughout most of northern rural AK. Diesel #1 has a lower gel temperature than Diesel #2 which is sold for heating fuel in warmer climates. Diesel #1 is same fuel the refineries sell as Jet fuel (Jet A), and in many tank farms it is stored as Jet A until sold as DF1. 163 Diesel #2: Is commonly used throughout the US. In Alaska it is used for marine and highway diesel as well as heating fuel in warmer regions. Diesel #2 is preferred over #1 where it is warm enough as it has higher energy content. Diesel Fuel: A fuel composed of distillates obtained in petroleum refining operation or blends of such distillates with residual oil used in motor vehicles. The boiling point and specific gravity are higher for diesel fuels than for gasoline. Distillate Fuel Oil: A generic name for a refined petroleum product. It can refer to diesel, heating fuel or jet fuel. Electricity: A form of energy characterized by the presence and motion of elementary charged particles generated by friction, induction, or chemical change. Energy Balance: The difference between the total incoming and total outgoing energy. When the energy budget is balanced, the system neither gains nor loses energy. Energy Information Agency (EIA): An independent agency within the U.S. Department of Energy that develops surveys, collects energy data, and analyzes and models energy issues. http://www.eia.doe.gov/ Exports: Shipments of goods from within the 50 States and the District of Columbia to U.S. possessions and territories or to foreign countries. Fuel: Any material substance that can be consumed to supply heat, power, or mechanical energy. Included are petroleum, coal, and natural gas (the fossil fuels), and other consumable materials, such as uranium, biomass, and hydrogen. Furnished without payment (power): The amount of electricity furnished by the electric utility without charge, such as a municipality under a franchise agreement or for public street and highway lighting. It does not included energy consumed by the utility. Gallon: A volumetric measure equal to four quarts (231 cubic inches) used to measure fuel oil. Gas: A non -solid, non -liquid combustible energy source that includes natural gas, coke -oven gas, blast -furnace gas, and refinery gas. Grid: The layout of an electrical distribution system. Gross Domestic Disposition: The total amount of energy available for sale in the domestic region, i.e. energy produced for sale in the domestic region in addition to energy imported for sale within the domestic region. Gross Extraction: The total amount of fuel obtained or produced by a power production plant. 164 Gross Generation: The total amount of electric energy produced by generating units and measured at the generating terminal in kilowatt-hours (kWh) or megawatt hours (MWh). Heating Degree Days (HDD): A measure of how cold a location is over a period of time relative to a base temperature, most commonly specified as 65 degrees Fahrenheit. The measure is computed for each day by subtracting the average of the day's high and low temperatures from the base temperature (65 degrees), with negative values set equal to zero. Each day's heating degree days are summed to create a heating degree day measure for a specified reference period. Heating degree days are used in energy analysis as an indicator of space heating energy requirements or use. Hydroelectric Power: The use of flowing water to produce electrical energy. Imports: Receipts of goods into the 50 States and the District of Columbia from U.S. possessions and territories or from foreign countries. Industrial Sector: An energy -consuming sector that consists of all facilities and equipment used for producing, processing, or assembling goods. The industrial sector encompasses the following types of activity: manufacturing, agriculture, timber harvest and wood processing, fishing and fish processing, hunting, mining, oil and gas extraction, and construction. Overall energy use in this sector is largely for process heat and cooling and powering machinery, with lesser amounts used for facility heating, air conditioning, and lighting. Fossil fuels are also used as raw material inputs to manufactured products. Note: This sector includes generators that produce electricity and/or useful thermal output primarily to support the above -mentioned industrial activities. Injections: Natural gas injected into storage reservoirs. Installed Capacity: The maximum theoretical production output of a plant, based either on nameplate capacity or actual (practically determined) capacity. Internal Combustion: The process where fuel is burned, or combusted, inside a cylinder, such as a diesel engine, producing power directly as opposed to fuel burning externally, such as in a steam engine. The term internal combustion engine usually refers to an engine in which combustion is intermittent, such as the more familiar four-stroke and two-stroke piston engines. A second class of internal combustion engines uses continuous combustion: gas turbines, jet engines and most rocket engines. Kilowatt-hour (kWh): A unit of energy equal to one kW applied for one hour; running a one kW hair dryer for one hour would dissipate one kWh of electrical energy as heat. Also, one kWh is equivalent to one thousand watt hours. Kilowatt (kW): One thousand watts of electricity (See Watt). 165 Load (Electric): Amount of electricity required to meet customer demand at any given time. MCF: One thousand cubic feet. Megawatt (MW): One million watts of electricity (See Watt). Mining: An energy -consuming subsector of the industrial sector that consists of all facilities and equipment used to extract energy and mineral resources. Nameplate Capacity: The maximum rated output of an electric power production unit (i.e. generator, prime mover) under specific conditions designated by the manufacturer. Capacity is usually indicated on a nameplate physically attached to the generator. Natural Gas: Gas in place at the time that a reservoir was converted to use as an underground storage reservoir in contrast to injected gas volumes. Net Capacity: The maximum load that an electrical apparatus (i.e. generating unit or station) can carry, not including use by the electrical apparatus. Net Domestic Disposition: The total amount of energy produced in the domestic region that is available for sale within the domestic region, i.e. not including energy use by producers or energy exported for sale outside of the domestic region. Net Extraction: The total amount of fuel obtained or produced by a power production plant, not including electric energy use by the plants. Net Generation: The amount of gross generation not including 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. Oil: A mixture of hydrocarbons usually existing in the liquid state in natural underground pools or reservoirs. Gas is often found in association with oil (See Petroleum). O&M: Operations and maintenance Other: The "other" category is defined as representing electricity consumers not elsewhere classified. This category includes public street and highway lighting service, public authority service to public authorities, railroad and railway service, and interdepartmental services. Peak: The amount of electricity required to meet customer demand at its highest. The summer peak period begins June 1st and ends September 301h, and the winter peak period begins December 1st and ends March 31st 166 Petroleum: A broadly defined class of liquid hydrocarbon mixtures. Included are crude oil, lease condensate, unfinished oils, refined products obtained from the processing of crude oil, and natural gas plant liquids. Note: Volumes of finished petroleum products include non - hydrocarbon compounds, such as additives and detergents, after they have been blended into the products. Petroleum Products: Petroleum products are obtained from the processing of crude oil (including lease condensate), natural gas, and other hydrocarbon compounds. Petroleum products include unfinished oils, liquefied petroleum gases, pentanes plus, aviation gasoline, motor gasoline, naphtha -type jet fuel, kerosene -type jet fuel, kerosene, distillate fuel oil, residual fuel oil, petrochemical feedstocks, special naphthas, lubricants, waxes, petroleum coke, asphalt, road oil, still gas, and miscellaneous products Plant: A term commonly used either as a synonym for an industrial establishment or a generating facility or to refer to a particular process within an establishment. Power: The rate of producing, transferring, or using energy that is capable of doing work, most commonly associated with electricity. Power is measured in watts and often expressed in kilowatts (kW) or megawatts (MW). Power Cost Equalization Program (PCE): Participating utilities receive state funding to reduce the charge to consumers in rural areas where prices can be three to five times higher than prices in urban areas. 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). Prime Mover Prime Mover Description (U.S. EIA) Code 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 Engine (diesel, piston) CA........... Combined Cycle Steam Part CT........... Combined Cycle Combustion Turbine Part CS........... Combined Cycle Single Shaft (combustion turbine and steam turbine share a single generator) CC........... Combined Cycle - Total Unit HY........... Hydraulic Turbine (includes turbines associated with delivery of water by pipeline) PS........... Hydraulic Turbine — Reversible (pumped storage) BT........... Turbines used in a binary cycle such as geothermal 167 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 in planning stage) Pro Forma: A Latin term means "for the sake of form," it describes a method of calculating financial results in order to emphasize either current or projected figures. Purchased Capacity: The amount of energy and capacity available for purchase from outside the system. Railbelt: The portion of Alaska that is near the Alaska Railroad, generally including Fairbanks, Anchorage, the communities between these two cities, and the Kenai Peninsula. Refinery: An installation that manufactures finished petroleum products from crude oil, unfinished oils, natural gas liquids, other hydrocarbons, and oxygenates. Reinjected: The forcing of gas under pressure into an oil reservoir in an attempt to increase recovery. Renewable Energy Fund (REF): Established by the Alaska State Legislature and administered by the Alaska Energy Authority to competitively award grants to qualified applicants for renewable energy projects. Renewable Energy Resources: 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. Residential Sector: An energy -consuming sector that consists of living quarters for private households. Common uses of energy associated with this sector include space heating, water heating, air conditioning, lighting, refrigeration, cooking, and running a variety of other appliances. The residential sector excludes institutional living quarters. Residual Fuel Oil: A general classification for the heavier oils that remain after the distillate fuel oils and lighter hydrocarbons are distilled away in refinery operations. It is used in steam - powered vessels in government service and inshore power plants, and can be issued for the production of electric power, space heating, vessel bunkering, and various industrial purposes. Revenue (Electricity): The total amount of money received by an entity from sales of its products and/or services; gains from the sales or exchanges of assets, interest, and dividends 168 earned on investments; and other increases in the owner's equity, except those arising from capital adjustments. Short Ton: A unit of weight equal to 2,000 pounds. Space Heating: The use of energy to generate heat for warmth in housing units using space - heating equipment. It does not include the use of energy to operate appliances (such as lights, televisions, and refrigerators) that give off heat as a byproduct. Steam: Water in vapor form; used as the working fluid in steam turbines and some heating systems. Transmission System (Electric): An interconnected group of electric transmission lines and associated equipment for moving or transferring electric energy in bulk between points of supply and points at which it is transformed for delivery over the distribution system lines to consumers, or is delivered to other electric systems. Tonne (Ton): A unit of mass equal to 1,000 kilograms or 2,204.6 pounds, also known as a metric ton. Total Disposition: The total amount of sold or transferred energy. Turbine: A machine for generating rotary mechanical power from the energy of a moving force (such as water, hot gas, wind, or steam). Turbines convert the kinetic energy to mechanical energy through the principles of impulse and reaction, or a mixture of the two. U.S. Department of Energy (DOE): Oversees programs, such as Wind Powering America, with the mission to advance national, economic, and energy security; promote innovation; and ensure environmental responsibility. http://www.energy.gov/ Watt (Electric): The electrical unit of power. The rate of energy transfer equivalent to one ampere of electric current flowing under a pressure of one volt at unity power factor. Watt (Thermal): A unit of power in the metric system, expressed in terms of energy per second, equal to the work done at a rate of one joule per second. 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Cr m, m, C, R, — =, X; Xi =' Jr Cr mi =>, 0; c, �; c, c, Y m O O Q 3 +.. N O Z T U' W' fl' �=' ' F-� Q! U' _' Cl N O C O W, Y, Z Z H X; J; Z; �; Qe Z' �� U a Hr cnr Qr �. a• Q• Qr �r Or �r �: r o°ic cc Lo Appendix C Maps of Energy Regions Figurel. Alaska Energy Statistics 2003 Regions Arctic & Northwest b'1._ Yukon Southeast Southwest ^ Southeentral Figure 2. Native Corporation Regions .e- BERING STRAITS L A f f KOHIAG ALEUT Source: First Alaskans Institute 179 SEALASKA Figure 3. Alaska Census Area Map Alaska Borough & Census Area Boundaries - 2008 l � p �� �• �1 rn r�wr+caw .w...Er (� P rss lid �� 4 0 A «� wTaM OPb �iTnov�RO�awwWrt TK M wrp•M Y' Source: 2000 Census, Alaska Department of Labor and Workforce Development Figure 4. Alaska Energy Regions Map Alaska Energy Regions 8 .r j. 3 ��+ *W+.•+e.rn�rr r R+.•�+wa.14 .... a—s" tom. f� J 1w.aM &6-N!V Source: Alaska Energy Authority 180 r AL M Appendix D Data Sources for Electric Energy Statistics The primary data source for the electric power statistics is the U.S. Department of Energy (DOE), Energy Information Administration (EIA). Every utility and industrial (including military) electrical generating facility with a capacity greater than one 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 on their website: (http://www.eia.doe.,gov/). We obtained data for the years 2002 through 2008. The forms of interest to compile this publication are the EIA 860, 861 and 923, formerly EIA 906 and EIA920. These are reporting forms for capacity, generation, sales and revenues. The use of the EIA database is a continuation of the methodology used in the 2003 Alaska Electric Power Statistics update. Before the 2003 update, the report's primary data source was a questionnaire sent to each Alaska utility and industrial facility. There were several reasons to use the federal database for this report rather than a survey. 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 is available on the EIA website, it is redundant to collect the same information through a second questionnaire. It is also considerably less expensive to collect the data from the EIA website than to collect it through a mail -out survey. 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, obtaining generating characteristics from a single source helps to insure consistency between federal and state reports. Nonetheless, using EIA data poses some challenges because not all information reported in this publication is collected via the EIA forms. First, the smallest utilities with installed capacity less than one megawatt, are not required to report to EIA and are not included in the EIA database. Second, not all Alaska generating facilities report as required by law. Data collected in the forms are available in sets of databases that may present portions of the data differently. For instance, some data may be available at the utility level only, while other data may be at the facility and/or generator level. The forms are processed by different departments within EIA and may have differences in the underlying definition of the data making reconciliation of the information in the datasets within forms, and across the different forms sometimes difficult. Finally, the lag time for the availability of the federal data is approximately two years. The biggest challenge was identifying missing utilities and other generating units and incomplete data from reporting units. In an effort to identify all utilities and generating facilities in Alaska, we created a comprehensive list of electric utilities using a combination of the lists of utilities from the 2003 Alaska Electric Power Statistics report, the EIA databases, the Power Cost 181 Equalization program (PCE) database, the master utility list from the Regulatory Commission of Alaska, and the Alaska Department of Environmental Conservation (DEC) AIRTOOLS database.' To fill in missing data we used the database for the annual Power Cost Equalization Reports by the Alaska Energy Authority (AEA). Also, as needed, ISER supplemented these data sources by conducting direct surveys of utilities, industrial and military generators. 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 did not provide information for this report. These small utilities were all contacted by email and phone. The 2008 Power Cost Equalization data provided 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 Alaska Village Electric Cooperative (AVEC) and Alaska Power and Telephone (AP&T). The EIA data for these utilities was in some cases reported only as a total across all communities, and we used this as control totals. AEA, AVEC, AP&T and NSPL provided helpful assistance in supplying installed capacity information for each plant not originally included in the PCE database. In this case we were able to publish information taken directly from the utility reflecting statistics from each of its serviced communities. The PCE database contains information collected through AEA's PCE Utility Monthly Report which PCE participants must file. Utilities also report to the RCA annually for fuel cost adjustments. Reporting to both entities should be consistent, however discrepancies are not unusual. These discrepancies may be due to high turnover in small utilities, poor reporting and limited staff to verify the utilities' self reported data. In addition, there are data (energy loss, use by facility and energy provided without charges) that is not included in the PCE report. Because of this, the values found in table 2.2a may not reflect a summation of all AP&T communities as reported in the PCE report. Rather they reflect what was reported to the EIA directly as prepared by the utility itself. This same methodology was implemented in the sales and revenues tables (2.4a) when deemed appropriate. The intent is to create as comprehensive of a table as possible. The summary information in the historical tables was calculated from the same sources mentioned above. Data from these sources was calculated and re -formatted where appropriate and consolidated into master data files from which all the tables in this report where built. Inevitably the use of multiple data sources introduces some inconsistencies in reporting. Notwithstanding, we believe that the Alaska Electric Power Statistics 2010 update report provides useful information on the state of electric power generation in Alaska. 1 The AIRTOOLS database contains information on all stationary facilities that are required to register for an emissions permit, under Title V of the 1990 federal Clean Air Act. 182 Appendix E Reporting Requirements Energy Information Administration Every utility, industrial and military electrical generating facility with a capacity greater than one megawatt (MW) is required to report their operating characteristics to the US Department of Energy (DOE), Energy Information Administration (EIA) annually, and in some instances, monthly. This information is compiled by the EIA and is available for every generating facility on their website (http://www.eia.doe.gov/). Specific reporting requirements are determined by the Department of Energy but collected, assembled, and evaluated by the EIA according to the Federal Energy Administration Act of 1974. We obtained data for years 2002 through 2008. Three EIA forms were used in this report: • EIA-860 Annual Electric Generator Report. This report contains information on capacity and types of fuel used. It is completed by all existing plants and proposed (5-year plans) plants that: 1) have a total generator nameplate capacity (sum for all generators at a single site) of one MW or greater; and 2) where the plant is connected to the local or regional electric power grid and has the ability to draw power from the grid or deliver power to the grid. • EIA -860M Monthly Update to the Annual Electric Generator Report. This report contains monthly updates to the EIA-860. It is completed by those who also completed EIA-860 and additionally indicated a proposed change in generator production within one month of the report period. The proposed change may be due to: 1) a new generator scheduled to start commercial operation; 2) an existing generator scheduled to retire from service; or 3) an existing generator with a proposed modification scheduled. • EIA-861 Annual Electric Power Industry Report. This report contains information on peak production, net generation, sales, and revenues. It is completed by electric industry distributors including: electric utilities, wholesale power marketers (registered with the Federal Energy Regulatory Commission), energy service providers (registered with the Regulatory Commission of Alaska), and electric power producers. • EIA-923 Power Plant Operations Report. Since the 2003 production of this report, EIA has changed some forms. The data collected in Forms 906 and 920 have been combined and are now reported in form 923. This report contains information on electric power generation, fuel consumption, fossil fuel stocks, and fossil fuel cost and quality. It is completed by all electric power plants that: 1) have a total generator nameplate capacity (sum for generators at a single site) of one MW or greater; and 2) where the 183 plant is connected to the local or regional electric power grid and has the ability to draw power from the grid or deliver power to the grid. Power Cost Equalization Program and Regulatory Commission of Alaska Participants of the Power Cost Equalization (PCE) program report to the Regulatory Commission of Alaska (RCA) for fuel cost adjustments to their rates. The RCA has authority to maintain accounts and records of public utilities that fall under its jurisdiction, under Alaska Statute 42.05.451. This responsibility allows the Regulatory Commission of Alaska to obtain information from regulated utilities. Additionally, all utilities that serve ten or more customers must obtain an operating certificate, which describes the authorized service area and scope of operations of the utility. The RCA will issue a certificate when it finds the utility to be fit, willing, and able to provide the service. The RCA maintains a list of both regulated and unregulated certified utilities. Utilities report annually to the RCA, but file a PCE Utility Monthly Report with AEA. Alaska Department of Environmental Conservation To identify any new or missing electricity generators, we reviewed and requested specific data fields from the Alaska Department of Environmental Conservation (DEC) AIRTOOLS database. The AIRTOOLS database contains information on all stationary facilities that are required to register for an emissions permit, under Title V of the 1990 federal Clean Air Act. This Act is administered by the U.S. Environmental Protection Agency (EPA), which has responsibility for protecting and improving the nation's air quality and stratospheric ozone layer. This responsibility is administered in Alaska via DEC. The AIRTOOLS database provided an additional list of facilities not required to report to either the DOE or the RCA, mostly industry generators. Facilities requiring an air emissions permit meet at least one of the following criteria: 1) a potential to emit greater than 100 tons per year of a regulated air contaminant; 2) a combustion source with a rated capacity greater than 100 MMBtu/hour; or 3) a combustion source with emission control equipment with a rated capacity greater than 50 MMBtu/hour. Facilities initially identified from the AIRTOOLS database were contacted by phone and/or email to determine whether they are currently electricity self -generators. Once, their generating status was established data for this report was requested. 184