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US Army Corps
of Engineers
National
Hydroelectric Power
Resources Study D
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Volume XXIII
September 1 981
ALASKA POWER AUTHORJrt
Regional Assessment:
Alaska and Hawaii
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SECURITY CLASSIFICATION OF TH!S PAGE (When D~tt" EntenHf)
REPORT DOCUMENTATION PAGE READ INSTRUCTIONS
BEFORE COMPLETING FORM
I. REPORT NUMBER 2. GOVT ACCESSION NO. 3. RECIPIENT'S CATALOG NUMBER
Volume XXIII
4. TITLE (and Subtltl•) 5. TYPE OF REPORT & PERIOD COVERED
National Hydroelectric Power Resources Study: Final
Regional Assessment; Alaska and Hawaii
6. PERFORMING ORG. REPORT NUMBER nm. 82-H-23
7. AUTHOR(•) 8. CONTRACT OR GRANT NUMBER(•)
u.s. Army Engineer Division, North Pacific
P. 0. Box 2870 N/A
Portland, OR 97208
9. PERFORMING ORGANIZATION NAME AND ADDRESS 10. PROGRAM ELEMENT. PROJECT, TASK
!\REI'\ & WORK UNIT NUMBERS
Same as No. 7 above.
II. CONTROLLING OFFICE NAME AND ADDRESS 12. REPORT DATE
u.s. Army Engineer Institute for Water Resources September 1981
Kingman Building 13. NUMBER OF PAGES
Fort Belvoir, VA 22060 224
14. MONITORING AGENCY NAME A ADDRESS(If different from ControtllnQ Olflc•) IS. SECURITY CLASS. (of thle report)
UNCLASSIFIED
Same as No. 11 above. 1s ... DECLASSIFICATION/DOWNGRADING
SCHEDULE
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Approved for public release; distribution unlimited.
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18. SUPPL ENENTARY NOTES
19. KEY WORDS (Continue on reveue •Ide It neeea•ary and Identity by block number)
Hydroelectric power potential; electric power supply and demand; hydroelectric
project evaluation; electric power projections
20. ABSTRACT~_,....,, .. 10iYb1 Et ~ -..tl.ldentlfr by bloel< numb•JThl.S volume br1.efly describes
existing conditions (physical, social, economic) affecting electric supply and
demand 1n the states of Alaska and Hawaii. It discusses the existing electric
~nergy sys tern and the role of hydropower therein. Projections of e l'ectrical
supply and demand through the year 2000 are discussed. The hydropower resources,
~eve loped and undeveloped, of the region are evaluated and a regional ranking of
specific projects and s i t e s '" h i ch are reconmended to be studied l.n further detail
~s presented. The public involvement in the planning process lS described.
DO 1473 EDfTlON OF t NOV 65 IS OBSOLETE UNCLASSIFIED
SECURITY CLASSIFICATION' OF TH!S PII.GE (1/J'hen Dat• Enter<>d)
U.S. Army Corps of Engineers
National Hydroelectric Power Study
Regional Report: Volume XXIII
Alaska
September 1981
Prepared by:
U.s. Army Corps of Engineers,
North Pacific Division
P • 0 • BoX 2 8 7 0
Portland, OR 97140
u.s. Army Corps of Engineers,
Alaska District
P.O. Box 7002
Anchorage, AK 99510
Prepared for:
U.S. Army Corps of Engineers,
Institute for Water Resources
Kingman Building
Fort Belvoir, VA 22060
PREFACE
The economic success and standard of living in this country have been
achieved, in part, at the expense of abundant supplies of low cost, non-
renewable, energy sources. In recent years however, diminishing reserves of
the preferred non-renewable energy sources, i.e. oil and natural gas, have
prompted a national energy policy which emphasizes conservation and the
development of new and renewable sources of energy. This report is a direct
result of the national energy policy as it focuses on our major existing
renewable energy resource, hydroelectric power.
Congress, in the Water Resources Development Act of 1976 (P. L. 94-587),
authorized and directed the Secretary of the Army, acting through the Chief of
Engineers, to undertake a National Hydroelectric Power Resources Study
(NHS). The primary objectives of the NHS were (1) to determine the amount
and the feasibility of increasing hydroelectric capacity by development of new
sites, by the addition of generation facilities to existing water resources
projects, and by increasing the efficiency and reliability of existing
hydroelectric power systems; and (2) to recommend to Congress a national
hydroelectric power development program.
The final NHS report consists of 23 volumes. Volumes I and II are the
Executive Summary and National Reports respectively. Volumes III and IV
evaluate the existing and projected electric supply and demand in the United
States. Volumes V through XI discuss various generic policy and technical
issues associated with hydroelectric power development and operation. Volumes
XII and XIII describe the procedures used to develop the data base and include
a complete listing of all sites. Volumes XIV through XXII are regional
reports defined by Electric Reliability Council (ERG) regions. The index map
at the inside back cover defines the ERG regions. Alaska and Hawaii are
presented in Volume XXIII.
This volume, number XXIII, describes the hydroelectric power potential in
the states of Alaska and Hawaii. A map depicting all sites described in the
text is located in the jacket, inside back cover.
CONTENTS
PREFACE
LIST OF TABLES
LIST OF FIGURES
1. REGIONAL OBJECTIVES ••
1.1
1.2
2.
2. 1
2.2
2.3
2.4
2.5
2.6
Regional Objectives ••
Other Studies • • •
EXISTING CONDITIONS •
Alaska Geographic/Hydrologic Subregions •
Topography • • • • •
Hydrologic Conditions • • • • ••••
Economics of Area • • • • • • • • • •
r-1ajor Electric Energy Users •
Future Development
3. EXISTING ENERGY • • . •
3.1
3.2
3.3
4.
4.1
4.2
5.
5.1
5.2
5.3
5.4
5.5
5.6
5.7
6.
6.1
6.2
Transmission Systems • • . • • • • • • •••
Description of Existing Energy Systems Excluding Hydropower
Role of Existing Hydropower • • • • • • •••
DEMAND SID1MARY
Electrical Utility Demand -Present Conditions
Electric Utility Demand -Future Conditions
DESCRIPTION OF METHODOLOGY FOR EVALUATION OF
POTENTIAL HYDROPOWER • • • • • • • •
General
Initial Inventory and First Screening •
Stage 2 Second Screening • • • • •
Stage 3 Third Screening • • •
Stage 3 Fourth Screeing • •
Stage 4 Regional Power Plan •
Public Involvement
INVENTORY
General Discussion of Stages 1, 2, and 3
Stage 4 Inventory • • • • • • • • . • • •
iii
i
v
vi
1-1
1-1
1-2
2-1
2-1
2-4
2-5
2-6
2-7
2-8
3-1
3-1
3-3
3-11
4-1
4-1
4-7
5-1
5-1
5-1
5-4
5-5
5-S
5-6
5-7
6-1
6-1
6-5
CONTENTS(cont)
7. EVALUATION
7.1
7.2
7.3
Regional Plan Development Program •
Transmission Interties •••••
Comparision of Electrical Power Demand with Hydropower
Potential • • • . . • • • . • • • • • •
APPENDIXES
Appendix A -Summary Listing of Potential Projects
Appendix B -Public Review Comments
Appendix C -References
Appendix D -Glossary
iv
7-l
1-l
7-1
7-8
LIST OF TABLES
Table
2-1 Alaska Economic Indicators • • • • • • • • • • • • . • • • • 2-7
2-2 Alaska Electrical Energy Consumption by Consumer Category
for 1978 • • • • • • • • • • • • • • • • • • • • • 2-8
2-3 OBERS Projections of Population, Income and Major Sector
Earnings, (Alaska) • • • . • • . • • . • • • • • • • 2-9
3-1 Existing Transmission Lines -33kV and Above • • • • • • 3-2
3-2 Transmission Lines and Major Interconnections, Alaska, 1979 3-2
3-3 Summary of Alaska Energy Generation (GWh) -1979 • 3-4
3-4 Alaska Utility Systems • • • • • • • • • • • • 3-8
3-5 Electric Utility Systems, Principal Operations and Retail
Customers by Ownership Segment • • • • • • • • • • • • 3-10
3-6 Ownership of Utility Systems by Size of Total Energy
Requirements • • • • • • • • • • • • • • 3-10
3-7 Existing Hydroelectric Plants, Alaska • • • • • 3-12
4-1 Annual Energy, Peak Demand and Load Factor • • • • • • • • • 4-2
4-2 Alaska Annual Growth Rates of Energy Consumption • 4-3
4-3 System Load Variations in Alaska • • • • • • • • • 4-4
4-4 Alaska Estimated Resources, Demand and Reserve Margins • 4-6
4-5 Harza Forecast of Electric Utility Power Demand, Alaska 4-8
4-6 Alaska Generation Mix • • . • • • • • • • • • • • 4-10
4-7 Regional Summary of Alaska Capacity and Net Generation • 4-12
4-8 APA Forecast of Electrical Power Demand, Alaska • • • • 4-13
5-1 General Plan of Study • • • • • • • • • • • • • • • 5-2
6-1 Summary of Hydropower Project Screening Results, Alaska 6-2
6-2 Total Physcial Hydropower Potential, Alaska • • • • 6-3
6-3 Total Economically Feasible Hydropower Potential, Alaska 6-4
6-4 Hydropower Potential at Projects Suitable for Further Study,
Alaska . . . . . . . . . . . . . . . . . . . . . . . .. . . 6-5
6-5 Project Type and Status Identifier • • • • • • • • • • • • • 6-6
7-1 Potential Hydropower Sites Identified for Detailed Study,
Alaska . . . . . . . . . . . . . . . . . . . . . . . . . . 7-2
7-2 Summary of Regional Electrical Capacity and Energy Demand,
Alaska • . • • • • • • • • • • • • • • • 7-8
7-3 Regional Electrical Capacity and Energy Demand Versus
Hydropower Potential • • • • • • • • • • • • 7-9
v
LIST OF FIGURES
Figure
2-1 River Basins of Alaska ...•....•.
3-1 Existing Hydropower Plants, Alaska ...
4-1 Seasonal Hourly Loads, Chugach Electric
5-l Flow Chart of Screening Process
7-1 Site Location Hap •.•.......••
vi
2-2
3-13
4-5
5-3
7-7
Chapter 1
REGIONAL OBJECTIVES
Within the last generation, hydropower investigations in Alaska have iden-
tified many potential projects throughout the State. Except in Southeast
Alaska, however, very little was known about the extent of the State's hydro-
power resources prior to World War II. After the war, serious interest
appeared, motivated by a worldwide search for large low-cost hydropower projects
that could be used for the production of aluminum and a desire to provide a
viable economy in the then Territory of Alaska. More recently, the oil embargo
of 1973 and subsequent price increases served to revive interest in hydropower
development. License applications for study and construction of hydropower
facilities continue to be received by the Federal Energy Regulatory Commission
(FERC) in record numbers. With the vast undeveloped hydropower potential in
Alaska, combined with the ever-increasing cost of thermal energy resources, par-
ticularly the cost of oil and gas, the outlook for construction of hydropower
plants in Alaska is promising. In addition, through the establishment of the
Alaska Power Authority, the State has developed the institutional, technical,
and financial capability to provide the catalyst necessary for hydropower deve-
lopment to proceed.
Considering all of the possiblities, the findings of this study indicate an
undeveloped hydropower potential of 42,700 megawatts of capacity and 224.4
billion kilowatt-hours of energy (25,600 average megawatts). Most·of Alaska's
potential hydropower, however, is not needed within the state and is not econo-
mically feasible to transmit to the potential users outside the State. Within
the State, the electrical economy has become heavily dependent upon fossil fuel
energy. Diminishing reserves of these traditional primary energy sources have
prompted a national energy policy which emphazises both energy conservation and
development of new sources of primary energy. The potential for developing some
new hdyropower projects as well as an opportunity for retrofitting existing
hydropower projects exists. While some limitations on development are obvious
and were evaluated through rather cursory examination, other constraints were
extremely complex and required detailed engineering analyses. These issues were
investigated, in assessing the realistic potential contribution that hydropower
could make in meeting Alaska's growing electric energy demands.
1.1 REGIONAL OBJECTIVES
The overall objectives of the NHS were to identify and assess the potential
for development of the nation's hydropower resources to help meet the short and
long term energy demands of the nation. The evaluations conducted during the
study considered the physical potential, economic costs, environmental and
social impacts, institutional constraints, and marketability.
The following specific objectives were established for Alaska:
1. To decrease the State's dependency on oil and gas for generating
electricity.
1-1
2. To analyze and define the State's need for hydropower.
3. To assess the potential for increasing hydropower capacity and energy at
existing dams and undeveloped sites.
4. To analyze the current marketing constraints to additional hydropower
development.
5. To assess the general environmental and socio-economic impacts of the
development of specific hydropower projects.
6. To recommend maximum feasible utilization of the energy potential
derived from the State's hydropower potential cons is tent with regional demand
for electricity and the State's environmental quality objectives.
1.2 OTHER STUDIES
----~
Since World \var II a number of studies of Alaska's potential hydropower
resources have been completed. Major early studies included government and
private studies on both the Wood Canyon and Yukon -Taiya projects and a
comprehensive inventory of the hydroelectric resources of Southeast Alaska
published by the U.S. Forest Service and the Federal Power Commission in 1947.
The purpose of that report was to bring together the best available data
assembled on hydropower and provide a basic listing of potential energy
generating sources for the industrial growth of the Southeast region.
The Bureau of Reclamation first conducted a statewide field reconnaissance
study of Alaskan hydropower projects in 1948. Attention was focused on the
Susitna River basin potential and other hydropower projects. That recon-
naissance initiated the study which led to the authorization and development of
the Eklutna Project near Anchorage. Other investigations were completed in 1953
on several smaller projects in other parts of the State.
A separate series of regional water resource studies by the Corps of
Engineers investigated alternative hydropower development strategies including
the investigation of the Rampart project on the Yukon River. Reconnaissance
studies on the Rampart project indicated an immense potential of low-cost hydro-
power. Further investigations by the Department of Interior and feasibility
reports by the Corps of Engineers recommended that the Rampart project not be
developed due to environmental effects, the lack of a power market, and an abun-
dant supply of inexpensive natural gas. Interim solutions were needed and
alternative options included a number of smaller projects. One of those
options, Bradely Lake near Homer, although authorized for construction by the
1962 Flood Control Act, remains unconstructed.
As part of the Department of Interior investigation, the Bureau of
Reclamation prepared a comprehensive inventory of the statewide hydropower
resources between 1962 and 1967. This extensive work essentially provided a
complete identification of potential sites in Alaska. That inventory benefited
from a great deal of information that was previously not available in a compre-
hensive inventory. The Alaska Power Administration has updated major portions
of that inventory, screening the summary to 252 of the most favorable potential
l-2
hydropower sites in Alaska. The initial inventory included data on physical
potential, mapping, hydrology, cost estimates, and in a few cases field checks
for engineering suitability. The results were published in the 1969 and 1976
Alaska Power Survey by the Federal Power Commission.
In addition to the NHS, in 1978 the Corps of Engineers initiated studies
to determine the potential for small (less than 5 ~1W) hydropower projects
throughout Alaska. Reports for the Southeast and Aleutian Islands areas have
been completed while the report for the Southwest subregion is scheduled for
completion in the near future. These reports address or will address potential
sites that would produce less than 1 megawatt of power.
1-3
Chapter 2
EXISTING CONDITIONS
2.1 ALASKA GEOGRAPHIC/HYDROLOGIC SUBREGIONS
Alaska is divided into six geographical/hydrological subregions which are
based on the major drainage basins within the State. These subregions, as
determined by the Interagency Technical Committee for Alaska, are shown on
Figure 2-1. These include the Southeast, Southcentral, Yukon, Southwest,
Northwest, and Arctic subregions.
Southeast
Southeast Alaska stretches nearly 600 miles along the border of British
Columbia. The terrain is typified by high mountains and small drainage basins
which lead directly to the ocean. Heavy precipitation with high runoff rates
contributes to the opportunity for numerous hydropower developments throughout
the entire area. Thirteen percent of the State's population is located within
the area. The State capitol, Juneau, is situated midway within the subregion.
The principal industries are government, forest products, fishing, and tourism.
Because of the steep terrain, glaciers, and many islands, there are no intercon-
necting highways or power transmsission systems. Transportation is dependent
upon air travel and the Alaska State Ferry system. Historically, electrical
generation for the larger communities has been furnished by local hydropower
supplemented by diesel generation or all diesel. Most of the smaller towns are
fully dependent upon diesel generation.
Southcentral
The Southcentral subregion of Alaska is characterized by much lighter
runoff, colder climatic conditions, and less steep topography than Southeast
Alaska. These conditions result in hydropower sites located mainly on the large
river systems such as on the Copper and Susitna Rivers. This area of the State
contains approximately 57 percent of the population. Major industries are asso-
ciated with oil development and processing around Cook Inlet, fishing, seafood
processing, government, and trades. Most of the towns in the area are intercon-
nected with good highway and air transporation systems. The major portion of
the electrical generation in the Anchorage-Cook Inlet area is provided from
natural gas. The area is serviced by a power transmission system between Homer
at the south end of the Kenai Peninsula to Talkeetna, north of Anchorage.
Electrical service in the Anchorage-Cook Inlet area is provided by five separate
utilities. Electrical service to other isolated communities is provided by
individual utilities, primarily from diesel generation.
2-1
N
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HYDROLOGIC SUBREGIONS
1901 -ARCTIC
1902-NORTHWEST
1903-YUKON
1904-SOUTHWEST
1905-SOUTHCENTRAL
1906-SOUTHEAST
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Figure 2-1
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RIVER BASINS OF ALASKA
CANADA
Yukon
The Yukon subregion is the largest of the six subregions with an area of
about 204,000 square miles--approximately 35 percent of the area of the State.
The Yukon River system and its tributaries have the only hydropower potential in
the area. Due to the lack of storage sites, essentially no viable sites exist
north of the Alaska Range, including the north slope of the Alaska Range. The
area has only a few other sites which could be physically developed in the
entire Yukon basin. Most of the better sites on the mainstream river systems
have been excluded from possible development by recently enacted Alaska Lands
legislation. Roughly 20 percent of the State's population lives in this area
with Fairbanks being the main population center. The area's primary economic
components are the State and Federal governments, the military, the petroleum
industry, and the University of Alaska. Fairbanks experienced rapid growth
during the construction of the Alaska pipeline and severe economic decline after
pipeline completion. Fairbanks is connected to the Anchorage area by a highway
system and to the south 48 states through Canada by the Alaska Highway. It is
also served by several airlines and the Alaska Railroad which connects Fairbanks
to seaports on Cook Inlet and the Gulf of Alaska. Currently, Fairbanks is
supplied by two electric utilities from coal-fired generation and oil-fired com-
bustion turbine generation. Outlying villages in this area are primarily depen-
dent upon diesel engine generation for their electrical needs.
Southwest
The Southwest subregion is about 109,000 square miles in area. The area
consists of major river drainage areas of the Kuskokwim, Nushagak, and Kvichiak
Rivers, the western flank of the Alaska Peninsula, and the Aleutian Islands.
Few good hydropower sites exist within reasonable transmission distances of the
major population centers of Bethel, Dillingham, and Naknek. Roughly 5 percent
of the State's population lives in this area. The majority of the economy is
based on commercial fishing and processing, with government and recreation being
other important industries. The streams support one of the world's most produc-
tive red salmon fisheries. Recent exploration indicates potential for signifi-
cant oil deposits in the Bristol Bay area, however, immediate development is
being delayed for environmental reasons. Currently, main population centers
plus the numerous scattered villages are dependent upon diesel generation for
meeting electrical energy needs.
Northwest
The Northwest area is similar to the Yukon area with hydropower sites being
limited to the major stream systems. This area constitutes roughly 3 percent of
the population of the State. The major towns are Nome and Kotzebue. Primary
industries in the area include commercial fishing, fur trapping, and government,
with subsistence being the primary method of livelihood in the outlying areas.
Transportation to and within the area is restricted to air travel on a year-
round basis, while during the summers water travel is available. Electrical
power generation is furnished entirely by isolated diesel generation systems.
2-3
Arctic
Hydropower potential in the Arctic subregion is severely restricted due to
the lack of head, water supply, climate, and economical dam and reservoir sites.
The area north of the Brooks Range constitutes roughly 2 percent of the State's
population. The area's largest single industry is the oil development at
Prudhoe Bay. Other major industries include oil and gas exploration, construc-
tion, and government services. Subsistence living constitutes the remainder of
the economic activity for this area. Transportation is restricted to air travel
on a year-round basis and an occasional barge or ship during the late summer.
Electrical generation for the Barrow and Prudhoe Bay oil development areas con-
sists primarily of oil and gas-fired turbines and diesel generators. The
outlying villages depend entirely on diesel generation.
2.2 TOPOGRAPHY
Alaska has a land area of 586,412 square miles, approximately one-fifth the
size of the United States. Surrounded on three sides by waters of the Arctic
and Pacific Oceans and the Bering Sea, Alaska has 46,000 miles of coastline.
The topography of the State is extremely diversified, highlighted by two vast
mountain systems: the Brooks Range to the north and the Pacific Mountain System
to the south.
The Brooks Range, lying about 100 to 200 miles inland from the Arctic Coast,
is the northern extension of the Rocky Mountain System. From the Canadian
border the Brooks Range extends westward for 600 miles to the Arctic Ocean.
Many peaks in the eastern part of this range exceed 9,000 feet in elevation; in
the west, peak elevations decrease to an average of 3,000 feet.
The Pacific Mountain System is the continuation of the Coastal Mountain
System of the conterminous United States and Canada. This system consists of
two parallel arcs that generally follow the coastline from Southeast Alaska to
and including the Aleutian Islands. The northern arc includes the boundary of
the Alaska and Aleutian Ranges, and the Aleutian Islands. The southern arc
includes many of the islands of Southeast Alaska as well as the Fairweather
Range, the St. Elias Mountains, the Kenai-Chugach Mountains, and Kodiak Island.
Elevations in the Pacific Mountain System range from 1,000 to 4,000 feet, in the
Aleutian Range to more than 10,000 feet, and in the Alaska and St. Elias
Mountain Ranges to over 20,000 feet (Mount McKinley).
North of the Brooks Range lies the Arctic Coastal Plain which rises grad-
ually from the Arctic Ocean to a maximum elevation of 600 feet at its southern
margin. This vast tundra plain is virtually without relief except for scattered
groups of low hills east of the Colville River that range in height from 20 to
230 feet.
The intermountain plateau lies between the Brooks Range and the Alaska Range
consisting of dissected uplands and broad, alluvium-filled basins. The basin
floor ranges in altitude from over 6,500 feet in the Yukon-Tanana uplands in the
east to generally less than 1,000 feet in the Yukon-Kuskokwim and Bristol Bay
lowlands to the west.
2-4
The majority of the people in Alaska live in proximity to the sea coast in
the Southcentral and Southeast subregions of the State where they enjoy a
moderate climate due to maritime influences. These same areas include extensive
glaciers and ice fields at elevations of 2,000 to 3,000 feet above sea level,
exhibiting all the characteristics of a very cold alpine climate ecosystem. The
continuous permafrost that exists over roughly the northern third of the State
and the discontinuous permafrost that extends over parts of the Southwest and
Southcentral Subregions present difficult water supply problems.
2.3 HYDROLOGIC CONDITIONS
The highly diverse geographical features of Alaska have a significant impact
on the climate of the State. A zone of maritime influence, which extends
throughout Southeastern and Southcentral Alaska along the gulf coast experiences
a mild, wet climate; annual precipitation reaches as high as 200 inches with
higher amounts in the glaciated mountain areas of the region. Away from this
maritime coastal zone the climate changes rapidly with decreasing amounts of
precipitation and greater extremes in temperature. Average annual precipitation
in the interior is 12 inches, decreasing to 6 inches or less along the Arctic
Slope. However, considerably more precipitation falls in the interior moun-
tainous area. About two-thirds of Alaska receives less than 20 inches of preci-
pitation annually.
Mean annual temperatures range from 43 degrees F along the maritime coastal
zone to 10 degrees F along the Arctic Slope. The interior of Alaska experiences
the greatest extremes in temperature. In this region mean-maximum summer tem-
peratures range between 75 and 80 degrees F, while the mean-minimum winter tem-
peratures are in the range -20 to -30 degrees F with extremes down to -50
degrees F and colder.
Climatological differences in Alaska resulting from its unique geography
cause a wide variation in the hydrology of streams. Low-lying areas adjacent
to the Gulf of Alaska have high unit runoffs and relatively little seasonal
variation. In the mountainous areas adjacent to the Gulf, runoff is high, and
in the northern part of the State runoff rates are relatively low.
All major streams in Alaska originate within the State except for the Yukon
and Porcupine Rivers (Upper Yukon subregion) and the Alsek, Taku, and Stikine
(Southeast subregion) whose headwaters are in Canada. All of the streams in
Alaska flow into either the Arctic Ocean, Bering Sea, or the Pacific Ocean.
The streams in the region fall into two general groups, glacial and nongalacial.
Most glacial streams are found in the Southcentral and Southeast subregions, and
the southcentral portion of the Yukon subregion.
The Yukon River is the largest in the State and ranks fifth in discharge
among streams in the United States. The Yukon drainage that is solely in Alaska
covers about 35 percent of the State. The estimated mean annual discharge is
257,000 cubic feet per second (cfs), 32 percent of which flows into the State
from Canada. Major tributaries of the Yukon River include the Koyukuk, Tanana,
and Porcupine Rivers.
2-5
Other principal river systems in Alaska include the Colville (Arctic),
Kobuk, (Northwest); Kuskokwim (Southwest), and Susitna and Copper Rivers,
(Southcentral). Extensive natural inland lakes in Alaska encompass S.l million
acres of the State.
The combination of geologic, climatic, seasonal, geographic, and other
effects often produces problems and conditions in Alaska for which there are no
comparable situations in other parts of the United States. Nevertheless, Alaska
has by far the greatest potential of any state for the development of hydr!)-
power, particularily in the Southcentral and Southeast regions where topographic
conditions are favorable and streamflows are relatively high and uniform.
Additional potential exists in the water that is stored in the vast snowfields
and glaciers in these regions.
In other dreas of Alaska not only the intensity but the duration of cold
weather produces unusual effects. The prolonged periods of cold weatl1er and
associated permafrost preserve a significant amount of water in a non-
accessible, solid state. Shallow rivers and lakes freeze to the bottom or
develop several feet of ice cover and remain frozen for most of the year. Low
instream flow is the rule for most areas of the State during the winter.
Alaska's climate and varied terrain place significant limitations on the supply
of water which is available for development of hydropower.
2.4 ECONOMICS OF AREA
Table 2-1 summarizes the significant 1970 demographic and economic data for
Alaska. [Economic Area 172, as defined by the Bureau of Economic Analysis
(BEA), u.s. Department of Commerce].
In 1970 Alaska's population was 305,000, and represented about 0.2 percent
of the national total. Over the period 1962 to 1970, the population grew at an
average annual rate of 2.7 percent. The 1975 population was estimated at
405,000, reflecting a high average annual growth of 5.8 percent during the
period 1970 to 1975. Preliminary 1980 census figures indicates a current popu-
lation exceeding 400,000.
Total earnings in Alaska have been growing at an average annual rate of
about 4.8 percent. The 1970 Alaska earnings represented about 0.2 percent of
the national total. By far, the largest earnings sector has been government,
contributing about 44 percent to Alaska's total earnings. Construction and
trade also contributed a significant portion to the Alaska total earnings.
The 1970 Alaska per capita income of $4,202 was about 21 percent higher than
the national average. Between 1962 and 1970, the Alaska per capita income grew
at an average annual rate of 4.0 percent. Figures for 1980 (not yet available)
will show a higher per capita income level, but inflation has trimmed the dif-
ference between the Alaskan and national standards.
2-6
Notes:
Table 2-1
ALASKA ECONOMIC INDICATORS
1970
Earning Sector
Agriculture
Mining
Construction
Manufacturing
Transportation Utilities
Trade
Finance
Services
Government
Total Earnings
Population (Thousands)
Per Capita Income ($)
Per Capita Income Relative to the U.S.
1/ 1967 dollars
2/ Laws governing mining prohibit disclosure of earnings.
2.5 MAJOR ELECTRIC ENERGY USERS
Earnings 1/
(Millions $)
18
2/
122
80
111
135
31
118
522
1,137
305
4,202 1/
1.209
The relative proportion of electrical energy consumed during 1978 by the
major consumer categories (residential, commercial, and industrial) for repre-
sentative utilities in Alaska is given in Table 2-2. Electrical energy consump-
tion in the State is fairly evenly divided between the residential and
commercial categories. The low rate of consumption in the industrial category
reflects the relatively low level of heavy industrial activity in Alaska.
2-7
Table 2-2
ALASKA ELECTRICAL ENERGY CONSUMPTION BY CONSUMER CATEGORY FOR 1978
Residential
GWh 1,164
Percent 44.7
Source: Edison Electrical Institute.
Notes:
1/ Small light and power.
Z/ Large light and power.
Commercial 1/ Industrial 2/ Other 3/
1,295 56 87
49.8 2.2 3.3
3/ Includes street and highway lighting (13 GWh), other public authorities (65
GWh), railroad and railways (2 GWh), and interdepartmental use (7 GWh).
2.6 FUTURE DEVELOPMENT
Population
Table 2-3 summarizes the significant demographic and economic projections
for Alaska, as approximated for BEA economic area 172. The projections are
based on the 1972 Office of Business and Economic Research and Statistics
(OBERS) projections. The OBERS projections forecast an average annual popula-
tion growth rate of about 1.6 percent between 1980 and 1990, then 1.1 percent to
the year 2000.
Commercial and Industrial Development
The largest portion of Alaska's earnings is likely to be generated from the
the government sector, which is expected to supply about 40 percent of the
region's total earnings in 2000. The mining sector, although small in magni-
tude, has the largest portion of national earnings compared to other Alaska
industrial sectors. Total earnings in Alaska are expected to grow about 3.7
percent annually between 1980 and 2000.
Per capita income in Alaska is expected to be much higher than the national
average. In 1980, the Alaska per capita income is likely to be 18 percent above
the national average, and decrease to 14 percent above in the year 2000.
Overall growth in Alaska per capita income is expected to be about 2.6 percent
in constant dollars between 1980 and 2000.
2-8
Table 2-3
OBERS PROJECTION OF POPULATION, INCOME, AND MAJOR SECTOR EARNINGS, (ALASKA)
Income and Earnings In Constant 1967 Dollars
Year
Sector 1980 1985 1990 2000
(Earnings, million $)
Agriculture 21 23 24 29
Mining 46 56 68 90
Construction 180 211 247 332
Manufacturing 115 135 159 215
Transportation Utilities 176 215 262 381
Trade 192 229 273 386
Finance 54 69 87 135
Services 204 263 339 542
Government 724 862 1,026 1,447
Total Earnings
(Million $) 1, 713 2',064 2,487 3,557
Total Personal
Income (Million $) 1,875 2,289 2,795 4,088
Total Population
(Thousands) 333 361 391 438
Per Capita
Income ($) 5,626 6,340 7,145 9,333
Per capita Income
Relative to u.s. 1.18 1.17 1.16 1.14
Note:
Sum of sector earnings may not equal the total because of discrepancies in OBERS
data.
2-9
Chapter 3
EXISTING ENERGY
3.1 TRANSMISSION SYSTEMS
The major electrical transmission systems in Alaska are in the Southcentral
(Anchorage-Cook Inlet), Southeast (Juneau), and Yukon (Fairbanks-Tanana Valley)
subregions. The remainder of the State's transmission systems are isolated, and
serve local towns, villages, and nearby environs.
The largest load concentration is in Southcentral Alaska which includes the
Greater Anchorage Area, Matanuska Valley and the Kenai Peninsula. Power resour-
ces for these load centers are in the Beluga and Kenai natural gas fields. The
Eklutna and Cooper Lake hydropower projects also serve this area. This region
has a number of smaller isolated power systems with low voltage circuits.
The second largest load center is loacted in the Yukon subregion. The main
source of power is furnished by coal burning steam plants in Healy and
Fairbanks. Oil-fired combustion turbines in Fairbanks and North Pole furnish
the remainder. Diesel plants at Fairbanks and Healy supply standby power.
In Southeast Alaska separate power systems serve each community. Most of
the transmission in this area is from hydropower plants to the various load
centers. Hydropower is an important source of supply for Juneau,
Metlakatla, Pelican, Petersburg, Sitka, and Skagway. Diesel electric plants
augment the local electrical system. Transmission grid systems are limited or
nonexistent between these communities. The majority of the State's population
is urban and power systems are isolated, with service generally confJned to the
immediate area. The developed areas with complete electrical service occupy
less than 5 percent of the State's area.
The Alaska Village Electric Cooperative (AVEC) was organized for the purpose
of providing electrical service to the remote native villages under a plan deve-
loped through the efforts of the Rural Electrification Administration (REA), the
Office of Economic Opportunity, the Bureau of Indian Affairs, the u.s.
Department of Labor, and the State of Alaska. AVEC now serves some 14,000
people in 48 remote villages where regular electrical service was not available
or adequate only 5 years ago. Most villages have populations of 100 to 500.
Each village owns the cooperative and provides rights-of-way, powerplant sites,
and operators. Local diesel plants furnish power directly to distribution lines
serving the many small communities and villages.
A total of 1,037 miles of transmission lines at 33 kV and above are pre-
sently installed in Alaska as shown in Table 3-1. Table 3-2 shows a summary of
transmission lines by region.
3-1
Table 3-1
EXISTING TRANSMISSION LINES-33 kV AND ABOVE
Nominal Line Voltage Ownership
Voltage Circuit Hiles Type Circuit Miles
138 kV 303 Cooperative 886
115 kV 348 Municipal 63
69 kV 161 Federal 88
33 kV 225 1,037
1,037
Table 3-2
TRANSMISSION LINES AND MAJOR INTERCONNECTIONS, ALASKA, 1979/1
Anchorage-Cook Inlet Area
(and Kodiak)
Total
Fairbanks Area
Total
Southeast Region
Total
Alaska -Total
Total
Level
(kV y)
138
138
115
69
33
13.8/69
138
69
33
138
183
33
138
138
ll5
69,13.8/69
33
Line
(miles)
128 Overhead
12 Submarine
348 Overhead
86 Overhead
153 Overhead
4 Overhead
731
119 Overhead
71 Overhead
42 Overhead
232
41 Overhead
3 Submarine
30 Overhead
T4
288 Overhead
15 Submarine
348 Overhead
161 Overhead
225
1,037
Sources: Alaska Public Utilities commission and Alaska Power Administration.
Notes:
1/ Lines under 33 kV not included.
2! Nominal voltage.
3-2
3.2 DESCRIPTION OF EXISTING ENERGY SYSTEMS EXCLUDING HYDROPOWER
Type of Energy and Magnitude
As of 1979 the installed electrical generating capacity in Alaska was
1,866.8 megawatts. About 84 percent of the electricity generated in the State
was produced from energy supplied by fossil fuel. Natural gas was by far the
major fuel, accounting for 56 percent of the year's output. Next came oil (18
percent), coal (10 percent), hydro (10 percent), and wood waste (6 percent).
Most recent additions have been in oil and natural gas-fired plants with a
strong trend toward dependency on these fuels. In 1979, more than 4.8 billion
kilowatt-hours of electricity (4,380 GWh thermally) were generated in the State.
The combustion turbine, fired by gas or oil, accounts for the largest portion of
the thermal generation (60 percent) followed by the steam turbine (24 percent)
and internal combustion diesel generator (16 percent). Table 3-3 presents a
summary of the net electrical energy produced in 1979 by types of generation for
the six subregions in the State.
Fossil-fueled, thermal-electric powerplants have, for many years, been the
mainstay of Alaska's elelctrical power industry. Nearly all new installed capa-
city in the Railbelt area has been combustion turbine units. This includes new
oil-fired units installed in Fairbanks and several relatively new natural gas-
fired units added by the Anchorage area utilities. In addition, there are a
number of new combustion turbine units in industrial applications in various
parts of the State.
The increased use of combustion turbines reflects the advantages of low ini-
tial equipment cost, minimum ordering and installation lost time, and tech-
nological advances. The principal advantage in the Anchorage area, until
recently, was the availability of low cost natural gas for fuel. Additional
advantages for Alaska are increased capacity and efficiency of combustion tur-
bines because they operate at low altitudes and with low annual average air
inlet temperatures.
The efficiency of combustion turbine units is considerably lower than for
conventional steam, but options do exist to improve their efficiencies. These
include regenerative cycle units, and waste heat boilers in conjunction with
steam and combustion turbine units to form combined cycle plants. Two combined
cycle units will soon go on line in Alaska. Future combustion turbine units
will have higher firing temperatures which increases their efficiencies and in
turn increases the efficiencies of future regenerative and combined cycle units.
Approximately 49 percent of the total State thermal generating capacity is
located in the Southcentral subregion. A further breakdown shows that 74 per-
cent of this subregion's thermal capacity is produced by combustion turbines.
About 23 percent of the State's total thermal capacity is in the Yukon area of
which 29 percent is steam-electric. Systems in Southeast Alaska are a mix of
diesel, hydropower, and industrial wood waste-fired steam plants. The rest of
the State's power systems (except for Barrow) are completely dependent on diesel
generation. Generating units in utility steam-electric plants range in size
from 500 to 25,000 kilowatts. Steam-electric generating units in national
defense plants vary in size from 500 to 7,500 kilowatts.
3-3
Table 3-3
SUMMARY OF ALASKA ENERGY GENERATION (GWh)-1979
Jype o_!_Ene.!JlL ____ Southeast
Gas o. 0
Oil 86.5
Coal o.o
Hydro 263.9
Pulp 306.0
Total subregion 656.4
Combustion Turbine 0.0
Internal Combustion 86.5
Steam Turbine 306.0
Total Thermal 392.5
·-------
Southcentra I
2,260.1
235.8
o.o
192.2
2,688.1
2, 015. 1
240.6
240.2
2,495.9
o.o
202.5
506.5
o.o
0
709.0
152.7
49. I
507.2
709.0
------------------~--~
----~-----,---~
Arctic/ South-
hwest West Ml
442.7 0.0 o.o 2, 702.8
81.6 163.7 94.5 864.6
o.o o.o o.o 506.5
o.o 0.0 0.0 456. 1
0.0 0.0 0.0 306.0 ---524.3 163.7 94.5 4,836.0
454.4 0.0 o.o 2,622.2
69.9 163.7 94.5 704.3
o.o o.o _!_, 053.4
524.3 163.7 94.5 4,379.9
--------·----·-----~---·~--
Source: Alaska Power Administration.
3-4
Combustion turbine units were first installed by Alaska utilities in 1962
for baseload operation as well as for peaking. Combustion turbine plants are
presently operating to serve most of the load in the Anchorage area but are pri-
marily used for intermediate and peaking purposes in the Fairbanks area. Unit
sizes vary from 750 to 72,900 kilowatts. The largest single generating station
in Alaska is the Beluga plant located on the west side of the Cook Inlet. The
plant, which consists entirely of combustion turbines, has a total capacity of
298,100 kilowatts. Internal combustion engine (diesel) generating plants are
scattered throughout the State and are used exclusively in the isolated areas of
the Southwest, Northwest, and Arctic subregions. Plants vary widely in size and
number of units. Individual units of 6,450 kilowatts are in operation, but the
average size is in the range of several hundred kilowatts.
Future Potential
The Southcentral Region, particulary the Anchorage-Cook Inlet area, has the
widest variety of thermal alternatives with natural gas, coal, and oil available
in close proximity. Natural gas in the Anchorage-Cook Inlet area has been the
least expensive fossil fuel in the State, and relatively low-cost power supplies
are assured as long as low-cost natural gas is available for power production.
However, there is genuine doubt that adequate natural gas reserves exist to
supply sufficient energy to meet total power requirements through 2000. Several
experts are of the opinion that natural gas will be either unavailable or too
costly for power production beyond 1985. This is due partly to skepticism con-
cerning estimates of natural gas reserves and partly because of national econo-
mic factors. There may be better uses of natural gas (e.g., petrochemical uses
and home space heating) than generation of electrical power, especially when
extensive coal deposits are available.
Large steam-electric plants have lower per-kilowatt costs than smaller ones;
but existing and immediate future forecasted electrical power requirements in
Alaska load areas indicate there is no need for large units. In comparison with
plants of comparible size now in service, higher capital costs and longer lead
times required for coal, oil, and gas-fired steam-electric plants indicate that
oil or natural gas-fired combustion turbines and combined cycle plants will be
built to meet future power requirements until at least 1984. Utilities are
seriously considering sizeable combustion turbine and/or combined cycle
installations to be added within the next 5 years. Combustion turbine unit
sizes will range from 60 to 70 megawatts and a combined cycle plant would range
from 100 to 200 megawatts. Industry will most likely continue to add smaller
size (20-35 MW) combustion turbine and/or diesel units. Based on the estimated
mid-range power requirements, it appears that a baseload coal-fired steamplant
in the 300-500 megawatts size range could be utilized in the Anchorage area by
1985.
For the Yukon subregion, the range of thermal alternatives is essentially
the same as for the Southcentral subregion except for the present use of natural
gas as fuel in the latter subregion. Coal-fired plants are now being planned to
meet Fairbanks area utility loads of 1983 and beyond. Vast coal deposits in the
Nenana field could provide adequate fuel to meet all of the subregion's future
power requirements. However, until 1985 the subregion's utilities will probably
continue to add combustion turbine units and possibly, if warranted, combined
cycle units.
3-5
Alterntives for the Fairbanks area electrical system include the possibility
of using oil or natural gas from the Alaska pipeline or from the proposed
natural gas pipeline. Some refining would be needed, however, to produce
suitable fuel for any type powerplant. For smaller power systems in the
Southcentral and Yukon subregions, no economical alternatives to diesel genera-
tion have been identified to date.
Outside the Southcentral and Yukon subregions there are fewer options. Oil-
fired diesel electric powerplants are expected to continue as the main source of
electricity and in some areas are the only available source for most power
systems. Controlling factors which preclude other thermal alternatives include:
(a) No access to alternate fossil fuels.
(b) Small-size power market.
(c) The large investment required for conventional steam-electric plants.
It should be noted that small coal-fired plants have received consideration
recently, but are not likely to be economically feasible because of the ex-
tremely high investment costs for small capacity units.
There are no active nuclear powerplants in Alaska, and nuclear power is not
currently a factor in Alaska power planning, primarily due to the relatively
small power requirements and the availability of other attractive alternatives.
Large nuclear powerplants would not likely fit the State power system needs
until beyond 2000, unless loads develop substantially higher than present fore-
casts.
There is considerable interest in Alaska's geothermal potential, and good
reasons exist to explore and define this resource and to proceed with
development. Two areas in Alaska are classified as "known geothermal resources
areas:" the Pilgrim Springs of the Seward Peninsula, and an area on the Aleutian
Chain. These and other areas which are thought to have relatively high poten-
tial are, however, remote from major load centers. The Seward Peninsula
geothermal potential is the most promising of the two areas and may eventually
prove usable if potential mining loads materialize, or if other electrical power
requirements build to a size warranting a regional power system.
Of the possible other electrical energy sources thought to be available in
the future, wind power may have some applications in Alaska. The opportunity to
displace high cost fuels increases the attractiveness of such an alternative.
The present state-of-the-art of wind power embraces mainly applications for
small remote installations, but there are conceptual plans for sets of very
large wind generators to be used for major energy supplies. The most likely
near term future application of wind power for Alaska appears to be as a supple-
ment to diesel power for remote villages or industrial sites where suitable wind
conditions exist, and alternative generation options are limited. Responsible
officials do expect interest to increase in wind generation and also expect
several wind demonstration projects within the next few years.
There is, at present, little basis for assuming solar power will be a signi-
ficant alternative for Alaska power systems in the future. Incoming radiation
3-6
levels in the northerly latitudes are comparatively low, especially in winter
when energy demands are the highest. Solar power is generally thought to be
impractical for Alaskan electrical generation but may be a consideration in new
residential construction where energy conservation measures are being empha-
sized.
Other potential sources of power in Alaska include wood and tidal power.
Although Alaska is endowed with an abundant source of wood, presently the high
cost of collecting and handling the large volumes required makes wood uneconomi-
cal as a fuel for generating electricity in comparision to conventional fossil
fuels. The Cook Inlet tidal range is one of the world's largest and could be a
significant source of power. Because of the availability of more cost-
competitive energy sources, the large size of the project, and technical
problems requiring solution, tidal power remains a distant alternative energy
source.
Impacts
In the contiguous 48 states the adverse effects of thermal and air pollu-
tants from electric power plants have been well documented. One significant
problem in Alaska is the occurrence of ice fog in the Fairbanks area during the
winter caused by increased atmospheric moisture rising from the local steam
generating plant and other sources. Due to the low level of development in
Alaska, other short-term environmental problems resulting from electrical
generating plants are minor or unidentified. To date, monitoring of air and
water quality has been limited. If the future baseload electrical generation is
met largely by thermal generation means, the State will be faced with very
significant environmental problems characteristic of those in the contiguous 48
states. The State of Alaska, recognizing this, has included measures to protect
the environment as a primary objective in plans involving power plant
developments.
Ownership
The electrical power industry in Alaska is composed of a plurality of uti-
lity systems: some owned by private companies, some owned by governmental agen-
cies (Federal or municipal), and some owned by electrical cooperatives
(sponsored by REA). In addition to the utility power systems, there are
numerous self-supplied (non-utilities) industrial and national defense power
systems in the State. Table 3-4 lists Alaskan utilities, indicates type of
ownership. and gives the utility designation.
Table 3-5 compares type of ownership of utility systems based on systems of
record in 1979. As shown in this table, the largest number of utilities are in
the private group. However, in 1979, 67 percent of the more than 140,000 retail
customers in Alaska were served by Alaska's 14 cooperatively owned systems while
only 8 percent were served by private utilities. By way of contrast, the pri-
vate sector in the contiguous 48 states serves more than 75 percent of the
retail customers. During the 1965-1975 period, however, the total number of
electrical utility systems in the contiguous 48 states decreased, the total
number of Alaska's utilities increased during this same period.
3-7
Designation
AHFI
ALEL
ANCO
APAD-E
A PAD-S
APCO
APTC
AVEC
ARVI
BAUI
BUCI
BLPI
CIEL
CHEA
COMA
couu
COEC
CRTP
CVEA
FACO
FYUI
GHEA
GOVE
HOEA
HUGti
HLPC
KECO
KOEA
KTEA
KLEV
LBES
MEAl
MUCI
MPU1
MDEP
Table 3-4
ALASKA UTILITY SYSTEMS
----------------------------·--·------
Utility
Amfac Foods, Inc.
Alaska Electric Light and Power Company
Anchorage Municipal Light and Power Dept.
Alaska Power Administration-Eklutna (Anchocage)
Alaska Power Administration-Snettisham (Juneau)
Aniak Power Company
Alaska Power & Telephone Company (4 towns)
Alaska Village Electric Cooperative, Inc.
(48 villages)
Arctic Utilities, Inc.
Barrow Utilities and Electric Cooperative Inc.
Bethel Utilities Corporation, Inc.
Bettles Light & Power, Inc.
Circle Electric
Chugach Electric Association, Inc.
City of Manakotak
City of Unalaska
Cordova Electric Cooperative, Inc.
Chistochina Trading Post
Copper Valley Electric Association, Inc.
Fairbanks Municipal Utilities System
Fort Yukon Utilities
Glacier Highway Electric Association, Inc.
Golden Valley Electric Association, Inc.
Homer Electric Association, Inc.
Hughes
Haines Light and Power Co., Inc.
Ketchikan Public Utilities
Kodiak Electric Association, Inc.
Kotzebue Electric Association, Inc.
Klukwan Electric Utility
Larsen Bay Electric System
~~tanuska Electric Association, Inc.
Manley Utility Co., Inc.
Metlakatla Power and Light
M & D Enterprise
3-8
Type of
Ownership
Private
Private
Municipal
Federal
Federal
Private
Private
Private
Cooperative
Private
Cooperative
Private
Private
Private
Cooperative
t·lunicipal
Municipal
Cooperative
Private
Cooperative
Municipal
Private
Cooperative
Cooperative
Cooperative
Private
Municipal
Municipal
Cooperative
Cooperative
Municipal
Private
Cooperative
Private
Hunicipal
Private
Designation
NEAl
NECI
NLPU
NPEC
NPLI
NKPI
NSRP
PALl
PMLP
PUCO
SESM
SESU
SIPU
TLPC
TPCO
THRE
WRLD
WTCO
YAPI
Table 3-4(cont)
Utility
Naknek Electric Association, Inc.
Nushagak Electric Cooperative Inc.
Nome Light and Power Utilities
Northern Power & Engineering Corporation, Inc.
Northway Power & Light, Inc.
Nikolski Power & Light Co.
North Slope Borough Power and Light System
Paxson Lodge, Inc.
Petersburg Municipal Light and Power
Pelican Utility Company
Seward Electric System
Semloh Supply (Lake Minchumina)
Sitka Electric Department
Teller Power Company
Tanana Power Company
Tlinget-Haida Regional Electric Authority
Cooperative
Wrangell Municipal Light & Power
Weisner Trading Co.
Yakutat Power, Inc.
3-9
Type of
Ownership
Cooperative
Cooperative
Municipal
Private
Private
Private
Municipal
Private
t·1uni ci pa 1
Private
Municipal
Private
Municipal
Private
Private
Municipal
Huncipal
Private
Private
Table 3-5
ELECTRIC UTILITY SYSTEMS, PRINCIPAL OPERATIONS AND RETAIL CUSTOMERS
BY OWNERSH IP SEGMENT
Systems of Record-1979
--~----~---
Systems with Generation G3nerat i ng Number Ret a I I Customers
Transmission Transmission Capacity Engaged In
Total and and (Percent of Distribution
Ownership Systems Di str I but ion Who lesa I i ng Total) ~ (Number) (Percent)
Private 25 25 0 4. 9 0 11' 500 8. I
Municipal 13 13 1 28.8 0 35,300 25.0
CooperatIve 1/ 14 14 2 60.0 0 94,700 66.9
Feder a I I 0 6.3 0 o.o
Total 53 52 4 100.0 0 141,500 100.0
Note: 1/ AVEC Is II sted as one system.
Table 3-6 shows the relative sizes of electrical utility systems, by type of ownership,
for 1979. In 1979 seven utilities--two of which are municipals, four cooperatives, and one
Federa 1--had energy requirements In exess of 100 mill ion kll0111att-hours and one of these
exceeded 600 million kilowatt-hours. The requirements of four others ranged between 25 and
99 mIll ion kl I owatt-hours In 1979.
Table 3-6
OWNERSHIP OF UTILITY SYSTEMS BY SIZE OF TOTAL ENERGY REQUIREMENTS
Systems of Record-1979
Number of Systems -Annua I Energy Req u l rements
Over 100 25-99 1-24 Under
Ownership GWh GWh GWh GWh Total
Private 0 14 10 25
Munici pa I 2 2 6 3 13
Cooperative ...!! 4 I 8 1 14
Federal 1 0 0 0
Total 7 4 28 14 53
Note: ...!! AVEC Is listed as one system.
3-10
3.3 ROLE OF EXISTING HYDROPOWER
Most of the early hydropower developments in Alaska were constructed to pro-
vide power for mining and other industrial uses, such as fish processing and
were often associated with hydromechanical installations. Over the years, many
small hydropower installations were constructed in Southeastern Alaska to serve
local and seasonal needs. Some of these still remain in service today, although
most small installations have been replaced by diesel generators.
The largest existing hydropower installation in the State is the Snettisham
project at Long Lake, 28 miles southeast of Juneau. This project, constructed
by the Corps of Engineers and operated by the Alaska Power Administration, began
operation in 1973 with an initial installation of 47,160 kilowatts. Ultimate
capacity planned for the Snettisham project is 74,160 kilowatts. The Alaska
Power Administration also operates the 30,000-kW Eklutna plant, 32 miles north
of Anchorage. The third largest hydropower installation in the State is the
15,000 kW Cooper Lake plant owned by Chugach Electric Association, Inc. and
located on the Kenai Peninsula, about 60 miles southeast of Anchorage.
There are more than 40 hydropower installations in Alaska, ranging in size
from 1.5 to 47,160 kilowatts. Most of the plants are small and only of local
significance. Only 14 plants are large enough and in locations to have an
impact on the future power supply of the State. These plants are listed in
Table 3-7 and their locations are shown on Figure 3-1. Twelve of these plants
are located in Southeastern Alaska and serve the cities of Juneau, Ketchikan,
Petersburg, Sitka, and Skagway and the communities of Metlakatla and Pelican.
The other two plants are in Southcentral Alaska and are part of the intercon-
nected system serving the Anchorage-Cook Inlet area. There are no hydropower
plants located in the Arctic, Northwest, Yukon or Southwest subregions.
All major hydropower developments in recent years have been made by public
entities. Of the five plants built in the last three decades, the two largest,
with a total capacity of 77,160 kilowatts or nearly two-thirds of the Alaskan
hydropower capacity, are Federally owned and operated.
In Southeast Alaska, power is primarily generated by diesel generators or a
mix of diesel generators supplementing hydroelectric power when available such
as in Juneau and Ketchikan. Only the Juneau area has hydropower capacity in
excess of present demands. All of the hydropower generated in Southeast Alaska
is used locally. There are no interties between communities; however, interties
are being considered.
In Southcentral Alaska, the primary service areas are supplied baseload
power generated principally by natural gas-fired combustion turbines.
Intermediate and peaking power are provided by the principal hydropower
projects, Cooper Lake and Eklutna.
3-11
Table 3-7
EXISTING HYDROELECTRIC PLANTS, ALASKA
January 1979
Year ot
Initial
System
Plant Name
(FPC Project No.) Location Capacity Ownership Operation
Southeast Region
Alaska Elec. Light & Power Co.
AI aska Elec. Light & Power Co.
Alaska flee. L lght & Power Co.
Alaska Elec. Light & Power Co.
Alaska Power & Telephone Co.
Pel lean uti I ity Co.
Ketchikan Public Utilities
Ketchikan Public utilities
Ketchikan Public uti I ities
Met I a kat I a Power & light
Petersburg Mun. Light & Power
Sitka Pub! ic Uti I it ies
Alaska Power Administration
Southcentra I Reg ion
Chugach Elec. Assn., Inc.
Alaska Power Administration
Cold Creek
Annex Creek ( 2307)
Upper Sa I mon Cr. (2307)
Lcwer Sa I mon Cr. {2307)
[);)wey Lakes ( 1051)
Pe I i can Creek
Ketchikan Lakes ( 420)
Beaver Falls
Si I vis ( 1972)
Purple lake
Crystal Lake ( 201)
Blue Lake {2230)
Snett Isham
Cooper Lake ( 2170)
(Kena l)
Ekl utna
3-12
Juneau 1' 600 Private 1914
Juneau 3,500 Private 1916
Juneau 2,800 Private 1913
Juneau 2,800 Private 1914
Skagway 480 Private 1902
Pel lean 500 Private 1943
KetchIkan 4,200 Pub! ic 1923
Ketchikan 5,000 Pub I lc 1947
Ketchikan 2,100 Public 1968
Met lakat Ia 3,000 Public 1956
Petersburg 2,000 Public 1955
Sitka 6,000 Pub I ic 1961
Speel Rl ver 47,160 Federal 1973
(Juneau)
Cooper 15,000 Pub! ic
Land l ng !Ibn Federal 1961
Eklutna 30,000 Federal 1955
(Anchorage)
Total 126,140
w
I ,.....
w
\ •~tc,.,~ ..--../~ ~t\ J~ ~ "erA.,_ ~[\
'"A 11~ ~ ( ~ ~\ j \ ••~r'c ~~ ~
~j~v:;·~ 'qr •J::(~c . ..:... ;. \~ ~ 'V', ~, ~ -<_~A\..1
_:----' t:ORTHW<sr
~ ~ ( YuKON ~ J .!< C P I 1'. &
-.. -'"''"••r•ok4c Bou•o•••
----........... sueR"f&.·o,.,_.L Aou,..,O.\~ty
~
! l •
'V\ ~~:~ I
<.....__-If 0;l 2J.• • ~~J: ~ ' "~""'" =· .. _ S 0 U T H W t S T ~ ~·:,ooo •u J!;t l-J~., j J\~';f; i~«s );
• ••. r!'-.. 1~ ,..,_.., ..... ''" "'"'•
W' ~ \'" "•-. '2\, -(' "" t::. c.-., ,, ! 0, .. ,,.,_, · \J '-"? , . • • " , • • , " ._ ??vr.,..,_ .\'"·'0<1 '"' ~ """-"' ~" 't. I .' -" ~" ' ·: <" •) ·--~' r . ~ ""· •, "" ''" .,,
' ' .,. "" " efo ~ (',0-'j,::$. • ......... ""~"~'t!{{~(~ "" ..,,.. ··~ .• ~ \' .w '-·
~
( ( ., ... • ry,._ ~
"' .~ \./ , <;;\ '" '·""' ...... ~. '*'" ' • ~ "".<;r . .:P ·y,~, " • •1, J<. ~<1;,1 IV
""-w, I ··-... ,.
~ ' , P < C I 1"1 C 0 C ~ 4 N T~ "''?i>f'"<\1'"'
c::;(dl~. C}~l d ·~6'. ,.;1.
" p ~ •
-.. . •. ' ' h-...1 h.. •'-' ·~ .. '-L-~·'·
Figure 3-1
EXISTING HYDROPOWeR PLANTS, ALASI(A
Several hydropower projects are currently under consideration in Alaska.
The proposed Upper Susitna Dam Project, as currently envisioned, would have a
total generating capacity of 1,558 megawatts and would exceed the combined
existing State hydropower capacity by more than 13 times. Other hydropower pro-
jects under detailed study or construction with a capacity of 1 Mlv or greater
include:
Community Served
Ketchikan
Petersburg/Wrangell
Wrangell
Sitka
Juneau
Klawock/Craig
Haines/ Skagway
Southcentral
Cordova
Homer
Kodiak
Valdez
Southwest
Bethel
Dillingham
Bristol Bay
Hydropower
Site
Upper Mahoney
Swan Lake
Chester Lake
Tyee
Thomas Bay
Green Lake
Upper Salmon Creek
(Rehabilitation)
Black Bear Lake
Hest Creek
Power Creek
Bradley Lake
Terror Lake
Allison Creek
Solomon Gulch
Kisaralik River
Lake Elva
Tazimina
Installed Capacity
(MW)
10
15
2.5
30
50
16.5
15
5
5
7
90
20
8
12
30
l
18
There are no proposals to develop hydropower in the Arctic, Yukon and Northwest
subregions of Alaska.
3-14
Chapter 4
DEMAND SUMMARY
4.1 ELECTRIC UTILITY DEMAND -PRESENT CONDITIONS
Delineation of Regional Power Systems
In this study, Alaska is considered an independent region since it is not
directly tied into the interconnected electric system of any other state. For
purposes of discussion the State is divided into the six major subregions
shown on Figure 2-1.
Peak Demand and Energy Use
The noncoincidental peak load and energy use for the major Alaska utili-
ties in 1979 was about 581 megawatts and 2,700.2 million kilowatt-hours (308.2
average megawatts) respectively (Table 4-1). These utilities represent about
75 percent of the total statewide demand. The peak demand increased at an
average annual growth rate of 11.4 percent over the 1965-1979 period, from
127.6 megawatts in 1965 to 580.8 megawatts in 1979. Within this period the
growth rate in peak demand from 1970 to 1975 was 14.1 percent, increasing from
234.4 megawatts to 453.2 megawatts. Energy use increased at an average annual
growth rate of 11.6 percent over the 1965-1979 period) from 578.5 Million
kilowatt-hours (66.0 average megawatts) in 1965 to 2,700.2 million kilowatt-
hours (308.2 average megawatts) in 1979. The use in 1970 was 1,043.9 million
kilowatt-hours (119.2 average megawatts) and 1,978.3 million kilowatt-hours
(225.8 average megawatts) reflecting an average annual growth
rate of 13.6 percent for the period 1970-1975. Table 4-2 shows annual growth
rates in energy consumption for residential, commercial, and industrial custo-
mers for the period 1965-1978.
Load Characteristics
Alaska is a winter peaking region. Mean annual temperatures range from
43 degrees F in the southern areas to 10 degrees F in the northernmost Arctic
areas. Table 4-3 shows the peak demand as a percentage of the annual peak as
well as the weekly load factors for the first week in April, August, and
December 1977 of five utilities representing the principal bulk power
suppliers in Alaska. These utilities are the following: the Fairbanks
Municipal Utility Systems in the Yukon subregion, the Chugach Electric
Association and Kodiak Electric Association in the Southcentral subregion, the
Sitka Electric Department in the Southeast area, and the Golden Valley
Electric Association (Yukon). Hourly load and load duration curves for the
first week in April, August, and December for Chugach Electric Association,
Inc. are shown in Figure 4-1.
4-1
Table 4-1
ANNUAL DEMAND, PEAK DEMAND AND LOAD FACTOR, ALASKA/1
..........____~---~-------·~ ---
2/
Annual Energl Dec. Peak Demand
Calendar Average Annual Peak Average Annua I Load Factor
Year GWh Growth Rate-% MW Growth Rate-% Factor %
1 1
1965 578.5 127,6 51.8
1966 647.6 11.9 140.5 10. 1 52.6
1967 71 I. 9 9. 9 149.3 6.3 54.4
1968 798.3 12. 1 182.9 22.5 49.7)!
1969 895.5 12.2 185.6 1. 5 55. l
1970 1,043.9 16.6 12. 5 234.4 26,3 12.9 50.8
1971 1,239. 9 18.8 13.9 263.0 12.2 13.4 53.8
1972 1, 404.3 13.3 14.6 288.4 9. 7 14. 1 55.4)!
1973 1,548.3 10.3 14.2 294.7 2.2 10.0 60.0
1974 1,670.3 7. 9 13.3 345.2 17. 1 13.2 55.2
1975 1,978.3 18.4 13.6 453.2 31.3 14. 1 49.8
1976 2,249.3 13.7 12.7 442.0 2. 5 10.9 57.9)!
1977 2,451.0 9.0 11.8 532.6 20.5 13. 1 44. 2
1978 2,613.5 6.6 11.0 564.2 5. 9 13.9 52. 9
1979 2,700.2 3.3 10. I 580.8 2. 9 11.0 53. 1
---------------------
Source: Alaska Electric Power Statistics, 1960-1976 and AI aska Power Administration
f i I es.
f'.btes:
J! Utilities considered are from the Southeast, Southcentral, and Yukon Subregions,
wh l ch represent approxImate I y 3/4 of the tot a I statewl de demand.
y Annual energy sales,
3/ Load factor based on 8, 784 hours.
4-2
Table 4-2
ALASKA ANNUAL GRQVTH RATES OF ENERGY CONSUMPTION
Percent
2/ 1/ 3/
Year Residential Commercial Industrial-Total-
1965 9.5 9.4 11.5 9.6
1966 9.4 11.9 23.5 12.7
1967 14.9 12.5 o.o 13.3
1968 5.2 5.5 3.6 7.0
1969 13.9 16.4 6.9 13.7
1970 11.5 9.5 7.5 10.3
1971 16.8 12.6 9.0 15.0
1972 3.5 4.5 11.9 5.5
1973 32.2 28.6 17.2 28.2
1974 3.0 3.0 7 .o 4.5
1975 9.0 14.0 27.5 7.4
1976 17.8 39.9 68.7 17.0
1977 13.3 18.5 8.2 14.8
1978 4.6 6.4 o.o 5.3
Source: United States Department of the Interior. Alaska Power Administration
"Alaska Electric Power Statistics 1960-1976" 4th ed. (July 1977) and EEl
Statistics.
Notes:
1/ Reported in source as "Commercial and Industrial -Large Light and Power"
Z/ Reported in source as "Commercial and Industrial -Small Light and Power"
3! Includes other sectors, in addition to residential, commercial, and
industrial.
4-3
.j>.
l.
lit i !lty
Fairbanks Municipal Utilities System
Chugach Electric Association, Inc.
Table 4-3
SYSTEMS LOAD VARIATIONS IN ALASKA/1
1977
First Week
of Apr II
Peak Weeki y
Demand Load
% of Factor
First Week
of August
Peak Week I y
First Week
of December
Peak Weeki y
Demand Load cemand Load Peak
% of Factor % of Factor Demand
Annua
Annua % Annual __ % _____ An~.!__ ___ % _____ ~-Dat€1
75.4 76.4 68. I 79. 1 94.2 83.7 27.6 cec 12
64.4 78.9 47.0 83.6 97.6 88. 1 27.4 cec 5
Golden Valley Electric Association, Inc. 54.4 81.4 38.8 77.9 91.4 87.1 89.9 cec 13
Kodiak Electric Association, Inc. NA NA 80.2 NA 90.1 NA 10. 1 l'bv 5
Sitka Electric Department NA NA NA NA NA NA 8. 1 2/ l'bv 29
Net Load
Energy Factor
GWh
128.46 53. 1
1,236.54 51.5
353.14 45.0
53.6 60.6
44.0 NA
---·-------~----------------------------------
Notes:
!/ Computations based on data from schedules 14 and 15 of 1977 FERC-Form 12.
2/ Does not inc I ude cecember 1977.
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The estimated generating capability, peak demand, and reserve margin for
the entire Alaska Region as well as the major areas in the State are given in
Table 4-4.
D Balance
The winter peak demand (noncoincident peak) for Alaska utilities was 662
megawatts in 1978 with 463 megawatts or 70.0 percent being contributed by the
Southcentral area. The Southeast area accounted for ll. 5 percent ( 76 HH), the
Yukon accounted for 15.3 percent (101 HW); and the Southwest, Northwest, and
Arctic areas combined accounted for only 3.3 percent (22 mJ).
ts
As previously mentioned, there are no transmission lines between any of
the major geographic areas in Alaska. Thus, there is no importing or exporting
of power between the different areas. Alaska is also isolated from the Canadian
Power System, and except for Hyder (Southeastern Alaska), power is not trans-
ferred into or out of the Alaska Region.
Reserve Reliabili
Presently, electrical resources in Alaska exceed demand requirements by
475 megawatts or 41.9 percent. However, since there are no interconnections
between the major geographical areas in the State, it is more meaningful to
consider the reserve margins on an area-by-area basis. Reserve margins for
the major geographical areas ranged from a low of 28.0 percent in the
Southcentral subregion to a high of 65.6 percent in the Yukon as shown in
Table 4-4.
Table 4-4
ALASKA ESTIMATED RESOURCES, DEMAND AND RESERVE MARGINS/1
1978
Alaska
Southeast
Southcentral
Yukon
Southwest, Northwest Artie
Combi
Note:
Generating
Capacity
(HW ------__; -----
1, 137
150
643
294
50
Peak Reserve
Demand
(MW)
---~----
662 475
76 74
463 180
101 193
22 28
1/ Utilities only. Military and industrial sources are not considered.
4-6
41.9
49.3
28.0
65.6
56.()
4.2 ELECTRICAL ENERGY DEMAND -FUTURE CONDITIONS
In considering the future demand for electricity, two separate forecasts
were evaluated: one developed by Harza Engineering Company for the Institute
for Water Resources, u.s. Army Corps of Engineers (Harza forecast); and, one
developed by the Alaska Power Administration (APA forecast). Although the
Harza forecast was prepared specifically for the NHS, it used standardized
procedures developed for use nationwide and does not reflect conditions unique
to Alaska. Further, it does not include electricity generated by private
industry and utilities or military installations. For these reasons, there
are significant differences in the results of the two forecasts as highlighted
in the following comparison:
Energy Demand (year)
Current (1978)
Future (2000)
Harza Forecast
(million kWh)
2,300
7,500
APA Forecast
(million kWh)
2,966
15,000
Since the APA forecast incorporates private and military generation as well
as generation by the public utilities and includes detailed consideration of the
State's potential for economic development, their data presents a more realistic
picture of the future demand for electricity in Alaska. Therefore, the APA
forecast is used in this report as the basis for determining the amount of
hydropower development which could be utilized to meet the future demand for
electricity (chapter 7). The results of both forecasts, however, are
discussed for comparison.
Harza Forecast
The Harza forecast was developed from three separate electricity demand
projections (Projections I, II, and III) which were derived from readily
available information. The most probable (Median Projection) forecast was
taken from the three projections simply by selecting the median of the three
projections for each point in time condsidered (1978, 1985, 1990, 1995, and
2000). Projection I represents a compilation and extrapolation of projections
made by the major utilities in response to an FERC reporting requirement.
Projection II was developed by the Institute for Energy Analysis at the Oak
Ridge Associated Universities in September 1976. And, Projection III is a
"consensus forecast" which was derived by averaging 15 forecasts made by private
and Federal economists during the past oil embargo period. With the exception
of Projection I, each forecast purports to be conservation oriented. A summary
of the results of these projections is shown in Table 4-5.
Peak Demand
Alaska's peak demand is expected to grow from 500 megawatts in 1978 to 1,700
megawatts in 2000, resulting in an average annual growth rate of 5.4 percent
over a 22-year period.
4-7
.1>-
1 co
Table 4-5
HARZA FORECAST OF ELECTRIC UTILITY POWER DEMAND, ALASKA
(1978-2000)
--·---------·-------------------------
7-Year
Growth
1978 Rate _.Y 1985
5-Year
Growth
Rate 1/ 1990
Population (thousands)
Projection
403. 2.6 483. 1.6 523.
Per Capita Consumption (MWh)
Total Use (Thousand GWh)
Peak Demand (GW)
Projection II
Per Capita Consumption (MWhl
Total Use (Thousand GWhl
Peak Demand (GW)
Project I on I II
Per Capita Consumption (MWh)
Tot a I Use (Thousand GWhl
Peak Demand (GW)
Median Project ion 21
Per Capita Consumption (MWhl
Total Use (Thousand GWh)
Peak Demand (GW)
Margin (Percent)
Resources To Serve Demand (G~i)
Load Factor (Percent l
-Notes:-
5. 6
2. 3
.5
5. 6
2.3
.5
5.6
2.3
.5
5.6
2.3
.5
47.8
12.3
15.2
14.6
2.6
5.3
6.6
2.6
7.2
6.6
4. 5
7.2
6.6
12.6
6. 1
1.4
6.7
3. 2
.8
6. 7
3. 7 .a
7. 6
3. 7
.8
47.3
1. 2
49.7
4.2
5. 8
5. 7
2. 6
4.2
5. 6
2.6
5. 7
5. 6
4.0
5. 7
5.6
J! The growth rates are average annual compounded rates over the period.
2/ Referred to in this report is the Harza Forecast.
15.5
8. 1
1. 8
8.7
4.0
1. 1
7.6
4. 9
1. 1
9.3
4.9
1. 1
50.0
'· 7
50.0
5-Year
Growth
Rate 11
1. 1
5. 7
6.9
6.9
2. 6
3. 7
4.4
2. 6
4.4
4.4
3.3
4.4
4.4
5-Year
Growth
1995 Rate 1/
552.
20.5
11.3
2.6
8.7
4. 8
1.4
8.7
6.0
1.4
10.9
6.0
1. 4
50.0
2. 1
50.0
1. 1
4.0
5. 1
5. 1
2.6
3. 7
4.3
2.6
4.3
4.3
3.2
4.3
4.3
2000
583.
24.9
14. 5
3.3
9.9
5. 8
1. 7
9. 9
7. 5
1. 7
12.8
7. 5
1. 7
50.0
2.6
50.0
Over a II
Growth
Rate I/
1. 7
7. 0
a. a
8.6
2.6
4.3
5.4
2.6
5. 6
5.4
3.8
5. 6
5.4
Factor
Alaska presently has the lowest regional annual load factor in the nation.
The annual load factor is expected to remain at about its present value of 50
percent through the remainder of the century.
Reserve Margin and_System Reliability
Due to the large distance and adverse terrain between load centers, most
Alaskan utility systems do not have transmission line interconnections. Thus,
the reliability of power within a particular generation system relies pri-
marily on an adequate local reserve margin. For this reason, reserve margins,
as presented in Table 4-4 currently range from very low in the Southcentral
subregion to high in the Southeast, and are expected to remain so. Studies are
currently under way to determine the feasibility of an interconnection between
the Southcentral and Yukon subregions, which would tie Anchorage and Fairbanks
together. For the purpose of this study, a reserve margin of 50 percent is
applied to the "median" peak demand to compute future capacity requirements.
Generation }fix
Table 4-6 shows the Harza-forecasted most probable generation mix for base,
intermediate and peaking capacity to 2000 for Alaska. The projected mix is
based on existing and planned generation facilities reported by the utilities,
characteristics of electric loads, an analysis of regional resource
availability, economic parameters, Federal and State regulations, and other
pertinent regional factors. To reflect the uncertainties and unforeseeable
factors which can affect future generation mixes, a range of future installed
capacity is defined for each major generation source. The projected mix is
based on the "median" demand and the reserve margins presented in Table 4-5.
In the past, Alaska has relied on combustion turbines as its principal
source of electric generation due to their low construction costs and the
availability of low-cost natural gas for fuel. However, this trend is
expected to change in the future. Many coal-fired plants are now under con-
sideration for the future. In addition, because of higher fuel costs, many
small hydropower plants are becoming economical to serve isolated areas.
Several small hydropower developments are now under construction or licensing.
The Susitna Project, now in the planning stage, could provide a large amount
of the Anchorage-Fairbanks electrical needs by the end of the century.
Several other smaller hydropower project sites exist and could be economically
developed in the future. Although interest has been expressed in a nuclear
generating plant for commercial use, it is considered unlikely that such a
power plant 'iY"Ould be in operation before 2000 due to excessive lead time and
E~conomic competition from hydropower and coal-fired energy generation sources.
4-9
Table 4-6
ALASKA GENERATION MIX
Percent of Total Capacity
_...._ ------~-~-----~---------------~ ~ ~--~-----------~---~------~
Gene rat ion Type 1985
(%)
1990
(%)
1995
(%)
2000
(lo)
-----------"--.---·------·----------------------~------~------~-------
Base
Coal 15-18 18-20 20-25 20-25
011 12-14 10-12 8-10 5-8
Gas 38-42 34-36 25-27 15-18
Conv. Hydro 2-4 5-10 10-20 20-30
Intermediate
Coal 2-4 3-5 3-5 3-5
Oil 5-6 4-5 4-5 3-5
Gas 5-6 5-6 4-6 4-6
Conv. Hydro 3-4 3-4 3-8 5-10
Other 0 0-1 0-1 1-2
Peaking
Oil 34 2-3 2-3 1-3
Gas 3-4 3-4 3-4 2-4
Conv. Hydro 2-3 2-3 4-6 5-10
Other 0 0-1 0-1 1-2
Total Capability (GW) 1.2 1.7 2.1 2.6
----------<---------~---~ ------·-~--
Specific Role of Hydropower
With a capacity of 131 megawatts, conventional hydropower represented
about 14 percent of the total installed capacity in 1977. Only two small
hydropower projects are under construction, Solomon Gulch and Green Lake,
although many hydropower sites are available for development. Several studies
of small .::tnd medium size hydropower developments are under way. The Susitna
Project with an estimated capacity of 1,558 megawatts has been the object of
many 3tudies, and the construction of the Watana and Devil Canyon Dams on the
Susitna River are under consideration. If these projects are approved, it is
likely that Anchorage and Fairbanks will be connected, greatly enhancing the
reliability of the two systems.
At this time no pumped-storage facilities are in the State and none are
planned by the utilities. While there ar<'! many conventional hydropower sites
to be developed, there is currently no economic incentive to develop a pumped-
storage project.
4-10
APA Forecast
Present Conditions
Based on data compiled by the Alaska Power Administration, the overall
installed capacity in 1979 was 1, 866.8 megawatts, and the overall energy use
was 4,836 million kilowatt-hours (552.1 average megawatts). More than one-
half of this energy was consumed in the Southcentral subregion, the most
heavily populated subregion of the State. Statewide, the total energy demand
increased by 1.6 percent in 1979. This was down from the 9.3 percent growth
rate registered in 1978. In 1979 the greatest increase in energy demand
occurred in the Southeast subregion with an overall growth rate of 4.1 percent
followed by the Southcentral subregion with a growth rate of 3.5 percent. All
other subregions of the State registered negative overall growth rates. A
regional summary of the Alaska capacity and net generation for the years
1977-1979 is presented in Table 4-7.
Future Conditions
The APA has made forecasts of the statewide electrical capacity and energy
needs for the years 1990 and 2000 based on high, medium and low growth con-
ditions. The results of the APA forecasts indicate that the total statewide
demand for electrical energy including utility, industrial and national
defense demands for the medium growth case will have increased from 4,386
million kilowatt-hours (552.1 average megawatts) in 1979 to 9,000 million
kilowatt-hours (1,027.4 average megawatts) in 1990 and to 15,000 million
kilowatt-hours (1,712.3 average megawatts) in 2000. A summary of the APA
demand projections broken down into the various subregions of the State is
included in Table 4-8.
4-11
Table 4-7
REGIONAL SUMMARY OF ALASKA CAPACITY AND NET GENERATION
1977, 1978, 1979 Preliminary
1977 1977 1978 1978 77-78 . -1979 1979 -19-79
Capacity Net Gen Capacity Net Gen Growth Capacity Net Gen Growth
REGION/Sector KW MWH KW MWH KW
SOUTHEAST
uti I ity 143,335 318,515 150,635 332,173 4.3 156,735 355,926 4. 1
lndustr Ia I 67,125 300,000 67,125 302,957 1.0 67,125 305,265 0.8
Total 210,460 618,515 217,760 635, 130 2. 7 223,860 661,191 4:T
SOUTI-CENffiAL
utility 556,383 1, 9201710 642,883 2,052,305 6. 9 717,533 2,150,386 4.8
Nat. Def. 55,726 153,868 55,726 164,574 7.0 55,726 156,404 -5.0
Industrial 107,890 317,845 113,685 376,028 18.3 113,685 376,028 0
Total 719,999 2,392,424 812,294 2, 592,90 7 ----s-:4 886,944 2,682,818 ·-:;;s-
YUKON
uti I ity 302,250 501,774 293,532 486,532 -3.0 295,132 464, 125 -4.6
Nat. Def, 86,625 232,352 86,625 217,967 -6.2 86,625 207,253 -4.9
Industria I 12,000 25,677 16,825 37,853 47,4 16,825 37,853 0
Total 400,875 759,803 396,982 742,432 -=2.3 398,582 709,231 -=4."5
ARCTIC NCRTHWEST
.p.. uti llty 24,579 44,905 25,746 47,701 6.2 26,111 48,295 I. 3
I Nat. Def, 6,940 20,771 6,940 19,470 -6.3 6, 190 18,254 -6.2
!-' Industrial 170,325 245,513 198,800 458,072 86.6 198,800 458,072 0 N
Total 201,844 311,190 231,486 525,243 ~ 231,101 524, 621 -=a:T
SOUTHWEST
uti I ity 24,579 44,905 25,746 47,701 6,2 26, 111 48,295 1. 3
Nat. Def. 49,200 139,600 56,150 124,800 -10.6 56, 150 115,936 -7. I
Total 71,617 181,774 80, 702 172,137 -..:s:-3" 80,802 163,641 -::;r;;9
ALASKA
uti I ity 1, 048,964 2,828,079 1,137,348 2,966,129 4. 9 1,220,163 3,066,437 3.4
Nat. Def. 198,491 546,591 205,441 526,811 -3.6 204,691 497,847 -5.5
Industrial 402,915 983,144 442,010 1,269,410 29.1 442,010 1,271,718 0.2
Total 1' 650,370 4,357,815 T, 784,799 4, 762,350 9":3" 1,866,864 4,836,002 r:o·
---------"~-----~·~--··~---------~~--
Table 4-8
APA FORECAST OF ELECTRICAL POWER DEMAND, ALASKA
------------1919 ___ " _____ 1980 ______ 2000
Capacity Energy Capacity Energy Capacity Energy
Area (MW) (GWh) (MW) (GW) (MW) (GWh) ------
Southcentral 887 2,683 1 '442 5,640 2,541 10,560
Yukon (Fairbanks
area) 339 709 600 1,364 675 2,072
Southeast 224 661 296 896 349 1,131
Southwest 81 164 108 252 134 358
Remainder of State 227 619 304 848 301 879
Total State 1..L86 7 4,836 2,800 9,000 4,000 15,000
Source: Alaska Power Administration.
Note:
1/ This is compared to the forecast of an energy demand developed by Harza
Engineering Company of 7,500 GWh in 2000 (See section 4.2).
4-13
Chapter 5
DESCRIPTION OF METHODOLGY FOR EVALUATION OF
POTENTIAL HYDROPOWER
5.1 GENERAL
The identification of sites in Alaska at which additional or new hydropower
could be feasibly developed was accomplished in four stages. The study began
with an inventory of potential hydropower sites, both existing and undeveloped.
The criteria applied at each of the successive screening stages required a
progressively more rigorous analysis to an ever-decreasing number of sites.
The overall objective was to identify sites that would warrant inclusion into
a regional hydropower development plan. Table 5-1 provides a summary of the
general plan of study. A flow chart of the screening process is shown in Figure
5-1. A discussion of the screening methodology is provided in the following
paragraphs.
5.2 INITIAL INVENTORY AND FIRST SCREENING
The objective of stage 1 was to inventory all water resources control sites
in Alaska including existing developed sites and previously identified undeve-
loped sites with the physical potential for hydropower production. To
accomplish this objective, an appraisal of the physical potential at both devel
oped and undeveloped water resources control sites was developed.
The initial study effort was directed toward identification of undeveloped
sites in Alaska with a power potential of one megawatt or larger using data from
previous studies and reports. Undeveloped sites with less than 1 MW power
potential were eliminated from the study using the formula:
Power potential (kW) = (Q)(h)(0.076)
PF'
Where: Q = Average annual discharge (cfs)
h = Net power head (ft)
0.076 =Factor based on the constant 11.8 and a plant efficiency of
about 85 percent
PF = Plant Factor (assumed 50 percent)
The average annual discharge for each undeveloped site was obtained from
actual or simulated measurements as necessary streamgage and observed discharge
data recorded by the U.S. Geological Survey (USGS) and data documented by other
agencies.
The next effort of stage 1 involved investigation of existing projects in
Alaska using data from the Corps of Engineers National Inventory of Dams, and
5-l
Stage
First
Second
Third
Objective
Inventory tot a I
physical hydro-
power potent I a I
Identify physical
potential showing
possible economic
teas I bi I ity
Identify econom-
ically feasible,
acceptable pro-
jects
Fourth ldenti fy projects
suitable for
study
Table 5-1
GENERAL PLAN OF STUDY
Number of Projects
and Potential Sites
Existing dams and
previous I y !dent If led
potential projects
Projects from stage 1
with a minimum physical
potentIa I
Projects from stage 2
with possible economic
feasibility
1. Projects from stage
3 that are econom I ca II y
feasible and acceptable
5-2
Basic Eva I uat ion
Screening Criteria
1st screening
lnstallable capacity
potential
2nd screening
Economic-powerhouse
cost vs. power
benet its
1. 1st screening
Economic feasibility
total powerplant
costs vs. power
benet its
2. 2nd ScreenIng
Acceptability
a. Env I ronmenta I
b. Social
c. Marketab I I ity
1. Conventional
system -match
developable potential
wIth demand.
2. Assess marketabil-
Ity of development.
Data
Required
1. Inventory of dams
2. Previous studies/
inventories of hydro-
power potent i a I
1. Form 1
2. Computer rout I nes-
power potent I a I I
powerhouse costs/
power benet its
1. 1st screening
Economic teas ibll ity
a. Form 2
b. Total plant cost
c. Regionalized power
benet its
d. Computer routines -
costs/benefits,
hydrology
2. 2nd screening
a. Form 2
envIronment a I ,
social, marketabll ity
and acceptabl I ity
data
b. Public Comments
1. Conventional system -
data from stages 1, 2, 3.
""' I
v.
STAGE 1
STAGE 2
STAGE 3
STAGE 4
(Fail 8/C
or cap
criterion)
Estimate Power
Potential
(capacity<1 MW) --i First Screening r-(capacity >1 MW)
(8/C >1.0 and cap >1 MW) Second Screening I-(cap <1 MW or
(Pass 8/C and-------
cap criterion)
8/C <10)
Environmental, Social, Acceptability Assessment
(No major 1 Fourth Screening t-(M~jor adverse
adverse Impacts)
impacts) 1 · 1 Delete Project
Recommend Project for Detailed Study
Figure 5-1
FLOW CHART OF SCREENING PROCESS
data on projects licensed by the Federal Energy Regulatory Commission (FERC).
Deleted from further study were all existing projects that would not yield a
power potential of one megawatt or greater, based on the formula: MW = 36 X
storage X head. This formula is based on the assumption that sufficient flow
would be available to refill the maximum capacity of each reservoir every 24
hours, and that all of the flow could be used to produce power at a head equal
to the height of the water control structure. This assumption assured that
any reasonable site would be retained for the next screening which required a
more rigorous analysis.
Following completion of the stage 1 evaluation, a Form 1 data sheet was
prepared on each developed and undeveloped site which passed the above screening
test. Recorded on the data sheets were the project's name, its location by
latitude and longitude, the drainage area, a representative streamgage number,
average annual flow and the project's installed capacity and corresponding
energy values. Also recorded for existing projects were data on the year a
project was completed, the type of structure, the active storage behind the
impoundment, and the project's specific purpose.
Sites failing to meet the minimum regional standard of one megawatt power
potential were not included in the computer data base developed for the study
and did not receive further consideration.
5.3 STAGE 2 (SECOND SCREENING)
Stage 2 involved a screening for preliminary economic feasibility of those
existing and undeveloped sites that met the one megawatt capacity criteria
established for the stage 1 (first screening). The principal task of the stage
2 activity was to refine estimates of capacity and energy for all sites
remaining on the active inventory. The criteria required a project to have an
economic benefit/cost ratio of 1.0 or greater. However, the economic criteria
were preliminary, as only the costs for the powerhouse and switchyard facilities
were estimated at this stage. The costs were at October 1978 price levels and
were amortized over 100 years at 6-7/8 percent interest to determine average
annual costs. These benefit/cost ratios were not interpreted as conventional
B/C ratios because only partial costs of power were computed. It was intended
only to eliminate sites clearly recognized as lacking economic feasibility.
However, because some local conditions merited special considerations, the
second screening retained a number of sites in the active file even though pre-
liminary B/C ratio was less than 1.0 to 1.0.
Additional information gathered during the second stage was used to
further evaluate the economic feasibility of new hydropower potential. The
physical characteristics of the dam considered the structure height and crest
length and the valley configuration. Also, the length of any waterway asso-
ciated with a diversion was considered. Other data compiled at this time
included a USGS streamgage number, refined latitude and longitude locations,
the reservoir size, and the computed active storage behind the dam impound-
ment.
Also during stage 2, identification was made of all sites included in the
stage 1 initial inventory that were capable of yielding a power potential of
5-4
50 kilowatts or greater at a benefit cost ratio of at least 1.0 assuming a
discharge exceedance frequency of 25 percent. The purpose of this activity was
to provide preliminary public information data on the National Hydroelectric
Power Study. In Alaska, 484 sites met the 50 kW -1.0 B/C ratio criteria. The
results of this inventory are published in the report entitled "Preliminary
Inventory of Hydropower Resources, Volume 1, July 1979."
5.4 STAGE 3 (THIRD SCREENING)
This screening activity was directed toward identifying those sites which
demonstrated firm economic feasibility. Form 2 data sheets were prepared for
all projects meeting stage 2 (second screening) criteria. These data included
more detailed site locations, physical site and valley characteristics taken
from available topographic maps, tailwater rating curves and other data to the
extent that it was available.
To assure that project cost etimates would be sufficiently detailed and
adequate for comparison, these estimates were based on the average of major
construction-cost items derived from historical experience at more than 100
Federally constructed projects nationwide and updated to the July 1978 price
level. Power benefits were computed by FERC and are equal to the annual cost
of producing a like amount of electricity with a thermal generating plant.
The cost of the hydropower project includes all major cost items including
where appropriate land, reservoir clearing and preparation, dam, spillway,
intake and outlet, waterway, turbines and generators, and switchyard equipment.
Because of the difficulty in developing generalized transmission line costs
which could be applied nationwide, transmission costs were omitted. (Detailed
cost estimating procedures used are described in Volume XIII of the final report
on the NHS, Data Base Inventory Support ~tudies). Annual costs reflect 6-7/8
percent interest, an economic project life of 100 years, costs for major re-
placements, and charges for annual operation and maintenance. Although cost
estimates are adequate for comparing potential hydropower developments with each
other on a comparable basis, the costs obtained for the projects are not suf-
ficiently detailed to be relied on as estimates of probable actual construction
costs.
This final screening involved the assessment of noneconomic factors to
determine overall project acceptability for all projects remaining under study.
Data on environmental and social impacts and institutional and marketability
constraints to development were compiled and entered on the Form 2 data sheets
and computer data base.
Projects were examined with respect to their effects upon existing land use,
anadromous fish and wildlife migration and habitat. Also investigated were
social impacts including a project's impact on recreation areas, a town site,
historic/archaeological sites, and other important cultural resource areas.
Current and proposed institutional laws were investigated to determine the
extent to which hydropower development has been constrained by such laws as the
Alaska Lands Bill. Known data was entered onto the computer data base with an
5-5
additional comment reflecting the present institutional status. The marketabi-
lity analysis was prepared by the Alaska Power Administration on those sites
which were found to be suitable for further study, after consideration of all
other constraints. The purpose of the analysis was to identify those poten-
tially feasible projects for which there would be a projected demand by 2000.
All sites remaining after the third screening were assessed according to the
data gathered on environmental, social, and institutional constraints to deve-
lopment. Those sites which passed all three criteria and would be marketable
were identified as potentially feasible hydropower projects and are recommended
for the detailed study for possible development. Some of the projects are
currently in the advanced stages of study or are under construction for power-
on-line in the early 1980's. Projects under construction are considered undeve-
loped since, at this time, they are not yet producing power.
5.6 STAGE 4 REGIONAL POWER PLAN
In this stage a regional power development plan was formulated. Regional
power demands were examined and compared to the energy that could be supplied by
the projects at those sites remaining under study following the fourth
screening. During the development of the regional power plan the sensitivity of
changed power values and the removal of environmental constraints were
considered. Also, electrical energy supply and demand within the major subre-
gions of the State were analyzed separately in view of the limited present and
projected development and the improbability that extensive interties, (with the
exception of an Anchorage-Fairbanks intertie), will be developed within the for-
seeable future.
The Arctic, Northwest and Southwest subregions have scattered isolated
electrical power demand centers. Power for these areas is presently generated
by fossil fuel plants and is distributed through the local community system.
There are no transimission facilities to areas outside each community.
Opportunities for interconnection in these isolated areas are highly unlikely.
The distances between villages, rugged terrain, and relatively small loads pre-
sent obstacles which make development of large-scale hydropower projects
substantially infeasible in these areas. Special State legislation has provided
financing to expedite development of the Kisaralik and Lake Elva projects in the
Southwest subregion. The Lake Elva project is of marginal size (l MW) although
it appears to be the major prospect for hydropower in the Dillingham area.
There are few options for such remote areas; therefore, diesel-electric
powerplants are expected to continue as the main source of electricity past
2000.
The Southcentral subregion has the largest demand for electrical power in
Alaska. A number of potential hydropower sites have been investigated. The
prime alternative is development of two dams on the Susitna River. The next
largest potential hydropower development is on Chakachamna River, however, this
project could have land use conflicts since its development would have a minor
impact on the Lake Clark National Park. Small individual sites are av?ilable
that could satisfy a portion of the demand for this market area. Other sites
with acceptable capacity and economic capabilities have been precluded by
5-6
restrictive land use designation, such as national parks, national monuments,
national wildlife refugees, and wild and scenic rivers.
The development of an intertie system between Fairbanks, Anchorage, and the
Kenai Peninsula has been explored as a means of improving the efficiency in
energy use. Current construction includes the interconnection of Glennallen and
Valdez. A long range subregional grid interconnection could tie these systems
together with the railbelt (Anchorage-Fairbanks) scheme. If economically
feasible, this would lead to better regional coordination and optimal use of
power generation resources.
Kodiak Island falls within the Southcentral subregion. However, for all
practical purposes it remains isolated from any consideration of interties with
the mainland. A number of potential hydropower sites on Kodiak were screened
out during the advanced planning of the Terror Lake project. This project
would generate 20 megawatts of power in the first stage and an additonal 10
megawatts in a second stage of development. Other potential projects on Kodiak
Island include Larsen Bay, Port Lions, and Old Harbor. These projects are being
addressed in the Small Hydropower Study being done by the Alaska District Corps
of Engineers.
The Southeastern subregion is isolated from any of the larger power systems;
therefore, separate power systems are required to serve each community. In most
cases, the distances between towns, the rugged coastal terrain, and relatively
small loads preclude economically feasible intertie developments. A substantial
regional transmission system would be needed to utilize the available hydropower
energy resources and the required investments for such facilities would be very
large. Current planning includes possible interconnection between Petersburg
and Wrangell and another system connecting Ketchikan and Metlakatla. This would
be a major step toward creation of a Southeast subregional power system. For
long range planning, a regional grid interconnection with neighboring Candian
systems should be explored. Presently the opportunities for development of many
independent hydropower sites to serve individual communities appears to be the
most efficient method of meeting the load demands in Southeast Alaska.
5.7 PUBLIC INVOLVEMENT
Public involvement provided effective exchange of data on existing and
potential site development. Early public involvement consisted of telephone
calls, meetings with individuals, and letters to interested parties. To fami-
liarize the State agencies with the study, a coordination meeting was held in
Anchorage on 20 June 1980. The purpose of the meeting was to present the com-
puter techniques used to evaluate the power potential at the respective sites,
discuss the procedures for ranking the various projects according to economic
and environmental factors, and to discuss the utilization of the completed data.
Public Meeting
A report summarizing the progress of the study was prepared and disseminated
in July 1980. This report also announced that a public meeting was to be held
on 19 August 1980 to review the findings to date of the National Hydroelectric
5-7
Power Study. The meeting was held at Central Junior High School in Anchorage.
The meeting was cosponsored by the North Pacific Division and the Alaska
District. Colonel LeeR. Nunn, Jr., Alaska District Engineer, chaired the
meeting. Colonel Nunn introduced the meeting and made a few general comments
about the National Hydropower Study, its objectives and what had been
accomplished. }1r. Thomas White, North Pacific Division, study manager,
described the regional efforts and how it would fit into the scope of the
national study. Mr. Carl Barash, Alaska District, Chief Reports Section,
described the study results for the Alaska Region. A question and answer period
followed the presentation.
Review of Draft
The final stage in the public-involvement process was to make the draft of
this report available for review and comment by all those interested. The
report draft was completed in December 1980 and was available for review through
April 1981. Copies of the report were sent (December) to the Governor and heads
of State and Federal Agencies. In addition, a public notice announcing the
completion and availability of the report was sent (December) to interested
individuals and organizations. The public notice included a summary of the find-
ings of the study and a solicitation that comments be provided. Written com-
ments received were used in revising the report and are included in Appendix B
of this report.
5-8
Chap~r6
INVENlORV
6.1 GENERAL DISCUSSION OF STAGES 1, 2, and 3
Size of Inventory
During the initial stage of the NHS in Alaska the potential for additional
hydropower generation was evaluated at 61 existing water resource project sites
and 634 undeveloped sites. By means of the screening process described in
Chapter 5, the number of sites demonstrating potential economic feasibility and
environmental acceptability (stage 3 -fourth screening) was reduced to 59
including 10 existing projects and 49 undeveloped sites. Because of the number
of sites involved and the limited time frame, collection and analysis of site
data was based on available and readily developed information. No field
investigations were included as part of the study. A summary of the number of
projects included in each stage, in each of the six major subregions of the
State, is presented in Table 6-1.
Potential Hydropower Capacity and Energy
As indicated above, analyses to date of Alaska's physical hydropower poten-
tial and economic and non-economic constraints to project development indicate
that just 59 projects are suitable for further study. These project have
capacities of at least 1 megawatt, with a few exceptions; are in areas where a
demand exists or is projected to exist by 2000; are economically attractive
based on their estimated energy costs; and do not have severe environmental
or social constraints to development. The following discussion summarizes the
findings of the NHS in Alaska during each stage of the study.
Total Physical Hydropower Potential
The State's total physical hydropower potential at projects with a capabi-
lity of at least 1 megawatt of capacity, with a few exceptions, is represented
by those projects which were included in Stage 2 (see table 6-1). The physical
characteristics of the sites are such that, from an engineering viewpoint, no
insuperable constraints to development exist. The estimated generating capacity
available from the State's physically feasible projects is over 42.7 million
kilowatts. The average amount of energy available yearly from these projects
would amount to over 224.4 billion kilowatt-hours annually, enough electricity
to supply the needs of a population of over 40 million, based on 1978 State per
capita consumption of 5.6 megawatt-hours. Alternatively, producing the same
amount of electricity using oil-fired combustion turbines would require 374
million barrels of oil per year. The potential capacity and energy available
from the State's physically feasible projects is shown in Table 6-2; data are
shown for each subregion and for existing and undeveloped projects.
6-1
0\
I
N
Table 6-1
SUMMARY OF HYDROPOWER PROJECT SCREENING RESULTS, ALASKA
---------~-~
STAGE 1 STAGE 2 STAGE
Initial First ~cond
Inventory 1/
Existing Ondev.
Screening 21
Existing Onilev.
ScreenIng 3/
rxTSTin'g Ond e v.
Screening 4/
l:xistlng Lfidev.
Screening 5/
EX1sfing Ondev.
Proj_ec~_J)ites Tota I __ P_r_ojects Sites Total Projects Site~-Tota I Projects_ Sites Tota I Projects Sites Total
ARCTIC 0 5 5 0 5 5 0 3 3 0 2 2 0 0
NORTHWEST 0 27 27 0 16 16 0 16 16 0 6 6 0 0
YUKON 3 56 59 3 51 54 0 51 51 0 21 21 0
SOUTHWEST 2 38 40 2 28 30 0 28 28 0 7 7 0
SOUTHCENTRAL 14 196 215 12 138 150 1 132 133 0 41 41 0 16
SOUTHEAST 42 312 349 40 189 229 18 173 191 13 70 83 10 28
ALASKA TOTAL 61 634 695 57 427 484 19 403 422 13 147 160 10 49
-------------------~--
Notes:
1/ The total number of existing dams and previously studied, undeveloped sites inventoried (includes mutually exclusive alter-
native projects).
0
0
16
38
59
2/ The number of projects from the lnt itial Inventory might have hydropower development potential and were Inc I uded in the NHS com-
puter data base. Mutually exclusive alternative projects are Included.
3/ The number of existing projects and undeveloped sites which have the physical potential for hydropower development and might be
economically feasible. Mutually exclusive alternative projects are Included.
4/ The number of projects which would be economically feasible to develop if a market for the power existed and there were no non-
economic oonstraints. Mutually exclusive alternative projects are included.
5/ The number of economically feasible projects which are suitable for further study and possible development. Mutually exclusive
alternative projects are not included.
Table 6-2
TOTAL HYDRO POWER POTENTIAL, ALASKA
---
Existins Projects Undeveloped Sites Total
No. Capacity Energy 1-b, Capacity Energy 1-b. Capacity Energy
Subregion (MW) (GWh) (MW) (GWh) (MW) (GWh)
ARCTIC 0 0 0 3 222.0 1,073.0 3 222.0 1,073.0
NORTHWEST 0 0 0 16 103. 1 4,613.8 16 103. 1 4,613.8
SOUTHCENTRAL 0.3 o. 9 125 11,336.2 58,289.3 126 11,336.5 58,290.2
SOUTHEAST 18 31.6 177.0 170 9, 512.3 43,343,9 188 9, 543. 9 43,520.9
SOUTHWEST 0 0 0 28 3, 250.9 14,529.4 28 3,250. 9 14,529.4
YUKON 0 0 50 18,275.7 102,422.0 50 18,275.7 102,422.0
TOTAL 19 31.9 177.9 392 42,700.2 224,271.4 411 42,732.1 224,449.3
Notes:
1. Excludes existing hydropower projects which do not have additional
development potential.
2. Excludes mutually exclusive alternative projects.
Total Economically Feasible Hydropower Potential
The State's economically feasible hydropower potential is represented by·
those projects which passed stage 3t first screening (third screening shown in
Table 6-1). These are projects which would be economical to build when com-
pared with the cost of building thermal power plants to produce an equivalent
amount of energy. It is emphasized, however, that hydropower project costs
are based on generalized cost estimating procedures adjusted for Alaska
construction costs, 6-7/8 percent Federal interest, 1978 price levels, and a
100-year project life. It is further noted that, in this instance, Alaska is
unique among states in that its potentially economically feasible hydropower
potential greatly exceeds its present and projected demand for electricity.
The marketability of potentially feasible projects was considered during the
fourth screening, i.e. the second screening of stage 3 as indicated in Table
6-1.
Ignoring the fact that no market exists for much of Alaska's potentially
feasible projects, the generating capacity available from the State's economi-
cally feasible projects is nearly 38.0 million kilowatts. The average energy
available from these projects is over 197.0 billion kilowatt-hours annually.
The potential capacity of, and energy available from, the State's economically
feasible power projects is shown by subregion, for existing and undeveloped
projects in Table 6-3.
6-3
Table 6-3
TOTAL ECONOMICALLY FEASIBLE HYDROPOWER POTENTIAL, ALASKA
Existing Projects Undeveloped Sites Total ----------~·-----"-·· ··--·--
No. Capacity Energy No. Capacity Energy No. Capacity Energy
Subregion (MW) (GWh) (MW) (GWh) (MW) (GWh)
-------------------·------------------------------
ARCTIC 0 0 0 2 201.0 972.0 2 201.0 972.0
NORTHWEST 0 0 0 6 847.0 3,724.5 6 847.0 3,724.5
SOUTHCENTRAL 0 0 0 38 8,746.0 45' 97 6. 4 38 8,746.0 45,976.4
SOUTHEAST 13 25.0 177.0 70 8,828.8 40. 138. 6 83 8,853.8 40,315.6
SOUTHWEST 0 0 0 7 2,557.7 11,377.7 7 2,557.7 11,377.7
YUKON 0 0 0 20 16,7§3.6 _14 '6~2 .0 20 16,763.6 _94, 642. o_ ----
TOTAL 13 5.0 177 .o 143 37,944.1 196 '831. 2 156 37 .~69.1 __ !_~~08.2_ -------
Notes:
1/ Excludes mutually exclusive alternative projects.
2/ Potential economic feasibility does not consider marketability.
Projects Suitable for Further Study
To select projects suitable for further study, potentially economically
feasible projects were screened to eliminate those with major environmental
constraints and those whose output could not be marketed by 2000. Fifty-nine
potential projects having a total capacity of over 3.5 million kilowatts and an
average energy potential of more than 15.5 billion kilowatt-hours annually passed
the environmental and marketability screening criteria and are considered to be
suitable for detailed study either by the Corps of Engineers, State or local
governments, public or private utilities, or private investors. Projects iden-
tified for further study range from small (less than 25 MW) to large capacity.
The projects listed by range of capacity are: 20 projects have a capacity of less
than 10 MW; 25 projects have a capacity ranging from 10 MW to 50 MW; 7 have a
capacity in the 50 MW to 100 MW range; and 6 have a capacity of greater than 100
MW. The capacity and energy potentials from both existing and undeveloped pro-
jects are summarized by subregion in Table 6-4.
Plant Factors. Plant factors for the projects passing the stage 3 -fourth
screeing of the inventory vary from 0.23 to 0.91. The average plant factor
equaled 0.50 with the majority of the projects having plant factors varying from
0.4 to 0.6.
Primary Locations. The greatest number of projects are located in the
Southeast subregion which has 38, followed by the Southcentral subregion with 15.
The Arctic and Northwest subregions of the State did not have any projects which
passed the screening criteria. The Yukon subregion had one project while the
Southwest subregion had four projects.
6-4
Table 6-4
HYDROPOWER POTENTIAL AT PROJECTS SUITABLE FOR FURTHER STUDY, ALASKA
Existing Projects Undeveloped Sites
No. Capacity Energy No. Capacity Energy
Subregion (MW) (GWh) (MW) (GWh)
NORTHWEST 0 0 0 0 0 0
NORTHWEST 0 0 0 0 0 0
SOUTHCENTRAL 0 0 0 16 2,738.0 12,161.7
SOUTHEAST 10 16.8 161.8 28 520.2 2,276.8
SOUTHWEST 0 0 0 4 51.7 375.7
YUKON 0 0 0 1 200.0 566.0
TOTAL 10 16.8 161.8 49 3,509.9 15,380.2
Note: Excludes mutually exclusive projects.
No.
0
0
16
38
4
1
59
Total
Capacity
(l1W)
0
0
2,738.0
537.0
51.7
200.0
3,526.7
Energy
(GWh)
0
0
12,161.7
2,438.6
375.7
566.0
15,542.0
Existing Projects. Providing additional hydropower potential from the 10
existing projects would be accomplished through expansion of the existing hydro
power plants or providing additional storage. Total potential capacity created by
the development was estimated to be 16,800 kilowatts while providing 161.8 million
kilowatt-hours annually.
New Sites. There are 49 undeveloped sites having a total capacity of 3.5
million kilowatts and energy potential of nearly 15.4 billion kilowatt-hours.
6.2 Stage 4 Inventory
Projects Retained During Stage 4
The 59 projects that passed the stage 3 fourth screening were retained in
stage 4 as projects suitable for further study and possible development.
Physical Characteristics
Selected projects are classified into four groups (see Table 6-5):
a. Reservoir projects.
b. Reservoir with diversion projects.
6-5
c. Diversion projects.
d. Run-of-the-river projects.
Existing Projects. Of the existing projects, four are reservoir projects, four
are reservoir with diversion projects, one is a diversion project; and one is a
run-of-the-river project.
Undeveloped Sites. Twenty-eight of the undeveloped sites would be reservoir
with diversion projects; eighteen would be reservoir projects) and three would be
run-of-the-river projects.
Economic and Financial Characteristics
The computer estimated average cost of energy for the 59 projects varies
from 11.53 mills/kWh to 290.58 mills/kWh. Total annual project costs were
derived by summing the annual maintenance costs and the first cost based on
100-years project life and amortized at the Federal discount rate of 6-7/8
percent.
General Environmental and Social Conditions
Expansion of the existing hydropower projects would have no significant
environmental impact in most cases. Generally, any adverse modification to the
environment would have already occurred.
All of the new development sites were assessed in relation to their impact
on fish and wildlife, cultural resources, scenic beauty and impacts to
designated national parks or monuments. Those projects which would have signi-
ficant adverse impacts on these resources were dropped from further study. The
projects identified for further study either would have minimal adverse impacts,
or the magnitude of the impacts have not been conclusively determined.
Table 6-5
PROJECT TYPE AND STATUS IDENTIFIER
--·----------~-~-----
Operation
Status of Waterway Run of Reservoir with Irrigation Pumped
Structure River Diversion Reservoir Diversion Canal Storage
Existing A B c D E F
Existing with Power G H I J K L
Existing with
Retired Power Plant M N 0 p Q R
Breached s T u v w X
Breached with
Retired Power Plant y z 0 1 2 3
4 5 6 7 8 9
6-6
Chap~r7
EVATUATION
7.1 REGIONAL PLAN DEVELOPMENT PROGRAM
The impact of hydropower development was addressed through evaluation of
preliminary environmental constraints and screening criteria. Much of the
potential land and water resource development in Alaska is subject to current
political issues. Until recently, millions of acres of Alaska were withdrawn
from potential development by former President Carter under the provisions of
the Antiquites Act. The Alaska Lands Bill passed by Congress and signed into
law in December 1980 negated the land withdrawals under the Antiquites Act but
then designated a majority of these same lands, plus additional lands, as either
national parks, wild and scenic rivers, wildlife refuges, or wilderness areas.
Until implementation regulations are promulgated, it is unknown whether poten-
tial hydropower projects will be precluded from development by certain land
classifications. It is hoped that this study will provide useful information
for continued assessment of hydropower development as a viable alternative for
meeting Alaska's future energy needs.
A total of 49 undeveloped sites and 10 existing projects have emerged from
the three-stage screening for possible adoption in a development plan for
Alaska. These 59 projects are listed on Table 7-1, and their locations are
shown in Figure 7-1. They are listed by map number and should not be construed
as being in order of preferred development. More complete physical,
environmental, and social impact data on these and other projects studied are
presented in Appendix A.
The projects passing the final screeing have been evaluated as to their
potential impacts on several environmental and social concerns. These potential
impacts have been coded and are listed in the Appendix. A ranking system based
upon economic and environmental considerations was not developed. It was deter-
mined that such a ranking system would be inappropriate for Alaska. In Alaska,
the decision to develop a hydropower project must be based on a need as well as
a viable means of satisfying that need for a given locality. Interties between
geographical regions and communities are impractical in many areas, especially
Southeast Alaska.
7.2 TRANSMISSION INTERTIES
Alaska's population is primarily urban, concentrated in a few principal
cities and many smaller towns and villages. Fairly extensive interconnected
systems serve the population centers in the Anchorage-Cook Inlet and
Fairbanks-Tanana Valley areas. The rest of the State's power systems are iso-
lated, with electrical service usually limited to the immediate urban and suburban
areas. Some small communities scattered throughout the State have interties
between local utilities, industries, and military bases. Over 60 percent of the
State's population is served by the interconnected transmission system in the
Anchorage-Cook Inlet area. Five utilities, several industries, and two national
defense installations are tied to this system. In the Fairbanks area, two uti-
lities and three military bases are intertied.
7-1
Table 7-1
POTENTIAL HYDROPOWER SITES IDENTIFIED FOR DETAILED STUDY, ALASKA
Map Site Add itlonal Additional Average
Index Subregion I dent Capacity Energy Cost of
Number ProJect Name Number Stream LatItude Long I tude Owner Potentia I Potent I a I En~
( kW) (MWh) (mills/KWh)
Yukon
1. Browne AK6NPA0427 Nenana River 64 11.0 149 15.0 undeveloped 200,000 566,000 48.99
2. Kisaralik AK6NPA0012 Kisaralik River 60 26.4 160 5.5 undeveloped 30,000 131,000 56.72
3. Tazimina AK6NPA0032 Tazlm! na 59 58.0 154 33.0 undeveloped 18,000 224,000 17.00
.... 4. Grant Lake AK7NPA0018 Wood River 59 45. 1 158 32.0 undeve I oped 2,700 12,700 145. 87
I
tV
5. Lake Elva AK7NPA0155 Elva Creek 59 37.9 157 o.o undeveloped 1,000 8,000 290.58
Sout hcentra
6. Chu lltna AK6NPA0181 Chu I itna River 63 4. 9 149 45.0 undeveloped 34,000 166,000 45.07
7. Dev 1 I Can yon AK6NPA0188 Susitna River 62 48.9 149 18.9 undeveloped 776,000 3, 410,000 11.53
8. Watana AK6NPA0222 Sus ltna River 62 48.9 148 30.9 undeve I oped 792,000 3,480,000 17.97
9. Chakachamna AK7NPA0106 Chakachamna 61 13.0 152 22.0 undeveloped 366,000 1, 600,000 12.30 1/
---------·-·-· ----
1/ The project cost estimate for Chakachmna assumed construction of a open-channel waterway; but a tunnel would be
required thus substantially adding to Its costs.
Table 7-1 (cont)
Map Site Add It lonal Additional Average
Index SubregIon I dent Capacity Energy Cost of
Number ProJect Name Number Stream Lat !tude Lonsitude Owner Potential Potential Energy
( kW) (MWh) (mills/KWh)
10. Talkeetna AK6NPA0216 Talkeetna River 62 28.0 149 22.0 undeveloped ro,ooo 406,400 23.34
11. Keetna AK6NPA0197 Ta I keetna RIver 62 26.5 149 41.6 undeveloped 74,000 324,000 30.38
12. Skwentna AK6NPA0211 Skwentna Rl ver 61 51.9 152 7.0 undeve I oped 98,000 490,000 30.02
13. Yentna AK6NPA0224 Yentna RIver 61 36.9 150 32.0 undeveloped 219,000 960,000 38.47
14. Beluga Upper AK6NPA0175 Be I uga Rl ver 61 15.9 151 15.0 undeveloped 48,000 210,000 53.06
15. Coffee AK6NPA010B Be 1 uga R i ver 61 12.0 151 10.0 undeve I oped 37,000 160,000 50.41
....
I 16. \.M
Solomon Gu I ch AK7NPA0384 Solomon Gulch 61 30.9 146 15.9 under cons t. 12,000 65,000 25.57
17. AI I I son Creek AK7NPA0041 Allison Creek 61 7. 1 146 10.2 undeveloped 8,000 37,250 32.16
18. Snow AK7NPA0283 Snow River 60 17.9 149 18.0 undeve I oped 63,000 278,000 31.24
19. Brad ley Lake AK7NPA0103 Brad ley Creek 59 45.0 150 51.0 undeveloped 94,000 410,000 18.40
20. Terror Lake AK7NPA0166 Terror River 57 40.0 153 6.0 undeve I oped 20,000 139,000 19.94
21. Power Creek AK7NPA0039 Power Creek 60 36.0 145 34.0 undeveloped 7,000 26,000 103.34
Southeast
22. Pelican AKINPA0346 Pelican Creek 57 34.7 136 7.8 Pelican 1,000 1, 700 75.57
Utility Co.
Table 7-1(cont)
----·-·----·-------·-·.--
Map Site Additional Additional Average
Index Subregion I dent Capacity Energy Cost of
Number Pro~ct Name Number Stream _ Longitude Owner PotentIa I Potential Energ:i
(kW) (MWh) (mills/KWh)
23. Kasnyku Lake AK7NPA0335 Kasnyku Falls 57 11. 0 134 49.9 undeve I oped 7,000 30,000 41.63
24. Takatz Q-eek AK7NPA0311 Takatz Q-eek 57 6.9 134 51.0 undeveloped 20,000 97,000 34.48
25. Carbon Lake AK7NPA0321 Unnamed 57 1. 9 134 28.1 undeveloped 10,000 49,000 58. 16
26. Milk Lake AK7NPA0294 Mi I k Q-eek 56 58.0 134 47.0 undeveloped 7, 000 33,000 39.10
27. Diana Lake AK7NPA0325 Unnamed 56 53.0 135 3.0 und eve I oped 8,000 35,000 35.65
28. Green Lake AK7NPA0332 Vodopad River 56 95.3 135 11.6 under const. 16,000 64,000 48.47
-..J 29. Maksoutof AK7NPA0291 Maksoutof 56 30.0 134 57.9 undeveloped 24,000 117,000 23.47 I
.l>o
30. Borod i no Lake AK7NPA0319 B.P. Walter 56 22.3 134 42.9 undeveloped 5,000 24,300 44.51
31. Goat Lake AK7NPA0357 Pitch Fork 59 31.3 135 11.0 undeveloped 10,000 46,000 33.80
32. Dewey Lake AKINPA0359 !:ewey Q-eek 59 26.4 13518.9 A I as ka Power 1,000 1, 300 83.40
& Tele Co
33. Dayebas Creek AK4NPA0078 Dayebas Creek 59 17.2 135 2. 0 undeve I oped 5,000 18,200 65.95
34. Gold Creek y AKHNPA0099 Gold Creek 58 17.9 134 23. 9 Alaska Elec 2,000 9,000 34.90
Light & Power
Co.
·~·-··-~-~--
1! Although shown here and on the map (figure 7-1), reassessment of Gold Creek indicates that additional development,
although potentially feasible, is unlikely.
-.J
I.
\.n
Table 7-1(Cont)
Map
Index
N1.111ber
Site A:lditional Additional Average
SubregIon ldent Capacity Energy Cost of
Project Na~ _ .N.~be_r ~~-~Ji!r~a.rn.-~~~~· Latitude Longitude Owner Potential Potential Energy
35. Treadwei I Ditch_..!/ AKMNPA0086 Treadwel I
36. Annex AKINPA0098 Annex Creek
37. Lake Dorothy AK5NPA0096 Dorothy Oreek
38. Speel Division AK6NPA0082 Speel River
39. Snettisham y AKJNPA0102 Long Lake
40. Crater Lake y AK7NPA0356 Crater Creek
41. Tease AK7NPA0084 Tease Creek
42. Upper Sweetheart AK7NPA0143 Sweetheart
43. Sweetheart AK7NPA0083 Sweetheart
44. Scenery Creek AK7NPA0401 Scenery Creek
45. Fai Is Lake AK7NPA0417 Cascade Creek
46. Thomas Bay AK7NPA0310 Cascade Creek
47. Ruth Lake AK7NPA0400 Delt Creek
58 15.5 134 22.3 Alaska
Treadwel I
58 19.5 134 7.6 A.J. Ind.
58 14.0 134 3.0 undeveloped
58 6. 9 133 42. 9 undeve I oped
58 5. 9 133 48.0 AI aska Power
AdmInIstration
58 8.0 133 45.7 undeveloped
58 5.9 133 40.2 undeveloped
57 59.7 133 30.6 undeveloped
57 56.6 133 38. 1 undeve I oped
57 4. 9 132 41.9 undeveloped
57 1.1 132 45.1 undeveloped
57 3.3 132 45.2 undeveloped
56 59.0 132 45.0 undeveloped
(kW) (MWhl (mil Is/KWh)
2,500 10,000 25.70
1,800 3,000 15.24
34,000 150,000 15.24
63,000 275,000 32.84
0 57,100 23.50
27,000 106,000 30.47
16,000 70,000 29.42
7,000 31,000 42.94
29,000 127,000 38.19
15,000 67,000 34.04
44,000 190,000 18.20
50,000 217,000 18.47
13,000 63,000 45.61
!! Reconstruction of abandoned project considered unlikely today by Alaska Power Administration.
y Capacity and energy potentials and project costs are based on a Juneau area power market analysis by Alaska Power
Administration and on site-specific studies of hydrology and construction costs by the Corps of Engineers.
Table 7-1(concluded)
------
Map Site Additional Additional Average
Index Subregion I dent Capacity Energy Cost of
Number Project Name Number Latitude Long !tude Owner Potential PotentIal Energy
(kW) (MWh) (mills/KWh)
48. Anita AK6NPA0414 Zimovla Straiaht 56 15.5 132 26.5 undeveloped 3,200 14,000 54.60
49. Harding River AK7NPA0301 Harding Rl ver 56 16. 1 131 38,9 undeveloped 18,000 85,000 60.44
50. Tyee Creek AK7NPA0408 Tyee Creek 56 12.0 131 33.0 undeveloped 30,000 133,000 27.66
51. Swan Lake AK7NPA0132 Falls Creek 55 35.9 131 31.1 undeveloped 22,000 85,000 58.33
52. Mahoney Lake AK7NPA0123 Mahoney Lake 55 25.0 131 31. 1 undeveloped 14,400 56,000 30.42
53. Upper Silvis AKDNPA0139 Beaver Fa I Is 55 22,8 131 30.9 City of 2,000 49, 100 21.71
...., Ketchikan
I
0\
54. Lake Connell AKDNPA0141 Ward Creek 55 26.0 131 40,2 City of 2,000 10,400 56,45
Ketchikan
55. Ketchikan AKINPA0138 Ketchikan Creak 55 21. 5 131 37.0 City of 2,000 15,000 15, 11
Ketchikan
56. Chester Lake AKPNPA0097 Nichols Ott 55 7. 1 131 31.6 City of 2,500 5,200 48.785
Met lakat Ia
57. Black Bear AK7NPA0104 Black Bear 56 32.9 132 o. 5 undeveloped 5,000 22,000 44.36
58. Lake Mary AK7NPA0395 Old Franks Creek 55 26,0 132 29.0 und eve I oped 9,600 42,300 49.80
59. Mellen Lake AK7NPA0255 Reyno Ids Creek 55 12.0 132 36.0 undeve I oped 8,000 30,000 41.68
--·------~-----~-~----····~-------------
"' ·~·
"-1
I
"-1
v
~
~
"
_£;P~,u~<,_C'
"'-
T
A A
!!3RTHWEST
~ j( '"""''.y""(_~-) ~~.··~~ _.. \ '-. ' . lK '?> 'L,__ . ·---~~
(. j •
\ ·-·'
~-'"",..._~_.··~
+ Vv'4
ok "\(
5' Ou N i) (
~'· -~·-.J ~ 4'v/
/' \'. v . l
~-1
(--v::.,_ .• 1~~ --~ .
. h . ----::~-·"'-.J __, ~ t"'' ~ ~ 4'()..-
\" B£THC~,:~ 2 ~~;_j\
' 5 /
j, .r~1lii.L'NGJtHM &' ""\.. {7 ., ~\ ~
' I ~-
~~ ' p' 8 A ~
,.. 0 L ---\ w BR;S' _..,/' ~~
-~
SOUTHWEST
<1
c
£
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4RCTtc l
~ --·--
~.~
I
YUKON
-. ' SOUTHCENTRAL OF
L4K
F I c
0 c
c I A p
f1 r· :;-f
Figure 7-1
SITE LOCATION MAp
E
4 ,y
36
-30 :-:-~41 ~· .. ,
'43 44",, 146
24 '·<'t.Jr>j
2 "' :4s~~'\47 ~-._
"' ............... '·~;)\:, d~:;:_;. .,··-)
'30 vf ~-r t, ···~P:,_ ., . f41,J~r·"~~?... ~~
v 57~s;.-... -~53 ~7L5~~;?. A; "~~.~, "! •'!fi .
7.3 COMPARISON OF ELECTRICAL POWER DE}1AND WITH HYDROPOWER POTENTIAL
The projections of capacity and energy demand shown following for each
subregion include utility, self-supplied industry, and national defense needs.
Table 7-2
SUMMARY OF REGIONAL ELECTRICAL CAPACITY AND ENERGY DEMAND, ALASKA
--·----------
1979 1990 2000 -· Capacity Energy Capacity Energy Capacity Energy
Subregion (MW) (GWh) (MW) (GWh) (MW) (GWh)
-----· --------·-·-~---~-~.-~
Southcentral 887 2,683 1,442 5,640 2,541 10,560
Yukon 399 709 600 1' 364 675 2, 072
Southeast 224 661 296 896 349 1, 131
Southwest 81 164 108 252 134 358
Remainder of
State 277 619 304 848 301 879 --------
Total 1,867 4,836 2,800 9,000 4,000 15,000
---
The year 2000 energy requirement of 15.0 billion kilowatt-hours is roughly a
three-fold increase over estimated 1980 requirements and would represent an
average annual growth of 6 percent for the 20-year period.
It is likely that actual requirements may be substantially higher or lower
depending on pace of development of the Alaska economy and effectiveness of
various energy conservation programs.
Harza Engineering Company, in connection with the NHS, prepared three pro-
jections of future electric energy needs. Year 2000 estimates of energy use
excluding national defense and industrial use were as follows: Projection
l--14.5 billion kilowatt-hours; Projection 2--5.8 billion kilowatt-hours; and
Projection 3--7.5 billion kilowatt-hours; Projection 1 of 14.5 billion kilowatt-
hours is very close to APA's estimate of 15 billion kilowatt-hours. Inasmuch
as the Harza projections (1) did not consider national defense and industrial
needs and (2) used the 1972 OBERS population projections, which are generally
recognized as being inappropriate for Alaska conditions, it would be reasonable
to accept the APA projection as more realistic.
Comparing the hydropower potential with the projected demand of each
region (Table 7-3) reveals that, with electrical transmission interties, most
of the power needs of the Southeast, Southcentral, and the Yukon subregions of
Alaska could be met by hydropower. In addition, approximately 39 percent of
the power requirements of the Southwest could be met by hydropower. The power
requirements of the Arctic and Northwest subregions would have to be met by
other means.
7-8
Table 7-3
.REGIONAL ELECTRICAL CAPACITY AND ENERGY DEMAND VERSUS HYDROPONER POTENTIAL
Estimated Hydropower Marketable
Region Demand Potential Hydropower
Potential 1 I
Capacity Energy Capacity Energy Capacity Energy
(MW) (GWh) (MW) (GWh) (MW) (GWh)
Southcentral 2,541 10,560 2,738 12' 162 2,587 11,184
Southeast 349 1' 131 537 2,439 152 668
Southwest 134 358 52 376 84 368
Yukon 675 2, 072 200 566 200 566
Remainder of State 301 879 0 0 0 0 ------
4,000 15,000 3,527 15,543 3,023 12,786
1/ Marketable Projects by Year 2000. Source: Alaska Power Administration
7-9
Appendix A
SUMMARY OF LISTING OF POTENTIAL PROJECTS
Introduction
A primary objective of the NHS was to inventory and evaluate potential
hydropower projects. Projects inventoried included existing dams and other
water projects and previously studied undeveloped sites. Project data were com-
piled from existing information sources supplemented by data from USGS
topographic maps, where necessary. No site visits or other field investigations
were made. Although to the extent possible, all existing and undeveloped pro~
jects were inventoried, only those projects with existing power generating faci-
lities or projects with a reasonable potential for development for hydropower
were retained in the NHS inventory. This inventory is permanently maintained in
a computer data base which includes descriptive information and the results of a
computer analysis of power potential and development costs for each project. In
all, the active inventory for Alaska includes 430 projects.
Tabulated Data
The purpose of this appendix is to provide a summary listing of selected
data on the 430 existing and potential hydropower projects which were included
in the NHS inventory (computer data base) for Alaska. In the following table,
projects are listed in alphabetical order by census division. A description of
the data included in the table precedes the tabulated information. However, a
few items warrant clarification:
(1) Up to four lines of information are presented for each project.
(2) Projects are separated by a space.
(3) As noted in the description of tabulated data. The third character of
the project indentification number describes the type and status of the project.
A description of each of the possible project status/types is shown in the
following matrix:
* STATUS * TYPE OF OPERATION *
* OF ******************************************************************
* WATERWAY *RUN OF* * * RES. WITH * IRRIGATION * *
* STRUCTURE *RIVER * DIVERSION * RESERVOIR * DIVERSION * CANAL * STORAGE*
********************************************************************************
* * * * * * * *
* EXISTING * A * B * c * D * E * F *
* * * * * * * *
* EXISTING * * * * * * *
* WITH POWER * G * H * I * J * K * L *
* * * * * * * *
* EXISTING * * * * * * *
* WITH RETIRED* M * N * 0 * p * Q * R *
* POWER PLANT * * * * * * *
* * * * * * * *
* BREACHED * s * T * u * v * w * X *
* * * * * * * *
* BREACHED * * * * * * *
* WITH RETIRED* y * z * 0 * 1 * 2 * 3 *
* POWER PLANT * * * * * * * * * * * * * * *
* UNDEVELOPED * 4 * 5 * 6 * 7 * 8 * 9 *
********************************************************************************
A-1
(4) Project costs shown were derived from computer application of genera-
lized cost estimating procedures and should not be construed to be represen-
tative of actual costs.
A-2
:»
I w
COLUMN LINE FORM ~
NO. NO. ITEM NO.
2 2
3 40
4 310
5 311
0 (318/3!1)
Summary Listing of Existing and Potential Projects, Alaska
Description of Tabulated Data
COLUMN
HEADING
SITE ID NUMBER
PROJECT NAME
PRlMARY COUNTY
INC~EMENTAL C~PACITY
INCREMENTAL ENERGY
INCREMENTAL COST
DESCRIPTION
UNIQUE tO-CHARACTER IDENTIFIER FOR lACH SITE.
CHI\RACTERS:
1-2
3
4-&
7•10
EXAMPLE: HlCPQH0003
VALUE:
HI : STATE CODE (POSTAL A~~R~VIATION)
C : TYPE AND STATUS CUD~ (R~FtA TO FOHN 2 ITEM DESCRIPTION
POH
0003
OOCU~ENTATION FUR ITEM B4). CODES A THRU R INDICATE
EXISTING P~OJECTS, S THRU 3 INDICATE BREACHED PROJECTS
AND 4 THRU q lNJICATE UNDEVELOPED PROJECTS FO~ VA~IOOS
TYPES OF OPtRAT!ON.
: U.S. ARMY CORPS OF ENGINEERS DISTRICT CODE (~EFER TO
FC~M 2 ITEM DESCRIPTION DOCUMENTATION FOR ITEM 33)
: ONIUUE SEQUENTIAL NUMBER wiTHIN EACH DISTRICT
IDENTIFICATION NAME OF EXISTING DAM OR POTENTIA~ wATER MANAGEMENT PROJECT
(NOTE: ONLY THE FIRST 29 CHARACTERS OF A POSSIHLE •O CHARACTERS ARE PRINTED).
PRIMARY COUNTY NAME IN wHICH THE PROJECT IS LOCATED.
AMOUNT OF INCREMENTAL POTENTIA~ CAPACITY liN K•J THAT IS ESTIMATED FON T~E
PROJECT.
AMOUNT Of INCREMENTAL POTENTIAL AVERAGE ANNUAL ENERGY (IN MWH) THAT IS ESTIMAT£0
FOR THE PROJECT.
COST (IN S/MWH) OF PRODUCING THE lNCREM[NTAL POTENTIAL E~ERGY FOR THE PROJECT.
COLUMN LINE FORM Z
NO. NO. ITEM NO.
7 1 b08
:r
-1'-
8 669
Description of Tabulated Data(contlnued)
EXPLANATION OF ENVIRONMENTAL AND SOCIAL IMPACT CODES: (COLUMNS 7 •·8)
COLUMN
HEADING
ALPHABETICAL CODES y, N, AND U ARE DEFINED AS FOLLOwS:
Y ::: VES
N : NO
U ::: UNKNOWN
NUMERICAL CODES l THROUGH 5 ARE DtFINED AS FOLLOWS:
1 : MAJOR ADVERSE
2 = MINOR ADVERSE
3 = INSIGNIFICANT
4 ::: MINOR FAVORABLE
5 ::: MAJOR FAVORABLE
DESCRIPTION
ENVRNMNTL IMPACT CODE SEVEN CHARACTER ENVIRONMENTAL IMPACT CODE IS DEFINED AS FOLLOWS:
CHARACTER
POSITION DESCRIPTION
1ST NATIONAL/STATE PA~KS AND WILDERNESS
2ND WILD AND SCENIC RIVER
3RD RESIDENT FISH
4TH ANAOROMOUS FISH
5TH WILDLIFE HASITAT
bTH ENDANGERED SPECIES
7TH WETLANDS
SOCIAL IMPACT CODE NINE CHARACTER SOCIAL IMPACT CODE IS DEFINED AS FOLLOWS:
CHARACTER
POSITION DESCRIPTION
1ST CULTURAL AND HISTORICAL RESOURCES
2ND COMMUNITIES RELOCATED
.3RO TkANSPORTATION RELOCATED
4TH FARMLAND
·5TH LOCAL GROUP COMMENT
bTH ENVIRONMENTAL GROUP COMMENT
7TH DTHE~ GROUP COMMENT
8TH UTILITY INTEREST
qTH STATE COMMENT
COLUMN LINE FORM 2
NO. NO. IT£M NO.
24 65
if
\Jl
COLUMN
HEADING
SITE IO NUMBER
OEP CODE
Description of Tabulated Data (continued)
OESCR lPTlON
UNIQUE lO·CHARACTER IDENTIFIER FOR EACH SITE.
EXAMPLE: ~HICPOH0003
CHARACTERs:
1•2
VALUE!
HI = STATE CODE lPOSTAL ABdRlVIATION}
3
4·6
7·10
C = TYPE AND STATuS CODE {REFER TO fOHM 2 ITEM OE~C~IPTION
POH
0003
DOCUME~TATION FUR ITEM HI). CODES A THNU R INDICATE
EXISTING PRUJtCTS, S THRU 3 INDICATE BRF.ACHEO PRUJtCTS
AND 4 THRU 9 INDICATE UNDEVELOPED P~OJECTj FO~ VAkiUUS
TYPES OF OPERATION, = U,S. ARMY CORPS OF ENGINE~RS DISTRICT CODE (REFER Tu
FORM 2 ITEM D~SCRIPTION DUCUMfNlATION FUR ITEM 33)
= UNIQUE SEQUENTIAL NUMBER ~ITHIN EACH DISTRICT
IDENTIFICATION OF UNDEVELOPED PROJECTS AS AN ALTERNATIVE TO SOME OTHER PROJECT
OR AS A PART Of SUM~ SYSTlM, THIS ITEM ALSO INDICATES ~HICH ONE OF THE POSSIBLE
ALTERNATIVE P~OJECTS SHOULD BE INCLUDED IN ESTIMATES OF TOTAL ~ATIONAL
POTENTIAL,
THE OEPENDENT/INOEPENOENT CODE IS DEFINED AS FOLLO~S:
! : INDEP~NDENT SITE.
E : DEPENDENT, ALTERNATIVE SITE, EXCLUDED FROM
SuMi~Ar<IlS.
S; DEPENDENT, PART OF A SYSTEM. THIS SITE SHOULD
BE INCLUDED IN SUMMARY TABLES,
0 = DEPENDENT, ALTERNATIVE SITES WHICH ARE CHOSEN
av DISTRICT FOR INCLUSIUN IN SUMMARY TAoLES.
COLUMN LINE FORM 2
NO. NO. ITEM NO.
28 3
:r
C)'\
3 53
2 2
2 2A. '10
2 26 3I
2 3 bO
2 q 1b0
3 3b
3 2 37
3 3 12b
COLUMN
HEADING
ACTV INV
PO,ER AREA
PROJtCT NAME
PRIMARY COUNTY
NAME OF STREAM
OWNER
MAP REFERENCE
LATITUDE
LONGITUDE
DR, AREA
Description of Tabulated Data(continued)
DESCRIPTION
ACTIVE IN INVENTORY COOE FO~ IDENTIFYING SITES BASED ON CAPACITY ANO BIC RATIOS,
(SEE FORM 2 ITEM DESCKIPTiuN DOCUMENTATION FOR DETAILED EXPLANATION Of COUES),
SOME OF THE MORE COMMUN ACTIVE IN INVENTORY CODES ARE AS FOLLU~S:
: SITES CONSIDERED INACTIVE FOR STUDY THAT HAVE A TOTAL
POTE~TIAL CAPACITY BETwEEN 50 KN AND IUO~ KW AND A B/C RATIO
GREATER THAN 1,0,
2 : SITES CONSID£~~0 ACTIVE FOR STUDY THAT HAVE A TOTAL POTENTIAL
CAPACITY G~EATER THAN OR EQUAL TO 1000 K~ ANO ~IC RATIO
GREATER THAN OR EQuAL TO 1,0 (NOTE: OTHE~ SITES CHOSEN BY
THE DISTRICTS CAN ALSO HAVt A CODE = 2 TO INDICATE ACTIVE
STATUS),
4 : SITES CllNSIDE~ED INACTIVE FOR STUDY WHERE THE TOTAL POTENTIAL
CAPACITY IS LESS THAN ~0 Kw uR THE 8/C RATIO IS LESS THAN
1. 0.
5 : SITE CONSIDERED INACTIVE FOR STUDY BECAUSE ADVANCED ANALYSIS
SHUNED DEVELOPMENT OF THE SITE TO HE ECONOMICALLY OR
ENGINEERINGLY INFEASIBLE.
b : SITES C0NSID£Rt0 Ir~ACTlVt FOR STUDY BECAUSE THEY FAILED THE
SCREtNING ON ADVE~SE ENVIRONMENtAL, SOCIAL, AND/OR
INSTITUTIONAL IM~ACTS,
ELECTRIC ~ELIABILITY COUNCIL SUB-REGION (GEOGRAPHIC AREA FOR ALASKA),
IDENTIFICATION NAME OF tXISTING DAM 0~ POTENTIAL WATER MANAGEMENT PROJECT
(NOTE: ONLY ThE FI~ST 2q CHARACTERS OF A POSSIBLE '10 CHARACTERS ARE PRINTED).
P~IMARY COUNTY NAME IN ~HICH THE PROJECT 15 LOCATED,
NAME OF STREAM ~HE~E Trl£ PROJtCT IS LOCATED.
IDENTIFICATION OF PROJECT O~NER.
NOTE: DAEN XXX R~PREStNTS U,S, ARMY CORPS OF ENGINEERS
WHERE XXX INDICATES THE DISTRICT CODE (REFER Tu FORM 2 ITEM
DESCRIPTION DOCUME~TAT!ON FO~ A LIST OF DISTRICT CODES AND
F~OEKAL AGENCIES),
IDENTIFICATION OF USGS MAP SHO~ING LOCATION OF SITES AND OTHER MAPS A.S NEEDED
FO~ IDENTIFICATION,
IDENTIFICATION OF PROJECT LOCATION BY LATITUDE
(DEGREES, MINUTES AND TENTHS UF MINUTES).
IDENTIFICATION OF PROJECT LOCATION ~y LONGITUDE
(DEGREES, MINUTES AND TENTHS OF MINUTES).
DRAINAGE AREA (IN SQUARE MILES) OF THE PROJECT.
;l>
I
"--
COLUMN LINE FORM i
NO. NO. ITEM NO.
4 &2
4 2 b3
4 3 128
s 61
s 2 88
s 3 11
b 300
b 2 310
b 3 290
1· 301
2 311
l 291
a 3lR
8 2 318/311
COLUMN
HEADING
PROJ, PURP.
STATUS
AVE. Q
DAM Hi
TOT. STOR
PWI<, HO.
EXIST, CAP,
INC. CAP,
TOT. CAP,
EXIST, ENRG,
INC. ENERGY
TOT, ENERGY
ANUL, COST
ENERGY COST
Description of Tabulated Data(continued)
DESCRIPTION
IOENTlFICAT!ON OF AUTKO~IZED PROJECT PURPOSES AS FOLLOWS:
I : INM!GATION
H = HYOMOELtCTNIC
C : FLOOD CONTROL
N : NAVIGATION
S :;; wATER SUPPLY
R : fiECREATION
0 : DEoRIS CONTROL
P :;; fHIM POND
0 :;; OTHEI<
INDICATION OF PROJECT STATUS AS FOLLOWS:
IS :;; IDtNT!FIEU SITE
SP = STUDY PROPOSED
SA : AUTHORIZED FOR STUDt
F~ : FEASIBILITY STUDY IN PROGRESS
SI : STUOY INACTIVe
AVERAGE ANNUAL INFLOW liN CFS},
PA : PROJECT AUTHORIZED
OH : GDM IN PROGRESS
UC : UNDER CONSTRUCTION
OP : PROJECT IN OPERATION
NOTE: NEGATIVE VALUES INDICATE MACHINE DETERMINED VALUES BA5EU ON A
DRAINAGE A~EA RATIO OF THE PROJECT TO THE ~EPRtS~NTATIVE GAGE,
PHYSICAL HEIGHT (IN FEEl) Of OAM ABOVE THE STHEAMBED,
CUMULATIVE STORAGE (IN ACKE-FEETI AT TOP OF FLOUD CONrRoL POOL. IF ITEM 8S WAS
NOT SUPPLIED, THEN THE STORAGE VALUt wAS TRANSFERRED FROM ITEM 10~, MAXIMUM
STORAGE (IN ACRE•FEET).
WEIGHTED NET POWER HEAO IF DETERMINED BY PROGRAM:
(ITEM 111 If COMPUTED BY FLOw-DURATION PROCEDURE OR TRANSFERRED FROM
NORMAL NET PO~ER HlAD liTEM 105),
AMOUNT OF EXISTING CAPACITY (IN KW) FOR THE P~OJECT.
AMOUNT OF INCREMENTAL CAPACITY (IN ~W) THAT IS ESTIMATED FOR THE PROJECT.
AMOUNT OF TOTAL CAPACITY (!N ~WJ THAT IS ESTIMATED FOR THE PROJECT (EXISTING
PLUS INCREMENTAL),
AMOUNT OF EXISTING ENERGY (IN MWH) FOR THE PROJ~CT,
AMOUNT OF INCREMENTAL AVERAGE ANNUAL ENERGY (lN M~H) THAT IS ESTIMATED fON THE
PROJECT.
AMOUNT OF TOTAL ENERGY (IN M~H) THAT IS ESTIMATED FUR THE PROJECT (EXISTING P~US
I~CREMENTALJ.
TOTAl ANNUAL COST {IN 1000 $} OF PRODUCING THE lNCReHE~TAL POTENTIAL AVERAGE
ANNUAL E~ERGY THAT IS ESIIHATED FUR THE PROJECT.
COST II~ liMN~} OF PfiODuCIN~ THE INCREMENTAL POTENTIAL ENERGY THAT IS ESTIMATED
FOR THE PROJECT.
COLUMN LINE FOR~ Z
NO. NO. ItEM NO.
7 o&B
:r
00
8 bb"'
Description of Tabulated Data(continued)
EXPLANATION OF ENVIRONMENTAL ANO SOCIAL IMPACT CODES: (COLUMNS 7 • 8)
COLUMN
HEADING
A~PHABETICAL CODES Y, N, AND U ARE OEFINEO AS FOLLOWS:
Y : YES
N :: NO
U : UNKNOWN
NUMERICA~ CODES 1 THROUGH 5 ARE U~FINED AS FOLLOWS:
1 : MAJOR ADVERSE
2 :: MINOR ADVERSE
3 : INSIGNIFICANT
4 = MINOR FAVORABLE
5 : MAJOR FAVORABLE
DESCRIPTION
ENVRNMNTL IMPACT CODE SEVEN CHARACTER ENVIRONMENTAl,.. IMPACt CODE IS DEFINED AS FOLLOWS:
SOCIAL IMPACT COOE
CHARAClER
POSITION DESCRIPTION
1ST NATlONAL/STATE PARKS AND WILDERNESS
2NO WILD AND SCENIC RIVER
3RO RtSlOENT FISH
4TH ANAORUMOUS FISH
5TH WILOLlFE HABITAT
bTH ENDANGERED SPECIES
7TH W~TLANOS
NINE CHARACTER SOCIAL IMPACT CODE IS DEFINED AS FOLLOWS:
CHARACTER
POSITION DESCRIPTION
1ST CULTURAL AND HISTORICAL RESOURCES
2ND CUMMUNITitS RELOCATED
3RO TRANSPORTATION riELOCATED
4TH FARMLAND
5TH LOCAL GROUP COMMENT
bTH ENVIRONMENTAL GROUP COMMENT
7TH OTHER GHOUP COMMENT
8TH UTILITY INTEREST
9TH STATE COMMENT
~
1.0
Summary Listing of Existing and Potential
Hydropower Projects, Alaska
Project Listing
*****************************************••••*******************************************************•***************************** * SlTE IO * PROJECT NAME * LATITUDE •PROJ,PURP,• DAM HT * EXIST,CAP, •EXIST.ENRG•ANUL, COST * ENVIRONMENTAL *
* * PRIMARY CO. •NAME OF STREAM •LONGITUDE • STATUS •TOJ, &TOR• INC. CAP, *INC,ENtR~Y•ENEHGY COST• IMPACT CODE *
* OEP ACTV * OnNE.R * OR,M<EA * AVE, (J •P,..R, hD, * TOT, CI<P, •TOl.UH:.RGY• * *
• C0i)E. ;NV * MAP REFERENCE * (0 M,M) * * (FTl • (KW) * (Mt.rl) • (!OOu $} * *
* * • (0 ~i.M) • • (AC FT) • (Kw) * (M••M) • ($/MiiH) • SOCIAL
• GEOG, AREA • * (S!.l,MI) * (CFS) * (FT} • (Kw) • (Mi'IH) * * IMPACT CODE. *
•••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••• * AI\71;PA0\101 • EAGLE RIVER * bl 17 ,q • H • 125,0 * 0 * 0 * «b7<1,j * YNUUUUU *
* I S • ANCHORAGE EAGLE RIVER * 14<1 38,9 * IS • 0 • 15000 * 61000 * 7b.l:ic'1 * * * SO CENTRAL • UNDEVELOPED * 19'1 * 5'19,0• 16!>,8 • 13000 * olOOO * * UNNUUUUIJN *
* * AllCrlORAGE il•7, * • • * * • * *
* • * A~aNPAOG'i9 • ~HlTTIER TIDAL
* I 9 • A~CHGWAGE COOK INLET
* bO '1'1,7 * H
• 1~'1 9,5 * IS •
0• • SO CENTRA~ * U~OEVELOPEO
* • SEi'!A><D D•S,o,
•
• AK7NPAOOOS • ELlZA LAKE
* I '5 * INGOUN
• SO~T~EAST • UNOEVfLOPED
* * SIT~A A-1,
•
•
* * • • * 57 12,0 * H •
ELIZA CREEK * 13ij 19,9 * IS *
* b • 53,4•
•
* AKbNP~OOOb * HA3StLB0RG C~EEK * 57 36,9 • H
IS * I 5 • ANGOO~
• SOUTHEAST • U~OEVELOPED
* * SlT~A C•1,
* • AKbNPA0004 * J!M'S LAKE
• I 5 * ANGOON
• SOUT~EASY • U~J~VELOPED
• • SITKA C-1.
• ~~bNPA0007 " KATH~EEN CREEK
• l b * ANGOON
• SOUTHEAST • UNDEVELOPED
* * SITKA 0•3.
• AK7NPAOOD3 • LAKE FLORENCE
1 5 * AN~CON
• 50UT~EAST • U~OE~~LOPED
• SIT~A 0-3
* •
• AKbNPA2b10 • THAYER CREEl\
• I S • ANGOON
• SOUTHEAST • uN~EVELOPED
• • SIT~A C-2,
•
• '~7NPAv009 * A~u~A RIVER
* I S * 8AKkv~•N, S~
* ARCTIC • UNDEVELOPED
* • LOO~OUT ~IDGE
HASSELBORG CR• 134 18,0 *
• 83 •
* • *
• 57 33.9 *
JIM'S CREEK • 134 1B,'i *
* 1 <! *
*
* * 57 5b,O *
KATHLEEN CREE• 1)« 42,9 *
• 29 *
• • 57 1.1/:1,1
FLORENCE CREE• 134 37.9 *
• 3'1
•
* • 57 3b,S •
THAYER CREEK * 13q 31,0 *
At~UNA RIVER
" "1 *
*
* * b9
• 1 so
• •
0.9 •
1,9 •
bO':i
*
H
IS
H
IS
H
IS
473,0•
*
* 170,0•
•
*
* 17~.0•
270,0•
• •
H *
IS
H
IS
3'18.0•
*
3!7.0•
•
75,0 •
0 *
22.0 •
•
20.0 *
0 •
209,7 •
311(},0 *
() .
30'5,6 *
• s.o •
0 •
184,8 "
•
30.0 •
~8000 •
::001,4 *
•
25.0 •
0 *
10'1,8 *
•
* 3'10.0 •
H!OOOO •
37b.b •
200.0 •
0 *
52!l,O *
*
• 0 •
0 •
0 •
• •
0 •
1700 •
1700 •
* •
0 •
toOOO •
16000 •
* •
0 •
5000 •
5000 •
•
0 *
10000 •
10000 •
0 •
4000 *
4000 •
• •
0 •
16000 *
1b000 •
0 *
21000 •
21000 •
•
* 0 •
0 •
(; .
•
0 *
746'5 •
7465 •
• •
0 •
77000 *
77VOO *
• •
0 •
205'50 •
2055\l *
• • u •
48000 *
480\lU *
• •
0 •
19000 •
1900\l •
* • a •
7800U *
78000 •
•
<.) •
101000 *
1UlU0U *
0
0 •
*
* •
8'13,52 •
11'1.b'l *
•
*
11040
l'l.5.38
1382.7
b7,2!S4
197'1.0
«1.125
23c3.7
122.30
•
* •
*
* •
* •
•
* •
*
*
*
*
*
* •
1>057,4 *
77.b59 •
15912
157,54
*
*
•
*
NI<UUUUU
UIIINUUUUNU
YNUUUUU
UNNUUUUUU
YNUUUUU
UNNUUUUUU
YI<UUUUU
UNNUUUUUU
YNUIJUUU
UNIIIUUUUUIJ
YNUUUUU
UN,.,UUUUUU
YNUUUUU
UNNUUUUYU
Y"'UUUUU
UNNUNUUNN
*
* •
*
* •
* •
*
*
*
* • • • •
* • •
* •
*
•
*
• • •
* •
*
* *
·························•***********************************-********************************************************************
:r ......
0
Project Listing( continued)
**********************************************************************************************************************************
* SITE 10 * PROJECT NAME *LATITUDE •PROJ.PURP.• DAM HT * EXIST.CAP. •EXIST.ENkG•ANUL. COST * ENVIRONMENTAL *
* * PRIMARY CO. •NAME OF STREAM •LONGITUDE * STAlUS •TOT. STOR• INC. CAP. •INC.E~ERGY•ENE~GY COST• IMPACT CODE *
* OEP A.CTII * O~NER * DR.AREA * AVE. l.l •PI-4R. HD. * TOT • CAP. •TOT .ENt:.RGY• * *
• CODE !NV * MAP REFERfNCE * (0 M.M) * * (FT) * (K") * (Mt<H) * (1000 S) * * * • * (D M.Ml * * (AC fT) " (Ki'O) * (M,..H) * (S/M>'IH) * SOCIAL *
" GEOG. UIEA * * (SO.I-11) * (CFS) * (I'T) * (KW) * (MI'IH) * * IMPACT CODE *
*•*•*•************************************************************************************************************•**********•****
* AKbNPA0010 * KILLIK ~END
* I o * 8A~ROw•N. SL
* ARCTIC * UNDEVELOPED
* * KILLIK "lV~R
* •
* AKbNPA0011 * ~UCHER CREEK
* I o • dARk0n•N. SL
* ARCTIC * 0NuEVELO~ED
* * KILLIK RIVER
* * * AKbNPA0008 * KUKPUK
* I 5 * ~~~~RON-N. SL * NOATH~EST • UNOEVELOPED
* POINT HOPE 8•2
* • KISlRIILl~ RIVER
• &7 3.0 •
COLVILLE WIVE• 153 52.0 *
* 9180 *
*
*
*
* * b8 54.9 *
COLVILLE RIVE• 155 45.0 *
* 1>240 *
*
* * * * b8 24.9 *
KUKPUK RIVER * 1b5 59.0 *
* 21 bO •
*
*
*
* * Al\bNPA0012
• I 2
* SOUTrt,..EST
* BElHlL KlSARALIK
* 60 2b.4 •
RIV• lbO 5.5 *
* UNOtVEl..OPED
* BETHEL B-3.
* • AKoNP40013 * ALAGNAK RIVER
* I 5 * BRISTOL BAY * SOUTHhfST * UNOEVEL.OPEO
* ll H~INA A•S.
* * * A~7NPA0014 • A~ERICAN CREEK
* I 5 * ~RISTOL BAY
* SOUTH~EST • UNDEVELOPED
* * MT. KATMAI 0•4.
* * • AKE>NPA0015 * BECHAAOF
• I 5 • UAISfOL BAY
* SOUTH~EST * UNOEVELO~EO
* * NA~NEK A•3
* * * 4KHNP42b01 * CHIGNIK
• I 4 * BRISTOL BAY
* 544 *
*
* * 59
ALAGNAK RIVER• 151>
*
*
*
*
*
1.1 *
3.0 *
530 *
* * * sa 54. o •
AMERICAN CREE• 155 13.9 *
* 100 *
* *
*
* * 58 9.0 *
EGGEGIK RIVER• 15b 118.0 '*
* 1280 *
*
* * * Sb lt>.'l *
INDIAN CREEK * 158 24.8 *
* SO CENTRAL * ALASKA PKRS. ASSI'I. * 2 *
* * CHIGNIK 8•2
* * ~ AK7~PA001b * CHIKUMINUK
* l 5 * 8R!S10L BAY * SOUTH~EST • UNDEVELOPED
* * TAYLOR MTNS.
ALLEN RIVEH
*
*
*
* • bO 1o.o •
* 158 2b.O *
* 2BE> *
* *
H *
IS *
5b58.0•
* *
H *
IS *
3588.0•
*
*
H *
IS •
1590.0•
*
*
H *
ID
800.0•
*
*
H *
IS •
H
IS
2100.0•
* *
*
* 248.0•
*
*
H *
IS *
HS
OP
2208.0•
*
*
* * 22.0•
* *
H *
IS *
1tOil.O•
*
225.0 *
0 *
217.7 •
*
* 130.0 *
0 *
11'1.8 *
*
* 110.0 *
0 *
99.'1 *
*
* 315.0 *
716000 *
2bll.7 *
* •
210.0 *
3b3000 *
1b9.8 *
* •
135.0 *
19511 *
8b0.1 *
*
* so.o •
0 *
57.9 *
*
* s.o *
0 *
400.0 *
* * 1t.l.O *
0 *
2b1.7 •
•
0 *
148000 *
148000 *
*
*
0 *
53000 *
53000 *
* *
0 *
24000 *
211000 *
*
*
0 *
30000 *
30000 *
* *
0 *
16200 *
1&200 *
* *
0 *
2!:>000 *
25000 *
*
*
0 *
1&000 *
toOOO •
*
*
50 *
0 *
50 *
*
* 0 *
32000 *
32000 *
*
0 *
718000 *
718000 *
* *
0 *
254000 "
254000 *
* *
0 *
105850 *
105850 *
*
*
0 *
13100t.l *
131v00 *
*
0 *
79700 *
79700 *
*
*
0 *
120000 •
120000 *
*
*
0 *
7b000 *
7b000 *
*
* 1138000 *
0 ..
438000 *
* * 0 *
154000 *
154000 *
*
208b8
29. oil
17756
b9.90b
9208.8
11&.998
7431.4
56.728
S6'lb.3
73.9ij1
3279.2
27.327
35799
471. 4
0
0
d'l77.t
58.293
*
*
*
* *
" * *
* * *
*
* * * •
* *
* *
*
*
* •
*
* * *
* *
*
* •
*
*
* * *
*
*
* *
* *
NYUUUUU
UNNUNUUNN
YNUUUUU
UNNUNuUNN
NNUUUUU
UNNUUUUI'IU
YYUUUUU
UNNUUUUOU
NYUUUUU
UNNUUUUNN
YNUUOUU
UNNUUUUNN
YNUUUUU
UNNUUUONN
NNUUUUU
UNNUUUUUU
NNUUUUU
UNNUUUUUU
* * *
*
* •
*
* * •
*
*
*
*
* • •
*
*
* *
*
*
*
*
*
*
*
"' *
"' *
* • ..
* *
* * • ..
*
* ********•************•*****************************************************************************************************•******
•
~
I ...... .....
Project listlng(continued)
*********************•*******•****************************************************************************************************
* SITE 10 * PkOJECT NAME * LATITUDE •PROJ.PURP.• DAM HT * EXIST.CAP. •EXIST.E~HG•A~UL. CUST * ENVIRONMENTAL *
* *PRIMARY CO. •NAME OF STREAM •LONGifUOE • STaTUS •TOT. STOR* INC. CAP. •lNC.ENtRGY•ENERGY COST• IMPACT CUDt
* OEP 4CTV * OWNER • UR.AREA * AVE. Q •P~R. HO. * TOT. CAP. •TOT.ENt~GY• *
* CODE INV * MAP RI:.F!::RENCE * (D M.Ml * • (FTl * (KVI) • (t41'/rll * (I 000 :S)
* * • (0 M.t-<) * • (AC FT) • (1\W) * (M.-.rl) * (l>/MWH) *
* GEOG. Af.IEA * • (SQ.~U) * (CFS) • (ft) • (1\.-1) * (Mnrl) *
SOCIAL
IMPACT COOE
*
*
*****************Y**********•**************************************************•*•*************~**********************************
• AK7c;PA00!7 • CONTaCT Cf<I:EI\ * :08 12.0 * H * 20.0 • 0 • U * !3c!bo 7 • YNUUUUU *
* I '5 • BRISTOL SAY CONTACT CREEK• 155 S7.'l * IS • 0 • 5000 * 23000 * '57.b84 * *
* SOUTHIIEST • urWEVELOPEO * 54 • 127 .O• 273.7 * 5000 * 23vOO * * UNNUUUUNN *
* MT KATMAI A•b • * * * * * * * • * * * * AK7NPA0018 • GRANT LAKE • S9 45.'l • H
• I 2 • BRISTOL dAY WOOD RIVER • 158 32.0 • IS •
• SOUTHNEST • UNDEVELOPED 37 * 9b.O•
• DlLL!NGnAH D-7,0•6 * * * •
• AK7NPA0019 • GROSVENO~ LAKE
* I 5 • ~RlSTUL 8AY
• SDUTH~EST * UNDEVELOPED
• 58 110.0
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* 630 *
•
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• MT KATMAI C-3,C•4,C•'5 * • * AKbNPA0020 • INGERSOL
• I 5 • BRISTOL BAY
* SOUTHwEST • U~OEVELOPED
•
• J.I\7NPAG021
* I '5
• SOUTH..,EST
• LA~E C~ARK B-3.
* KAKHONAK LAKE
• BRISTOL BAY
* 'UNDEVELOPED
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• A~7NPA0022 • KONTNASHIBUNA
* I 5 • bR!SIOL ijAY
* SOUTHNE~T * UNDEVELOPED
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* • * A~7NPA0023 * KUKII\LEK
• I b • oRISTOL BAY
* SOUTH~EST * UNDEVELOPED
* ILlAMr.A A•7 •
• AKbNPJ.0021 • KULIK LAKE
* I 5 * ~RISfOL BAY * SOUTH~fST * UNDEVELOPED
* >IT. KHr-AI
* * AKbNPA0025 * KULIK LAKE
* 1 5 • bRISTOL bAY
• SJUT~~EST • UNDEVELOPED
* OILLlfiGHAI'I
• &0 28.0
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• 145 *
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* 200 • *
• S<l 18.'l •
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• 480 •
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* !55 7.0 *
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Project Listing(continued}
*******************~***********************W*************************************************•*****************************•******
SITE IO * PROJ~CT NAM~ • LATITUDE •PROJ.PURP.• DAM HT * EXIST.CAP. •EXIST.tNHG•ANUL. COST • ENVIRONMENTAL •
• * OEP
• CODE
• PRIMARY CU. •NAME OF STREAM •LONGITUDE * STATUS •TOT. STOR• INC. CAP. •INC.ENERGY•ENEHGY ~OST• IMPACT CODE
ACTV • OwNER • OR.AMEA * AVE. a'•PnN. HO. • TOT. CAP. •TOT.ENERGY• *
lNV • MAP REFERENCE * (0 M.MJ * * (FTJ • (KW) * (M~H) * (1000 ~) •
* (D M.M) * * (AC FT) * (KW) * (MWH) * {$/M~H) *
* GEOG. AREA • * (SQ.Ml) * (CFS) * (FT) * (KW) * (MWH) * •
SOCIA~
IMPACT CODE
*
•
*******************************************•**************************•***********************************************************
• AK7NPA0155 • LAKE ELVA
* I 2 • B~lSTOL SAY ELVA CREEK
• 59 37.9 •
* 159 o.o *
* 10 * * SOUTHWE&T * UNDEVELOPED * • GOODNEwS SAY C•l * • *
* * * * AKbNPA0027
• I b * SOUTHI'IEST
*
*
* LAKE ILlAioiNA
• SiHSTOL BAY
* UNDEVELOPED
* ~ILLlNGHAM A•2.
* * AKbNPA0031 * NAKNEK * I 5 * BR!STUL BAY * SOUTHnEST * UNDEVELOPED
* NAKNEK C•2,
• * AK7NPA0028 • NE~HALEN
* I ~ * 8KISTOL ~AY
* SOUTH~EST * U~OEVELOPEO * • ILIAMNA O•bo
* * * AK7NPA0029 • NISHLIK LAKE
* 0 5 * BRISTOL BAY
• SOUTHriEST * UNDEIIELDPEO
* * TAYLOK MTN 6•8
* AK7JiiPA0031
• 1 5
* SOUTHwEST
•
*
* • NONVIANUK LAKE
* t>RISTOL tiAY
* UNDflifLOPEO
* ILIAMNA A•7
• * ~K7NPA0032 • TAZIMINA
* l 2 • BRISTOL BAY * SOUTHwEST • UNOEIIELOPEO
* * ILIAMNA 0·5,
* * * AK7NPA0030 * TIKCHIK
* 0 5 * BRISTOL dAY
* SOUTHWEST * UNDEVELOPED
* • DILLINGHAM 0•6.
* * AK7NPA0034
• I 5
* SOUTHNEST
•
* * UGASHII\ LAKE
* BiHSTUL BAY
* UNDEVELOPED
• UGASH:;I( C•3
• 59 13.0 •
KVlCHAK MINOR• 156 2&,0 *
* &440 * •
*
• • • 58 3&,9 •
NAKNEK RIVER * lSb 29,0 *
* 27 20 *
*
*
*
* * 59 t15.0 *
NE~HALEN RIVE• 154 49.9 *
• 331 'I •
*
* * * • bO 27,0 •
TIKCHIK RIVER• 158 51,0 *
* Ub *
*
* * * • 59 1. q *
NONUIANUK RI~• 155 37,8 *
* 370 *
*
*
*
* • 59 58,0 •
TAZlMINA RIVE• 154 33.0 *
320 •
• *
* •
• 59 So.o •
NUYAKUK RIVER• 158 11.9 *
1530 *
* •
• * * 57 3&.9 •
UGASHIK RIVER• 157 0,9 *
* 830 *
* *
• •
52.2•
•
*
H *
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201&7,0•
•
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73.9 *
*
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202,7 *
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114,6 *
* * 45,0 *
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160,0 *
* 35.0 "
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175,8 *
*
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0 *
32.11 *
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1000 *
1000 *
* *
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313000 *
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*•**********************************************************************'*********************************************************
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(.,.)
Project Listing(continued)
~································································································································· * SITE ID * PROJECT NAME * LATITUOE •PROJ,PURP,• DAM HT • EXIST.CAP, •EXIST.ENKG*ANUL. COST • ENVIRONMENTAL *
• *PRIMARY CO, -NAME uF STREAM •LONGITUDE • STATUS •TOT. STOR• INC, CAP. •lNC,ENE~GY•E~EKGY COST• IMPACT CODE
* DEP ACTV * O"'NER • OR,AREA * AVE, Q •PwR, HD. *lOT, CAP, •TOT,t.Nt:RGY• *
* COOE IIJV • MAP REFERENCE * (0 M,Ml • * (FT) • (!\I'll • (,'111M) * ll 000 Sl *
* * * (0 M,M) • * (AC Fl) • (KW) * (Mi<rl) * l.li/MtH1)
• GEOG. ARE4 • * (SQ,MIJ * (CFS} • (FT) • (Krl) • (Mi<H) *
SOCIAL
IMPACT CODE
•
•
·······-····························································•••***************************************************~······· • AI'.7NP401.135 • UKAI< • 58 2!!,0 * H • 7~.0 • 0 • I) * ~<8<1'1,2 * YNUUUUU
* 1 5 * fiRlSTOL flAY UKAK RIVER * 155 ~0.0 * 15 • 0 • E>OOO * 30U00 * lb1,b4 * *
• SOUTH,..EST • u>JDEVELOP£0 • !911 • 1155,0• 111~>11 • bOQO • 30000 * * UNNUUUUNU *
* • MT, KATMAI 6•4 * * • * * * * *
* • * AK7N?A0037 * UKAK RIVER • 58 30.9
* I 5 * B~ISTOL BAY UKAK RIVER • 155 19,9 •
• Su CENTRAL • UNDEVELOPED
• • MT KATMAI B-11
• • AK7NPA003o * UPNUK LAKE
* I S * BRISTOL oAY
• SOUTH~EST • UNDEVELOPED
• TAYLOR MTN 13•8
* AK&NPA00~2 • BREMNER RIVER
* I 5 * CO~DOVA-MCCA
* SQ CENfR4L • UNUEVELOPED
• • VALDEZ A•2,
• * AK&NPA00~3 * BREMNER RIVER
* I b • CORDUVA-MCCA
* SO CENT~AL • UNDEVELOPED
* • CORDOVA D-1
• • * AKbNPAOOIIII • BREMNER RIVER
* I 5 • CO~OUVA-MCCA
• SO CENTRAL • UNDEVELOPED
* * BERING GLACIER
* AK&NPA0045 • BREMNER RIVER
* I 5 • COROOVA•MCCA
• SO CENTRAL • UNDEvELOPED
• VALDEZ A-1.
• AK7NPA004b * CANYON C~EEK
• I 5 * CU~DUVA-MCCA
* SO CE~TRA~ • UNuEVELOPED
* * MCCARTHY A-~.
•
• 19'1
•
* • cO 18,9 •
TIKCHIK RIVER• 158 4b,2 *
• I 00 •
• • * •
LITTLE • cO 59,0 *
LITTLE BREMNE• 1114 8,9 •
182
• •
* SF • bO So. 0 *
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* I ~8
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* I & * SO CENTRAL
• CLEAVE (PENINSULA) • o1 4,9 •
RIVER * 1~~ ~8.9 •
* 21500
* CO~OOVA~MCCA COPPER
* UNOEVELUPED
* VALDEZ A•3,B-2,B-3, •
•
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•
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•
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•
•
*********•******••*************************************•********************************•**********************•******************
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Project Listing(continued)
*************************************************************-**************************************~************************-*• * SITE 10 * PHOJECT NAME *LATITUDE •PROJ,PURP.• DAM HT * EMIST.CAP. •EXIST.ENRG•ANUL. COST * ENVIRONMENTAL * * *PRIMARY CO. •NAME OF STREAM •LONGITUDE * STATUS •TOT. STOR• INC. CAP, *lNC.EN€kGY•ENERGY COST• IMPACT CQO€ *
* OEP ACTV * OWNER * DR.AREA * AVE. Q •PwR. HO. * TOT. CAP. •TOT ,ENERGY* * *
* CODE INV * "4AP REFERENCE * (0 M,M) * * HT) * tKW) * (M.-.H) * (1000 $) * *
* * * (0 M,M) * * (AC FT) * (Kw) * (M..,H) * 0./MWH) * SOCIAL *
* GEOG, AREA * * (S~.MI) * (CFS) * (FT) * (KW) * (MWH) * * IMPACT COOt. *
*****~****************************************************************************•~························~····················· * AK7NPA0033 * CHATER LAKE * bO :S'l. 7 * H * S.O * 0 * U • i!.7'1. 2 * NIHUUUU *
* I 5 * COROOVA•MCCA CRATER LAKE * 1ll5 40,8 * FP * 0 * 389 * t<I3S * 1'14,44 • *
* SO CENTRAL * U"'OEVELOPED • 0 * 2.0• 13118,t. * 369 * 1<~35 * * NNNUYUUNN *
* * CORDOVA C•5. * * * • * * * o.
* * * * • * * * • * AK7NPA0048 * HANAGTA LAKE * b1 27,U * H * 73,0 * 0 * 0 * 5269.3 • YNUUUUU * * t 5 * CORDOVA•MCCA HANAGTA RIVER• 11111 3,9 * IS * 0 * 33000 * 11>0000 * 33, 58 * *
* SU CENTRAL * UNDEVELOPED * 100 * 3111,0• 1008.9 * 33000 * lb0\100 * * UNNUUUUNU *
* * MCCARTHY A•8, • * * * * * * *
* • * * * * * * * * * AK7NPA002b * HUMPBACK CREEK * bO 37,8 * H * 5.0 * 0 * 0 * 1170.45 * YNUUUUU *
* I 5 * COkOOI/A•MCCA HUMPBACK CREE• 145 37.8 * FP * 0 * 1010 * 3291> * 1<12. 73 * t! * SO CENTRAL * UNOEVEUJPED * 2 * 25,0• 3<19,1> * 1010 * 3i!.9b * * UNNUUUNNN •
* * COtiOOVA C•5, * * * * * * * •
* * * * • * * * • • * AK7NPA0050 * KIAGNA RIVER * b1 2.2 * H * 510.0 * 0 * 0 * 1&251 * yr,:;;UUUU * * I 5 * CORDOIJA•MCCA KIAGNA RIVER * 1112 24.5 * IS * 0 * 110000 * 193QOU * 64.207 ll *
* SO CENTRAL * UNOEVELOPEU * 185 * 1>71>.0• 91>9,0 * 4UOOO * 193000 * * UNNUUUUUU *
* * MCCARTHY A•4. * * * * * * * 1r
* •. * * * * * * • • * AI<7NPA005t * KLUTINA * bl 32,9 * H * 98,0 * 0 * 0 * 7521>,5 * NNUYYUU * * I 5 * COROUVA•MCCA KLUTINA RlVER• 1115 27.9 * IS * 1>92000 * 54000 * 21>3000 * 28.&18 * *
* SO CENTRAL • UNDEVELOPED * 1>70 * 1311,0* 334.1> * 54000 * 2&3000 * * UNNUUUUYU *
* * V ALOE Z 0•5, * * * * * * * *
• * * AK7NPA0052 * KUSKULANA RIVER * I 5 * CORDUVA•MCCA KUSKULANA
* SO CENTRAL * UNDEVELOPED * * MCCARTHY C•8,
* * * 1>1 32.'1 *
RIV• 1113 56,9 *
* 2b0 "
* *
H
IS
*
*
* 759.0•
* 310.0 ..
0 *
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*
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24000 *
*
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114000 "
114000 *
*
7771.9
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*
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*
* * * * * * * * * * * AK&NPA0053 * \.OWE (KEYSTONE CAN) * b1 5,9 * H * 114(),0 * 0 * 0 * 9304,'1 * NNUYUUU •
* I b * CORDOVA-MCCA LOWE RIVER * 145 30.0 * IS * 2110000 * 55000 * 254000 * 3b,b31 * *
* SO CENTRAL * UNOEVELOPEO * 190 * 1'134,0• 323.1> * 55000 * 254000 * * UNNUYYUYU *
* * VALDEZ A•&,A-5. • * • • * * * *
• * * -. • * * * * * * AKbNPA0054 * MILLION DOLLAR • bO 110.0 * H * 110.0 * 0 * 0 * 52833 * NYUUUUU *
* l 5 * CQRODVA-MCCA COPPER RIVER * 144 44,0 * IS • 0 * 440000 * 1927000 * 27.417 * *
* SO CENTRAL * UNDEVELOPED * 24200 * 52489.0• 88,9 * 440000 * 1927000 * * UNNUUUUUU *
* * CORDOVA C-2,0•2. * • * * • * * •
* * * * * * * * * * * AK7NPA00'55 * NIZlNA * bl 23.1 * H * 340.0 * 0 * 0 * 15020 * YNUUUUU * * l ~ * COROOVA•MCC~ NIZINA RIVER * 143 13,9 * IS * 1 0 * 45000 * 199200 * 75.403 * * * SO CENTRAL * UNOEVELUPEO * 1420 * 3450,0• 329,& * 45000 • 1':19200 * * UNNUUUUUU •
* * MCCARTHY B·b * * * * • * * *
*****************•**~******************************************************************************S********•*******•***********A*
:r ......
I.Jl
Project Listing(continued)
********************************************************************************~*************************************************
* SITE IO * PROJECT NAME * LATITUDE *PIIOJ,PURP,• DAM HT * EX!ST.CAP. •EXIST.~NNG•ANUL, COST * ENVIRONMENTAL *
* • PRIMARY CO. -NAME OF STREAM *LONGITUDE * STATuS •lOT. STOR• INC, CAP. •lNC.ENtAGY•E~E~GY COST• IMPACT CODE *
* OEP ACTV • O"NER * DR,AIIEA • AVE, Q •PWR, HO, • TUI, CAP, •TOT,EN~Ro;.h • *
* CODE !NV * MAP REFERENCE * (0 M,M) * * (FT} * (KI'I) * (MWH) * (lOQO $) * *
* * * (0 M,M) * * (AC fT) * (KW) * (Mf!H) * (.'io/Mi'!H) * SOCIAL •
* GEOG, AREA * * (SQ,rH) * lCFSJ * (fTJ * (1\W) * (M..,H) * * IMPACT CODf *
··············~················································•***********************************•******************************
• AI\5NPA~v39 * PO,..E.R CRtfK I • b!J 35,1 * 11 • 25,0 • 0 * U * 2b1!7 ,0 * NNYY<,UN *
" 0 2 * COROOVA-~lCCA POWER CREEK * 145 32.4 " SP • 0 * 5000 * 26000 * 103,34 * *
* SO CENTRAL * uNDEvELOP£0 • 21 * 251,0• 359,6 • 50\iO • 2oU00 • * NNNNYI'<UYY *
• • CO'<DOVA c .. s. * * * * * • * • * • * • lK7NPA0040 * POWE~ CREEK 2 * 60 36,9 H *
• E 5 • CO~DOVA•MCCA POWER CkEEK • !45 3!,4.
1!:1 •
SP •
• SO CENTRAL * U~DE~ELOPED
• CURJui/A C-5,
* * AK7NPAOOS7 * POhfK C~EEK
* I 5 * CORDOVA•MCCA
• SO CENTRAL • UNDEVELOPED
* * CORDOVA C-5 • • * AK7NPAOC58 % TEBAV LAKE
* l 5 * CUHOOVA•MCCA
* ~U CENTRAL • U~OoVELOP£0
* VALD~Z A•1 1 1•2,
* *
PO.vER CREEK
TEBAY RIVER
*
"
*
* • bO 35,9 •
" 145 30.9 •
* 19 •
•
* •
• bl 26.0 •
• 144 1!,9 *
105 *
*
*
• •
160,0•
•
H
FP *
H
IS
283,0•
* •
*
* 331,0•
*
* * AKbNPA0059 * THrlEE MILE CANYON * 60 59.0 *
RIVERo 144 10,0 •
52o •
H * 1 5 • CONDUVA-MCCA R~EMNER IS *
* SO CENTiiAL * UliiJEiiELDPEO
* • COrlOUVA 0-1
* • AKbNPAOObv • TIEKEL ~IV~R
• I 5 • Co~DOVA•HCCA
• SO CENTRAL • UNOEVELUPEU
* * VALDEZ A-3,
* AK7NPAC002 * TONSINA
* l 5 * COHUGVA•MCCA
* SO CE~T~AL * JNDEVELOPED
• VALDEZ C•4,
• AK6NPA Obi • TSINA
* I 5 • CUNDDVA•MCCA
• SO CENT~AL • UNJE~ELOPEO
* • VALDEZ a-c.
* * AK7NPA0062 * VA~ CLEVt
• l 5 * CORDOV~·HCCA
• SO CENT~AL * U~DEvELO?ED
• C01'(00VA C•l
* •
*
2291,0•
*
" * &1 !4,7 • H *
TIEKEL RIVER ~ 144 57,6 • IS •
421 * 830.0•
• • * &I 30,0
TO~SINA RIVER• 145 30.0 *
<:55
T::iiNA
UNNAMED
* * • • bl 9,(} •
• 145 30.9 *
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~
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Project Listing(continued)
********************************************************************************************************************************** * SITE 10 • PHOJECT N4ME *LATITUDE •PROJ,PURP.• DAM HT • EX!ST,CAP, •EXlSI,ENHG•ANUL, CUST * ENVIRONMENTAL *
* * PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •TOT, STOR• INC, CAP, •INC,ENERGY•ENERGY COST• IMPACT COO£ *
* OEP ACTV * Or.NER * OR,AREA * AVE. Q •PI'IR, HD. * TOT, CAP, •TOT ,ENERGY• * *
* CvDE INV • MAP REFEckENCE * (0 M,M) * * (fT) * (K>'I) * (~1NH) * {1000 $) * *
* * * (0 M,M) * * (AC FT) • (KI'>) * (M,..H) * (.$/MwH) * SOCIAL * * GEOG, AREA • * (SQ,IU) * (CFS) • (~T) * (KI'I) * (MII'H) • * lMP4CT CODE *
····~······································································~······················-··········••••***************** * AK7NPA00b3 * ~HlTE RIVE~ * bO 4,8 * H * 5,0 • 0 * 0 * 1338,3 * NNUUUUU *
* I 5 * COROOVA•MCCA WHITE RIVER * 142 9,9 * IS * 0 * 2172 • 15791 * B4,753 • *
• SO CENTRAL * UNOEVELOP£u * 29 * 290.0• 281.7 * 2172 * 15791 * * UNNUYYYNY *
• * t\E>Ht>G GLACIER A-4. • * * * * * * *
* • * AKbNPAaCb4 * 1'1000 CANYON
• I b * COROOVA•MCCA
• SO CENTRAL * u~uEVELuPED
* * VALDEZ o•2,
* • * AK7NPA0065 * YOUNG CREEK
* I 5 * CO~DUVA•MCCA
• SO CENTRAL * UNDEVELOPED
* MCCAI<THY A•4.
* * CHATA~IKA RIVER
* * * b1 25,0 *
COPPER RIVER * 144 19,9 *
• 20!>00 •
YOUNG CREEK
*
*
•
* * b1 12,2 •
* lil2 23.9 •
• 40 *
*
*
* * * AKo~lPA006b
• 1 6
* YUKON
* FAIRtiAHK~ CHATANlKA
* 1:>5 2.0 *
RIV• 148 31,0 *
• UNDEVELOPED
* * LIV~NGOOO A•4,
* * * AKbNPA00b7 * CHENA RIVER
• 77 0 *
* *
* * • bil 54,0 *
* I 5 * YUKON
* FAik~ANKS CHENA RIVER * 14b 22,0 * * uNDEVELOPED * 950 *
* * BIG PELlA 0•5, * *
* • * ...
* AK6NPA00b9 * TANANA NIVER (LITTLE DELTA) * b4 30,0 •
";. 146 45,0 •
* 18080 *
• 0 b • FAIRBANKS TANAN RIVER
* YUKON * UNDEVELOPED * *BIG DELTA 8•6,
• * AKbNPA0072 * CHILKAT
* I 5 * HAINES OlV * SOUTHEAST • UNJEVELOPED
*
*
* SKAG>.AY C•3.
* * AK6NPA0071 * CH!LKOOT
• 1 5 * HAINES OIV
* SOUTHEAST • UNDEVELOPED
* * SKA~wAY 8·2,
* *
*
*
• ..
* 59 38,0 •
CHILKAT RIVER• 135 56,0 *
* 190 •
•
*
*
* * 59 19. 'I *
CHILKOTT RIVE• 135 32,0 *
• 130 *
* *
* •
* * H * 1000,0 *
IS •14500000 •
3t>880,0• 949.0 *
*
*
H *
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152,0•
*
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*
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*
*
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• •
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1076.0•
*
*
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*
* 105.0 *
4110000 *
90,9 *
* •
110.0 *
270000 ..
10o,a •
•
* 140,0 *
0 *
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* 410.0 •
0 *
319.b *
*
* 180,0 *
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• * 0 * 0 •
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*
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*
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* •
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*
* * AKINPA0098 * ANNEX * 58 19.5 * H * 25.0 * 3500 * bOOO * 171,52 * NNUUUUU *
• I 2 * JU~IEAU ANNEX CREEK * 134 7.6 w OP * 23400 • 1750 * 3vOO w 57,176 • *
• SOUTHEAST * ALASKA ELEC LGT ANU PWR * o * •63,4• 755,0 * S250 * 9000 * * UNNUUUUUU *
• * JUNEAU 6•1 * * * * * * * *
*******a**********************•******************************************************************************************•********
:r
1-'
-...J
Project Listing(continued)
*********************************************************************************•************************************************ * SITE ID • PROJECT NAME * LATITUDE •PRQJ,PURP,• OAM HT * tXIST,CAP. •EXIST.(NRG•ANUL. COST * ENVIRONMENTAL *
• PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •TOT, STOR• INC, CAP, •INC,tNERGY•£NEMGY CGST* IMPACT CODE
• DEP
* CODE
•
ACTV • O~Nl~ * OR,AREA * AVE, 0 •PWR, HD, *TOT, CAP, •TOT.~NERGY•
INV * MAP REFERENCE • (D M,M) * * (fT) • (K~) * (MwH) * (1000 $) * (0 M.M) * * (AC FT) • (K~) * (M~H) * (./MNH)
• GEOI.i, ARE4 • * (SU,Mil • (CFS) • (FT) • (KW) * (MNH)
• •
SOCIAL
IMPACT CUD£
..
*
*
* ······~···~············································································••***************************************** * AK7NPA0090 • BEAR CREEK • S8 3,9 • H • 10,0 * 0 • U • l5b7,7 * NNUUuUU * * I 5 • JUNEAU BEAR CREEK • 134 0,0 • IS • 0 • 18000 • 44000 • 3S,b29 * *
* SOUTHEAST * UNDEVELOPED • 3 • 25,0• 849,1 • 11000 a 44UOU * * UNNUYYYYY *
* JUNEAU A•1, • * * * * *
* AK71H'A00'l1
• I 5
it SOUTHEAST
*
• BOUNDARY LAKE
* J!Jii[AU
* UNDE\IELUPEO
* TA~U RIV~R C-b,
• • AK7~PADU92 • CARLSON CREEK
• r s • J u :' £: A"
* SOUTHEAST • UNDEVELO~EO
• JUIH:.AU tl•1,
* • AK7~PA2b04 • COnEE CREEK
• I S • JIJ.~EAU
• SOUTHEAST • UNDEVELOPED
* JlHHiAU C•3.
• A<7NPA035o • CRAT(g LAKE
* C 2 • Ju.~EAU
• SOUTHEAST ~ UNDEVELOPEO
• TA!<;J A•b.
* A!';7NP42&01
• l b
• SOUTHEAST
•
* AK 'INP.:.2o08
• I 5
* SOUTHEAST
*
* OAVIDSUN CREEK
* JUNEAU
• Ul<utvSLOPEi.J
* TAKU RIVtR B-6,
• OA\IIE5 CREEK
* JUNE~<U
* UNLiEV£L0PEO
• J<.H<EAU C•3,
* • AKbNPA0093 • ENDICOTT RIVER
• I 5 • J~~EAU
• SOUTHEAST • UNDEVELOPED .. • Ju~-~EAu o-s.
•
• 58 34.'l
BGUNDARY CREE• 133 40.0 *
* 23 * • • *
* * 58 5.9
CARLSON CREEK• 134 !7,0 •
• 24
• •
• 58 38.0
CUWEE CREEK • 134 54,2 *
• 7
• • * •
• 58 e.o
CRATER CREEK • 133 45.7 *
12 *
* •
• 58 21.3
DAVIDSON CREE• 133 <~U.S *
* 30 •
• * 58 38,'1
DAVIES CREEK • !31.1 5'1,2 *
• 1/:l
•
• 58 47,1.1
ENDICOTT RIVE• 135 27,9 •
5& *
• * AKHNPA0099 • GOLD CRE~K 5 * 58 17,9
* I 2 • JUNEAU GOLD CREEK • 1311 23.9 *
* SOUTHEAST • ALASKA ELECTRIC LIGHT & POWE• 10 *
* • JUNEAU 8·2 • *
H
IS
H
* 235.0•
*
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339,0•
•
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0 •
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················••*•***********************•***********************************************************~**********~**************•
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Project Llsting(continued)
***************************************************************************************************************•******************
• SITE ID * PROJECT NAME * LATITUUE •PRUJ.PURP,o DIM HT * EXlST,CIP, •tXIST.tNWG•ANUL. CUST * ENVIRONMENTAL * * * PRIMARY CO. -NAME OF STREAM •LONGITUDE * ST.I.TUS • •TtlT, ~>TOR• INC, CAP, •INC.ENENbY.ENERGY CO~h IMPACT CuOt •
* DEP ACTV • O"NER * I)R,ANEA * AVE. Y •P,R, Hll, * TOT. CAP, •TOT ,Etv!:.RGY• * • * CODE INV * MAP REFERENCE * (0 M,M) * • (fT) • (KWJ • (l1i«H) • (1000 $) • 111
* • * (0 M,M) * * (AC FTJ * (KW) * (Mi\'H) * ($/M!'fH) * SOCIAL * * GEOG, AREA * * (SO, Mil * (CFSJ * (F T) * (Kil') * (Mr. H) * * IMPACT CODE *
**********************************************************************•*********************************************************** * AK6NPA0095 * LACE RIVER
* I 5 * JUNEAU
• SOUTHEAST * UNDEVELOPED
* * JUN~AU 0•3,
* • * kK5NPA009b * LAKE DOROTHY
* I 2 • JUNEAU
• SOUTHEAST * UNDEVELOPED
* * TA~U RIVER A•&.
• • AK7NPA0073 * LEMON CREEK
* I 5 * JU~EAU
• SOUTHEAST * UNU~WELOPEO * JU~EAU B-2
• • * AKI>NPA0075 o NUGGET C~EEK
* I 5 * JUNEAU
• SOUTHEAST * U~vEVELOPED
* o JUNEAU 8•2
* AKUvPA007b
• I 5 * SOUTHEAST
•
* * PETERSON LAKE * J llr1£ AU * UiltuEVELOPED
* JUNEAU 8•3
• * AK7NPA0077 * RHINE CREEK
o I 5 * JUNEAU
• SOUTHEAST * UNDEVELOPED
* * JUNEAU A•1
* *
LACE RIVER
• 58 '.:i7.o • * 134 57.9 *
* 393 *
* *
* • * 58 14.0 *
DOROTHY CREEK• 134 3.0 *
LEMON CREEK
* 11 *
* *
*
* * 58 20.9 *
* 134 30,0 * * 25 • •
* * • 58 25,0 *
NUGGET CREEK * 134 30.9 *
16
* * * * 58 2b.6 *
PETERSON LAKE• 134 44.0 o
* b *
*
* * • 58 13.4 *
RHINE CREEK~ * 134 10,8 *
* * *
" * •
o AKINPA0101 • SALMON CREEK NO 2 • 58 17.9 •
* I 5 * JUI'•EAU UPPER SALMON * 134 23.9 *
• SOUTHEAST * AJINOUSTRIESINC
• * JUNEAU 8•2
• •
* 5 •
* *
*
* * AKJNPA0100 * SALMON
• I 4 • JUNEAU
* SOUTHEAST • ~~~ ELE
o * JUN~AU
CREEK NO 1 * 58 17,9 *
LOWER SALMON • 134 30,0 *
L T & Pl'iR CO * b *
8•2 • •
• * o AKbNPA0079 * SHEEP
* I 5 * JUNEAU
• SOUTHEAST * UNDEVELOPED * * JUNEAU 6-1.
SHEEP CREEK
• * * 58 15.0 * * 134 18.9 *
* 15 *
* *
H * IS o
H
IS
H
3174.0•
• • • •
112.0•
*
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280,0•
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51,0•
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165000 *
2347.1> •
• • 230.0 •
18000 *
239.7 *
•
120.0 •
0 •
b0b.3 •
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7100 •
61>9.3 *
*
* 22,0 •
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389,b *
*
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19000 *
b4o.o •
• •
167,0 •
19000 *
.590,0 *
* * 180.0 •
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b2000 *
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* * 0 •
34000 *
34000 •
*
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*
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* •
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5b00 *
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*
0 *
298000 *
2'18000 •
•
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150000 *
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* *
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*
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•
* 3000 •
0 •
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* •
0 *
26144 *
2b144 *
*
t72b4
57.934
221lb.3
15.2<12
3722.3
1!6.56b
15.5<!.7
51. 90
1278,5
47,379
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3'53,,28
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0
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2001.7
76,5b7
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* *******************************•******************************************************************************************•······-
~ ,....
"'
Project Listing (continued)
················•******************•******************************************************************************************'***
SITE I D PfiUJECT NAME
* PRIMARY CO. •NA~E OF
• OEP
* CODE
•
ACTV * O~NER
!NV • MAP REFERENCE
* GEOG. AREA •
* LAT!TUUE •PRUJ,PUfiP,• OAM HT * EXIST.CAP,
STREAM •LONGITUDE * STATUS •TOT, STOR• INC, CA~.
* O~.AREA * AVE, Q •PWR, HD, * TOT, CAP,
• (0 H,M) * * (FT) * (10'1)
* (0 M,M) * * (AC FT) • (KI'w) * ( S Q ,111) * ( C F S) * ( F T) • ( K l'w)
•tXIST,tNRG•ANUL. CUST •
*INC.ENERG'*ENEHGY COST•
•TOT,ENcRGY• *
(1.\ ... H) * (1000 $) *
(M,..H) * (~/M>'OH)
(M,..H) *
!:;IW lRUNMtNT AL
IMPACT CODE
:>OC IAL
IMPACT CODE
*
*
*
• •
*************************************************************************************************•*******************************• * a~7NPA0080 * ShERMAN CREEK • 58 51,9 • H • 10.0 * 0 * U * 852,81 * NNUUUUU *
*I 5 * JUi<EAtJ SHEI<MAN CREEK• 13~ 8,1 • lS * 0 • 1200 * 4880 * 92,707 *
* S;JUTHEAST * U\i!E~ELOPED * 4 * •18,8• 390,0 • 1200 * 8<!8ii * " UNNUUUUNU *
• JUi<EAU 0-4, * * * • * * *
• * • AK6~PA0081 * SLIDE * 58 0, 0 * H
* I & * JU~EAU SLIDE LAKE • 134 22.0 * IS •
• SOUTHEAST • UNOEVELO~ED
* JlJ,'<EAU A-2,
• 14 • 85.0•
* • • •
• AKJNPA0102 • SN[TTISHAM • 58 5,9 *
* I 2 • JU~EAU LONG LAKE • 133 48,0 *
* 30 • • SOUTHEAST • AK PUftEA ADMIN,
* * TAKU RIVER A-b
* •
• AK,NP&0082 • SPEEL DIVISION
• • * •
• 58 (:>,9 *
• I 2 • JUNEAU SPEEL RIVER • 133 42,9 •
• l'ltl • * SOUTHEAST • U~OEVELOPED
* • TA~U RIVE~ A•5,
• • • •
* • AK7NPA0083 • SwEETHEART FALLS * 57 5b,b
* l 2 • J IJNE AU * SOUTHEAST • U~O~VELOPED
• 5U>10UM 0•5
• * AK7NPA0084 * TEASE
S~EETHEART CR• 133 38,1 *
35 •
• • ..
• 1 2 * JUNEAU TEASE CREEK
* 58 5.9 • ~. 133 <10,2 "
• S0UTHEAST • UNUEVELO?EO • 11 •
* TAKU K[V~R A•S, • • • * AMMNPA008t> * TRE&DWtLL DITCH
• I 2 * JUNEAU TREADWELL
• 58 I 5, 5 •
Olio 134 22,3 •
13 • • SOUTHEAST • AK ELET LIGHT & POwER
* * JUNEAU B-2,A•2
• AK7~PA0087 • TU~NER LAKE
• I 5 * JUNEAU
• SJUTHEAST * UNDE~fLOPEO
• TAKU RlV£~ 8-b,
• •
• 58 18.7
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• 52
•
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•
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IS *
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-491>,9•
• AK7NPA0088 * UNNAMED LIKE NEAR LACE RIVER• 58 53,0 • h
* I 5 * JL'><EAU UNNAMED * l3t1 49.9 * IS * SOUTHEAST * U><uEVELOPED • 3 * 28.0•
* JUNEAU 0-3, * •
• 40,0 •
0 •
549.t.; *
*
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150(100 •
79'l.2 •
•
325.0 •
910000 •
272,7 •
* •
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•
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1032,9 •
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•
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•
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7000 •
7000 •
* 411 oO •
0 •
225609 •
•
0 •
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b3000 •
" •
0 •
29000 •
29000 •
•
0 •
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•
* 0 •
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• •
0 *
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0 *
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•
•
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31124 •
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• lb&:.oo ~
57109 •
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275000 •
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•
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• •
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•
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28, I b
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38,190
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29.428
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k***~~*******•***********•*********************************************······································-········•***********
> I
N
0
Project Listing(continued)
*****•****************************************************************************************************************************
* SITE 10 * PROJECT NAME *LATITUDE •PROJ.PURP.• DAM HT * E~IST.CAP. *EXIST.ENRG•ANUL. COST * ENVIRONMENTAL *
* * PRIMARY CO. •NAME OF STREAM •LONGilUDE * STATUS •TOT. STOR• INC. CAP. •JNC,ENERGY•ENENGY COST• IMPACT CODE *
• OEP ACTV * U~NER * DR.A~EA * AVE. Q •PwR. HD. *TOT. CAP, •TOT.cNERGY• • *
• CODE !NV • MAP REFERENCE * lD M.M) * * (fT) * (KN) * (MNH) * (1QOO $) * *
* • (0 M.M) * • (AC FT) • (KN) * (MWH) * (l/MNH) • SOCIAL *
* GEOG. AREA * * (SQ.Ml) * (CFS) * (FT) * (KW) * (MNH) * * IMPACT CODE *
*******************************•*****************************************************************************************•********
* AK7NPA0143 * UPPER ~NEETHEART * 57 59.7 * H * 35.0 * 0 * 0 * 131b.7 * NNUUUUU *
* I 2 • JUNEAU SwEETHEART CR• 133 30.6 • IS * 18000 * 7000 * 30bo0 * 42.945 • *
• SOUTHEAST * U~OEVELOPEO * 3 * 45.0• 1178.6 * 7000 * $0bcv * * UN~UUUUUU *
• SUMOUM 0·5 * * * * * * * * •
• AK7NPA0089 * YEn~JNG CREEK
* I 5 * Ju~EAU
• SOUTHEAST * UNDEV£~0PED * TA~U RIVER B•b.
• A~H,PA01C3 • BRAD~EY LAKE
• l 2 • KENAI-COOK I
• SO CENTRA~ • U~OEVELDPED
* •
• 58 27.0 •
YEHRING CREEK• 133 45.9 *
• lb •
• • *
* • * 59 45.0
BRADLEY CREEK• 150 ~1.0 •
8b •
* • bE~DUVIA 0•3,C•3. *
*
• • •
• AK7NPA010o * CHAKACHAMNA LAKE • 61 13.0 *
R• 152 22.0 * * I 2 * ~ENAI-COUK I CHAKACHAMNA * SO CENTRAL • UNDEVELOPED
• TYONEK A•7.
•
• A'7NPA0107 * CHUIThA
* I 5 * KENAl•COUK
• SO CeNTRA~ • UNJEV~LOPED
* • TYO~EK A-a
• • AK6NPA0108 • COFFEE
* I 2 * KENil•COUK I
• SO CE~TRAL * UNOEVE~OPED
• •
• TV()tlt:K A-a.
• AK7NPA0109 * CRESCENT LAKE
• l 5 * KENA!•COOK I
• 50 CENT~AL * UNOEVE~OPED
• Kf,',AI tl•8.
* AKoNPA0110 * FOX
• l 5 • ~~NAl•COOK I
• SJ CENTMAL • UNOEVELDPtD
* ~ELDU\IIA 0•3
*
• 112\1 •
•
*
* • * 61 4.9 *
CHUITNA RIVER• 151 !9.9 •
* 00 * •
* * * • bl 12.0 *
BELUGA RIVER *~151 10.0 *
* 860
*
* • 60 2!.9 *
LAKE FORK OF * 152 49.9 *
FOX RIVER
* 200
*
•
* * 59 58.'1 •
• !SO 48.0 *
105 •
• • • •
H
IS
H
PA
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*
* * 155.0•
* •
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•
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*
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545.0•
• •
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1028.9 *
*
* !20.0 •
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1\153.9 *
*
* s.o •
'101'5000 *
792.i!. *
" •
50.0 •
0 •
551.4 *
•
* 120.0 *
0 •
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*
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30b000 •
516.4 *
* •
320.0 •
0 •
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*
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0 •
94000 *
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*
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9000 * • •
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37000 *
*
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* * 0 *
25000 •
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•
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0 •
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•
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410000 •
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* •
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• •
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* g •
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•
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* * 0 •
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lll.l.l\l8
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52.80'5
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* * •
*
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* * *
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* • •
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* * *
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•
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* * *
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* * *
*
• AKbNPAOlll * HALIBUT * 59 35.1 * H * 175.0 * 0 * 0 * 1bOO.o * YNUUUUU * * I 5 * KENAl•COUK I HALIBUT * 151 9,5 * IS * 0 • 12000 * 50b31 * 31.614 • *
• SO CENTRAL * UNDEVELOPED * 23 * 130.0• 584,4 * 12000 * 50b31 * • UYNYUUUUU *
• * SELDOVIA C•1 * * • * * * * *
~•••**X*********************************************************************************************************************•*****
Project Listing(continued)
•****************************************************************•****************************************************************
* SITE ID • PROJECT NAME • LATITUU~ •PROJ,PURP,• OM! HT • EXIST,CAP, •EXJST,tNRG•ANUL, COST • ENV IRUNMENTAL •
• PRIMARY CO, -NAMt OF STREAM •LONGITUDE • STATUS .. rur. STOih INC • CAP, •INC,ENtNGY•ENERGY COST• IMPACT CUDt
* DEP ACTV • Or'INER • OR,AREA • AVE. a •Pwfl • HD, * TOT, CAP, •TOT,£NtRt,Y• • •
• CODE INY . MAP REFERENCE • (I) M,M) • • (F TJ • [KW) • 0·1.-.H J • (I 000 S) • • • • • (0 M,M) • • (AC FTJ • (1\;;) • (1~t1H) • ( :1>/f-li'fH) • SOCIAL
* GEOG. AREA • • {SU.~\IJ • (CF S l • (FT) • (1\i'i) • (MI\H) • • IMPACT CODE
*******************************************************************************•***********************************•************** • A~bNPA0112 • KASILOF RIVER • bO 1S,'l • H • 150,0 • 0 • 0 • 1772/l • NNUUUUU • • I 5 * KE,.Al-COOK I KASILOF RIVER• !51 10,0 • IS • 0 • llOOOO • !93000 • 91,834 • • SO CE:-.TRAL * UNDEVELOPED • 731; • 2381>.0• 135,8 • 40000 • 1'13VOU • • ur.r.uuuuuu
• * KENAI B-4, • • • • • • • • • • • • • . J.KoNPA0113 • KENAI LO-'ER • bO 29,0 • H • 100,0 • 0 • 0 • 15109 • YNUUUUU
• l 5 * f-E';Al-ClHlK I KtNAI RIVER • !50 4'1,9 • IS • 0 • 55000 . 2&3000 • 57,450 • • . SO CENTIHL • U•<:;t:VELOPED • lo!:lo • 5934,0• 83,9 • 55000 • 263000 • • U~II'.UUUUUU
* KENid a-3, • * • * • • • • • • • • • • • • • A~7NPA0114 • KILLEY RIVER • bO 19.9 • H • 230,0 * 0 • 0 • 13222 • YNUUUUU
• I 5 • ~E~;AI•COOK I KILLEY RIVER • 150 i5,0 • IS • 0 • 21000 • 1\JOOOO • 13<>.22 • * SO CENTRAL • UNOEVELOPlD • 160 • 52'1,0• 358.0 • 2101)0 • 100000 • • UNNUUUUUU
• KEf<AI 8-2, • • • • • • . • • • . • • • • . AK71<PA0l!5 * HCi<ElL RIVER • 59 4,'l • H • 75.0 . 0 • 0 • 1913.3 • YNUUUUU
• I 5 * KC:iJAl-COOI< I MCNEIL RIVER • !54 10.0 • IS • 0 • 2000 • 8000 • 23'l.lb
;!> . SO CENTRAL • UNJEVtLOP£0 • 102 • 248.0• 111.8 • 2000 • 8000 . • UNNUUUUUU
I • • ILll>HNA A•/.1 • • • • • • •
N * • • • • • • • • • 1-' • AK6NPAOI16 • MOOSE HORN • 60 30.9 • H • 110.0 * 0 • u • 19~8b • YNUUUUU
• ! 5 * l(fNAl•COOK I I(ENAI RIVER . 150 23.7 * IS • 0 • bOOOO • 2'10000 • 1>7.1%
• SJ CENTRAL • UNDEVELOPED * 1':>40 • 5520.0• 'lll,9 • 6(1000 • 2".101,10() • • UNNUUUUUU
w IIE<;AI C•2. • • • • • • •
* • • • • * • • * * AK7~PAOib3 • PAINT HIVER • 59 10,3 * H • :n. 0 • 0 • iJ • 2075,5 • NNUUUUU
• I 5 • 1\UU.I-COUI( I PAINT RIIIER ~. !Sil 1il,3 • IS • 0 • 6000 . <:8000 • 74,125 • •
• SO CENTfiAL • UN0EVELOPED • 250 • 511,0• 11 s. 0 • 1>000 • 28UOU • • UNNUUUUUU • • • ILIA'INA A•ll • • • • • • • • • • • * • * • • lK6NPAOl!7 • SHEEi' CREE~ I • 5"1 ~6.9 • H • 400,0 • 0 • 0 . 21>751 • YNUUUUU
• 1 5 * Ktril>l-COIJK I SHEEP CREEK • 150 ~5.9 • IS • Lt • 20000 • 94U00 • 28'4.59 • * • SO CENT>lAL • UNuEVELOPED • 101 • 1>35.0• 381 ·" • 20000 • 94U00 • • lJNNUUUUUU •
* SELDOVIA 0·2. • • • • • • . • • * * * • • AKbNPAO 11 'I • STELTER • oO 28,0 • H • 210.0 • 0 • 0 • 122'12 • YNUIJUUU
• I b * KENAI•COOK I KENAI RIVER • ISO 7,9 • IS • 0 • 84000 • 403000 • 30.502 • * • SO CEt.TUAL • UNOEIIELOPEO • 81.!9 • 3700,0• 1'18.8 • 84000 • 40.SUOU • • UYYUUUUUU
* * KENAl il-1. • * • • • • • • • • * • • • • AK7NPA0120 • TUSTUMENA ~ bO 2.4 • l1 • 5,1) • 0 • 0 • 27b0,0 * YNUUUUU . I b • KE•'•Al-C00K I TUSTUMENA GLA• I 50 33.9 • IS • 0 • 21000 • 102000 • 27. 59
* SO CE;>;TRAL * UNDEVELOPE:O • 57 • 181l,O• lO'li:\.9 * 21000 • 10.2u0v • • Uf<NUUUUUU
* * I<Et.AI A-2 • • • • • • • •
•••*******************************************X**********************************************************************~************
if
N
N
Project Listing(continued)
********************************************************************************************************************************** * SITE lD * PROJECT NAME * LATITUDE •PROJ.PURP.• DAM HT * tXIST.CAP, •tXIST,tNRG•ANUL. COST * ENVIRONMENTAL *
* *PRIMARY CO, •NAME OF STREAM •LONGITUOE * STATUS •TOT, STOR• INC, CAP, •lNC,ENERGV•ENERGY COST• IMPACT COOt *
* DEP ACTV * Q,..NER • ilR,ARE:A * AVE, iJ *~'fiR. HD, * TOT, CAP, •TOT ,Ei,r:.iiGY• * *
• CODE 1~'<\1 • !'lAP REFER<:NCE * CD M,M) * * (FT} * (KW) * {M..,H) • (1000 $) * *
• * * (0 M,M) * * (AC FT) • (KW) * (M,..Iil * (S/M,..H) * SOCIAL
• GEOG, AREA • * (SQ,Ml) * (CFS) * (Fi) * (r(W) • (M,.,H) * * IMPACT COOE * •••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••• * AKJ~PA0142 * BEAVER FALLS * 55 24.0 * H * 34,0 * 4200 • 25500 * 215,25 * NNUUUUU *
• 1 5 • KETCHIKAN BEAYER FALLS * 131 30,0 * OP * 2000 • 1000 * 0 * 0 * *
* SOUTHEAST * KETCHIKAN CITY * b * •80,2• 609,0 * 5200 * 4360 * * UNNUUUUUU *
• • KETCHIKAN 6•5 • * * * • • * *
* • ~KHIPA0249
* t 5
• SOUTHEAST
*
*
* Fl5H CREEK
* 1<ETCHJKA1<
* UNDEvELOPED
* KETCtiiKAN 0•1.
* • AK7NPA0135 * GOKACHIN
• 1 5 * ~ETCHIK4N
* SOUTHE&ST * WNOE~ELOPED
• .t.K7NP4013b
* I 5 * SOUTHEAST
* KE TCH!KA~J 1:!•'1,
• * HA5SLEf< LAKE
• KETCHIKAN
* UNDEVELOPED
* KETCHIKAN A•S.
* * AK7~PA0094 * JANUARY
• I 5 * KETCHIKAN
* SOUTHEAST • UNDEvELOPED
• KETCHIKAN C•4,
* KETCHIKAN LAKES
FISH CREEK
* ..
* 55 56,4 *
• 130 3,3 •
* 34 •
* • • ..
* 55 23. 1 •
GOKACHIN RlYE• 131 19,5 *
9 *
*
* •
• 55 11.0 *
HASSLER CREEK• 131 2b.9 *
* 5 *
* .. * * * 55 3'1.9 •
NF MANZANITA • 131 4,9 •
* 3 * .. .. * * • AKINPA0138
* I 2 * SOIJTt.EAST
* KETCHII<AN KETCHIKAN
• 55 21.5 *
CRE• 1':s1 37 .o *
*
* * A!<.DNPA0141
• I 2
• S'JUTriE.4:>T
*
• AK7NP.l0121
• I b * :iOIJTHEAST
* ClTY OF KETCHIKAN
* KETCH!KA.~ !1•5
• * LA~E CUI\INELL 0AM
• KETCH!~aN ~ARO CREEK
* KETCHIKAN PULP COMPANY
* ~ETCH!AKAN 8•5,8•&
*
• 11 •
* *
* * 55 2&.0 * * 131 4.0. 2 *
• 13
•
*
•
* • LAKE GRACE * KETCH!K4N
* 55 38.0 *
GRACE CR REVI• 131 0,0 *
• UNDEVELUPED * 29 * * KE.TCiilKAN C•3. * *
*
H *
IS *
H
IS
H
419.0•
*
*
8s.o•
IS •
•33,5•
*
H *
IS •
35.0• ..
SH •
OP *
so
OP
H
IS
•14&.&•
•
174,0•
*
*
388,0•
•
• AK&NPA0122 * MAHONEY LA~E LOWEN * 55 25,0 * H • * I S * KETCHIKAN MAHONEY CREEK• 131 30.0 * IS
* SOUTHEAST * UNDEVELOPED * 5 * 104.0•
* KETCHIKAN t!•S " * *
1>0.0 *
0 *
294,7 •
*
31.0 *
0 •
31>9.6 * ..
•
30,0 *
0 •
594.6 •
*
* 10.0 •
0 *
31>'1.1> *
* 3~.0 •
9200 *
2&4.7 *
*
* 85,0 *
0 •
149.8 •
* •
85,0 *
121>000 •
455,5 •
* •
20,0 *
3890 *
84.9 •
*
0 *
2364 ..
2:$1>4 •
0 *
&500 *
1>500 •
• () .
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*
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•
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*
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*
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• •
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*
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•
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• •
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*
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*
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173&.3
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881.74
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*
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*
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*
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* *
*
*
* •
*
* ********************•*************************************************************************************************************
:>
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Project Listing(continued)
***************************************•**********************************************************~·····························M~
• SITE ID * PROJECT NAME * LATITUDE •PROJ,PURP,• DAM HT * tllST,CAP, •EXISI.tN~G.ANUL, COST * ENVIR0NMENIAL *
• PRIMARY CO. •NAME OF STREAM •LONGITUDE * STATUS ,•TOT, STOk• INC, CAP, •lNC,t~tRGY•tNEKGY COST• IMPACT CODE
• OEP
* CODE
ACTV • O~NER * OR,AR~A • AVE. Q •PwR, HD, • TOT, CAP. •TUT,t~lR~Y•
INV • MAP REFERENCE * lD M,M) * • (fT) * (~WJ • (M•Hl * (!000 $) *
* • (0 M,M) • • (AC FT) • (KI'I) • (Mf'IH) * ($/M..,ti) *
* GEOG, AREA • * (SQ,MIJ * (CFS) • lFT) • (1\/i) * (M~H)
SOCIAL
IMPACT CODE
•
* *
*
··••*************************************••······················································································· * A'7NPA0123 • MAHONEY LAKE UPPER * 55 25.0 * H * 25,0 • 0 • 0 * 1691.4 * NNYNYNN *
* I 2 *KETCHIKAN MAHONEY LAKE • 131 j1,1 * IS • 10200 • 14400 • 55590 * 30,42b *
* SOUTHEAST * UliOEVELOPEO * 2 * 48,0• 11:12'>.1 • 144v0 • 55:,90 * * YNNNYNUVY
* * ,<;ETCHII\AN b-5 * * • * * • * *
* * • AK7NPA0312 • MANZANITA LAKE
• I ~ • KETCHI~AN
• SOUTtiEAST • UNDEVELOPED
* 1\t TCtili'\AN C•4
* • AKbNPA0!25 • MIRROR
• I 5 • KETCtiiKAN
• SOUTHE.I.ST * UNOEVELOPED
• KETCHI~AN C•ll
• • * AK7NPA0126 * NAUZAHEEN LAKE
• I 5 * KeTCHIKAN
* SOUTHEAST • UNDEVELOPED
* • KETCHI~A~ A•S
•
• AK7NPA0l27
• I b
• SOUTHeAST
•
• * NAHA RIVER
• KtTCHI~AN
* UNDEVELOPED
• KETCHIKA~ C•S
* • AK7NPA0128 • ORCHARD C~EEK
* J 5 * KETCHIKAN * SOUTHEAST * UNDEVELOPED
• KETCHIKAN 0·5
•
* * * 55 34,7
MANZANITA C~E• 131 1,2 *
MIRROR LAKE
* 25 * •
* * 5!'> 29,0 •
• 131 7. 9 *
* 23 *
*
* 55 13,4
NADZAHEEN ~AK• 131 27,9 *
NAHA RIVER
• b •
•
* • 55 35,3 *
• 131 37,9.
* 55 *
* *
* * Sb 49,9 *
ORCHARD CREtK• 131 29,0 *
• bO
*
* * AK7NPA0129 • PERSEVERANCE LAKE • 55 24,0 •
* I 5 • KEICH!KAN
• SOUTHEAST • UNDEVELOPED
• * KETCHIKAN B•o
• AK7NPA0!3i!
• I 2 * S:JUTHEAST
* S"AN LAKE
• KETCH l K A i·;
• U:<OEVELOPED
• KETCtii~AN C-3,
wARD COVf CRE• !31 40,0 •
* 3 *
* • * • 55 35,9
FALLS CR REV!• 131 21,0 •
3b
* • * •
• AKONPA0l39 • UPPE~ SILVIS LAKe • 55 22.8 *
FALLS * 131 30,9 * • 0 2
* SOUTHEAST
* KETCHIKA~ BEAVER
* CITY OF KETCHIKAN
* KETCHIKAN 6·5
* 22 *
•
IS •
H
IS
H
IS
H
IS
H
85b,0•
*
*
* 303.0•
* •
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*
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IS
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580,0•
• •
*
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• •
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•
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•
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•
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539,4 •
•
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274.7 •
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0 •
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* 0 •
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0 •
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*
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• •
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0 *
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*
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• •
0 •
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•
0 •
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•
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•
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•
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4197,8
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4958,7
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5,8277
*
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• •
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• ..
•
*
*
* •
*
*
*
• •
* • •
•
*
•
•
·················•***********************************************•*****~********************************•******************•******
:r
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Project Listing(contlnued)
**********************************************************************•*********************************************************** * Sill IU * PROJECT NAMt *LATITUDE •PkOJ,PURP,* DAM HT * EX!ST,CAP, •EXIST,tNkG•ANUL. COST* ENVIRONMENTAL * * *PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATuS •TOT, STOR• INC, CAP, •INC,ENERGY•ENERGY COST• lMPACl CODE *
* OEP ACTV * OwNER * DR,AREA * AVE. Q •P,..R, HO, • TOT • CAP, •TOT ,ENERGY• * "
* CJDE INV * MAP REFt.kENCE * (D M,M) * • (FT) * (Kw) * (MWH) * (1000 S) * *
* * * (0 f.l,M) * * (AC FTJ * (KW) * (Mt;H) • (~/MV.H) * SOCIAL • * GEOG, AREA * * (SQ.~II) * (CFS) * (FT) * (I<W) * (M,..rl) * * IMPACT CODE "
***•*****************************•************************************************************************************************ * A~CNPA2b00 * WH!TMAN LAKE DAM * SS 17,9 * 0 * 35,0 * 0 * U * 324.47 * NNUUUUU *
* I b • t<ETCrHKAN .~HIHIAN CREEK• lll 31.7 * IS * 0 * 3000 * 3000 • 10ll.15 • *
* SOUTHEAST * CITY OF KETCHIKAN * 5 * 90,0• 329.& * 3000 * 3000 * • UNNUUUUUU *
* • ..:ETCHit<Ai\1 8•5 • * * * * * * *
* • * * • AK7NPA0134 * WHITMAN LAI(f * 55 20.1
• I 5 * KETCHIKAN CASE CREEK * 1 31 52. 3 *
* SOUTHEAST * UNDEVELOPED * ':i * * • KETCHIKAN B•S. * *
* * * * * AKbNPAOl~5 * AGASHASHOK (IGICHUK) * b1 13.0 •
RIVER * 1&2 30.0 *
* 12700 *
* I b w KOBUK NOATAK
• ~ORTHWEST * UNOEVELOPEO * • NORTAK,A-1 1 A-2,B•2,B•3 •
*
• • * * * AKbNPA014b * BUCKLAND RIVER
* I b * KOdUK
* NORTH ... EST * UNDEVELOPED
* CANDLE D-5.
* * AKbNPA0147 • FISH RIVER
* I 5 * KObUK
• NORTHwEST * UhOEVELOPED
* • SOLOMON 0•3.
* * • AKbNPA01S1 * KIWALII<
* 1 5 * KOtiUK
• NORTHWEST * UNDEVELOPED * • CANDLE D•b,
* * Al<bNPA 0149
* I b
" tWRTHI'iEST
*
* * KOBUK RIVER
* KOBUK * UNOEVEL.OPED * BAIRU MT. A•1.
*
* b5 3.5 *
BUCKL.ANO RIVE* lb1 3.0 •
FISH RIVER
* 2410 *
* *
• • * b5 5&.9 *
* 1b0 30.0 *
* 1120 *
* * * •
• c5 53,5 •
KIWALIK RI~fR• 1&1 53.4 •
761 *
KOBUK RIVER
* * * • * b7 7,9 *
* "159 7.0 •
* 7840 *
* • *
* * AKb~PA0150 * KOGOLUKTUK RIVER * bb 58.9 *
* 1 5 *KOBUK KOGOLUKTUK RI• 15b 37.~ *
• NORTHwEST • UNDEvELOPED * 412 *
* * SHUNGNAK 0-2. * *
* * * • * A~bNPA0152
* 1 5 * NORTHWEST
*
* t<UGRUK
* KOSU~ * UNDEVELOPED
* 8ENOELclEN 0•2
* b'S Sll.O *
KOGRUK RIVER * 1b2 4~.9 *
* 855 *
* •
*
H *
IS *
~<~5.8•
*
* 9o.o •
0 *
379.b *
*
* * H * 150,0 *
IS * 7500000 •
103cO.o• 12s.a •
•
* H *
IS *
332&.0•
• •
H *
IS *
9'l4,0•
* •
•
* 120.0 •
0 *
102,a •
• •
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102,8 •
•
* H
IS
* 220.0 * * &400000 •
1157,0• 209.7 •
H
•
*
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7673.0•
•
*
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IS
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* ..
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IS •
1192,0•
*
•
* 125.0 *
0 *
113.8 *
* •
8'5.0 *
178500 *
84.9 •
*
* 230.11 •
304\10 *
224,7 •
·•
0 *
2500 *
2500 *
•
0
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18b000 *
*
*
0 *
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* *
0 *
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13000 *
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*
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0 *
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*
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*
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* •
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• •
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37000 •
*
*
0 *
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•
877,78
75.7&2
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29.220
13&211
172,41>
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28573
54.321
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*
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* * ..
*
* *
*
*
* ·····················••***********************************************************************************************************
:>
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Project Listing(continued)
*******•*************************************************************•***********************************************************• * SITE ID • PROJECT NAME. • LATITUDE •PROJ.PURP.• DAM HT • tXIST.CAP, •EXJST,fNRGoANUL. COST* ENVIRONMENTAL *
*PRIMARY CO, •NAMt OF STR(AH oLDNGilUOE * STATUS oTOT, STOR• INC. CAP, oiNC,ENE~GY•ENERGY COST• IMPACT CODE *
* DEP
* CODE
• ~
ACTV * ON~E~ • OR,ARtA * AVE, Q oPwR, HD, • TOT, CAP, •TOT,tN£HGYo *
INV • MAP RtFERENCE • (0 M,M) o * (FT) * (K.-1) * {MI'<H) * (1000 $) *
* (0 ~1.M) * • (AC FT) * (KW) * (M..,H) * (,1;/M,.,H)
* {SW.~ll) * (CFSJ * {FT) • (1\r.) * {Mt'iH) *
SOCIAL
IMPACT CODE
* • • • GEDG. Aric4 * ••••*******•***************************************************************************~****************************************** * AKoNPA0153 * MISHEGUK • 67 56,9 • H • 205,0 • 0 * Q * 27142 * YNUUUUU * * I b • r\08UK NOATAK RIVER • 1b1 38,9 • IS • 0 • 17'1000 * 7b0000 • 35,713 * *
* NORTH~EST • UNDEVELOPED * 8750 * 7735.0• 196 0 6 • 174000 * 7b0000 * * UNNUUUUNU *
* BAIRD I'IT 0•6. * * * • * * * *
• AK6~PA0154 • N!MlUKTUK
* ! t> * 1\0i:!UK
• ~ORTHhEST • ~NOEvELOPEO
• BA!RU MT, 0•3.
*
* • b7 58.(i *
NOATAK RIVER * 160 15.0 •
* 7000 *
* *
• AK6NPA015b • UPPE~ K08UK RIVE~ * * 66 'lb.9 *
* I 5 * ~O~U~ KOBUK RIVER • 15b 11,0 *
* 2970 * * ~ORTHriEST • ~NOEVELOPED
• AKbfWA0157
* 1 b * NORTHt~EST
• •
• SHLJt<IOtiAK D•l •
* UPPEI< I<ORTAK
• KOt:lU~
• UNIJEVELOPED
* SA li<U MT.';S 0•3
* • 4K7NPA0159 • AYAKULIK
• I 5 • KCUlAK
• SO CENTRAL • UNDEVELOPED
• .<.t..;Lul( A·2.
• AKN~PA0171 * DRY SPRUCE
* 1 5 * KODIAK
* SO CENTRAL * C~C FISHERIES
• KO.JIAK 0•11
* AK7N°A01e0 • FRASER LAKE
* 1 ~ * ~O~IA~
* Su CfNTNAL • U~0EvELOPEO
* KAKLUK A•1
•
• AKbNPA01b1 * KARLUK LAKE
• I b w KOUIA~
* SO CENTRAL • U~~EWELOPED
* ~ARLU~ C-1
• ~:O:iPA01o2 * OLGA BAY
• I 5 * KOD!AK
• SO CENTRAL * U~DEVtLOPED
• KA~LUK A•l
* •
• b7 51:>,9
NOATAK RIVER • 1b0 11.9 *
• 7050
" • *
* • 57 13,1 •
AYAKULIK RIVE• 154 23.9 *
• I 8 i
•
• • * 57 55.4 *
OkY SPRUCE 6A•~153 3.0 *
• 1 •
• •
* * • 57 11.2 *
DOG SALMO~ CR• 154 10,1 *
* 7 2
• *
* • 57 23.0 •
KA~LUK RIVER • 15'1 3,0 *
* 165 *
*
* 57
OLGA NARROWS • 154
*
*
* 3.9 •
3,9 *
335
*
11 *
IS
o21&.o•
*
H
IS *
H
3031>,0•
*
*
IS *
4970.0•
*
H *
IS •
H
OP
455.0•
• •
* 4.0•
*
*
H *
IS •
17'1.0•
*
H *
IS *
414,0•
•
H *
IS
980,0•
*
* 245,0 •
0 *
1b5.S •
*
90.0 •
0 •
b 1. 9 •
* :no.o •
0 *
279,7 •
* •
85.0 *
0 •
160.8 •
* •
0 *
0 *
600.0 *
•
* s.o •
0 *
301.1> •
* 200.0 *
0 •
343.1> •
•
45.0 •
v •
b3.'l •
*
* 0 •
140000 *
140000 •
•
* 0 •
23000 *
23000 •
*
0 *
211000 *
211000 *
• •
0 *
10000 •
1ovvo •
*
75 •
295 *
370 *
* •
0 *
7000 *
7000 •
* •
0 *
18000 •
18000 *
•
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0 *
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8000 •
•
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&13000 •
b13(i00 *
•
0 •
114000 *
114000 •
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() .
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*
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0 •
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&5000 •
•
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37000 •
24617
'10.158
88!)1,&
17.207
30114
32.504
o1&3.a
125.79
B.Sb5
35.708
2370.3
74. 73
• •
*
*
*
*
*
* •
*
*
*
*
*
*
*
*
* 5399.0 •
&3.516 *
341!!.5
92,392
*
*
*
*
*
YNUUUUU
UNNUUUUNU
NYUUUUU
U~NUUUUUU
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UNNUUUUNU
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UNNUUUUUU
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TNUUUUU
UNNUNNUUU
YllUUUUU
UNNUUUUUU
* •
* • • • •
*
*
*
*
*
*
*
*
*
*
*
*
*
* •
*
*
* •
• •
*
w•~~********•**•~•*************************************************************•~**********•*************•************************
~
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Project Listing( continued)
**********************************************************************************************************************************
* SITE IO * PROJECT NAME * ~ATITUDE •PROJ.PURP,• DAM HT • E~lST,CAP, •EXIST,ENRG•ANUL, COST* ENVIRUNMENTAL * * *PRIMARY CO, -NAME OF STREAM •LONGITUDE * STATUS •TOT. STOR• INC, CAP, *lNC,ENERGY•ENE~GY COST• IMPACT CODE * * OEP ACTV * O"'NER * OR.At<EA * A\IE, Q •P.-.R, HO, * TOT. CAP, •TOT,tii<Ef<GY•· * * * CuOE lN\1 * MAP REFERENCE * (D M,M) * * (FT) * (KW} * (~1t'ln) * (1000 S) * *
• * * (0 M,M) * * (AC FT) * (KW) * (M,.,H) * (S/MWH) * SOCIAl. •
• GEOG, AREA * * (SO,Ml) * (CFS) * (fT) * (Kw) * (MfiH) * • IMPACT CiJOE *
*************************************************•**************************************•*****************************************
* AKNNPA0170 * ONE MILE CREEK * 57 2,5 * H * 10,0 * 8 * 70000 * 0 * NNUUUUU * * I 9 * KODIAK ONE MILE CR K* 152 23,9 * OP • 0 * 0 * 0 * 0 • *
• SO CENTRAL * NE~ ENGLAND FISH CO, * 15 * b2,0• 300,0 * 8 • 70000 • * UNNUUUUUU *
* KODIAK 0•1 * * * * * * * *
* * * AKbNPA0164 * SPIPIDON LAKE
* I 5 * KODIAK
• SO CENTRAL * UNOEVtLOPEO
* * KODIAK C•S,
• * AK7~PA0165 * SPIRIOON RI\IER
* I 5 * KODIAK
* SO CENTRAL * UNDEVELOPED
* * KODIAK D-b
* * * A~7NPA0lbb * TERROR LAKE
* I 2 * KODIAK
• SO CENTRAL * UNDEVELOPED
* * ~OJIAK C•ll.
• ..
* AKNNPA0169 * UGANIK
* I 4 * KOU!AK
.. * * 57 4Q,O *
SPIRIOON LAKE• 153 40,0 *
* 2~ *
* * • * * 57 40,9 *
SPIRIDON RIVE• 153 38,9 *
• 23 *
* *
* •
• 57 40. 0 *
TERROR RIVER * 153 b,O *
* 17 *
* * * * * 57 115.9 ..
CRATER CR KOD* 153 3~.0 *
* SO CENTRAL • INTE~COASTAL PKG, CO, * 15 *
* * KODIAK C•ll
* * • AK7NPA0167 * UGANIK
• I b * KODIA~
* SO CENTRAL * UNDEvELOPED
* • KODIAK C•5,
* * AKbNPA0172
• I b * SOUTHwEST
* •
* • CROO!<.ED CREEK
* ~U5tWKwi>1
* U·'IDEVELUPED
• SLEETMUTE D•b.
* * AK6NPA2b13 * HOLY CWOSS
* *
* * • 57 41,0 *
UGANIK RII/ER * 153 23.1 *
97 *
*
*
* • .. bl ll9,'l •
KUSKOKWIM RIV• 158 0,0 *
* 31100 *
*
*
*
*
• 0 b * KUSKOK~IM YUKON RIVER
* b2 15,0 *
• 159 40.0 *
* 320000 * * YUKON * UNUEVE!.UPED
* * HOLY CROSS A•l,A•2.
• * * A~7NPA0173 * KUSKOKWIM RIVER
• I 5 * KUSKOK.-.IM KOSKOK~IM * SOUTHnEST * uNDEVELOPED
* * MCGRATH A•l,
* * • * * 62 ll,'l *
RIV• 153 19.9 •
* 870 *
* *
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* 70,0 *
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* * 5.0 *
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*
* 25,0 *
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*
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93,9 *
• ..
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•
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•
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*
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2140000 *
2140000 *
*
*
•
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24801> •
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*
*
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107853 *
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*
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139000 *
139000 *
*
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0 *
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0 •
11b510 *
11651\1 *
*
* 0 •
9400000 *
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*
* 0 • 0 ..
2600000 • 12300000 *
2800000 • 12300000 •
* ..
0 ..
15000 •
15000 *
*
* •
0 *
72000 •
72000 *
*
* 1910.2 •
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*
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************•******•****************************************************************************************•*********************
Project Listing(continued)
**********************************************************************************************************************~*********** • SITE IU • PI'IOJECT NAME • LA T I TUOE •PRUJ,PUkP,• [JAM HT • tXIST ,CAP. •EXIST.tN~G•ANUl. COST • fNV HWI•MEN TAL • • . PRIM4RY co. -NAME OF STREAM •LONGITUDE • STATUS •TOT, STOR• INC, CAP, •INC,ENEAGY•ENENGY COSh IMPACT CUDE * • DEP AC TV • O.-.NER • OR,AREA • AVE. Q •PMI, nO, • TOT, CAP, •TOT,t:NtRGY• • • • CODE l'JV . MAP REFERENCE . (lJ I~, M) . • (FT l • (K .-1) • (M,,h) . (1000 :S) . . . (0 N,M) • • (AC fTJ . (K") • (M..,H) * ($/M>';H) • SOCIAL • • GEOG, AREA • • (S(l,IH) • (CFS) • (F T) * (r<w) • (Mil H) • • lMPACT CODE
***********************************************************************•***************************•···~·························· • AK6NPA0174 • BELUGA LOWER • I:> I IS,O • H • 60.0 • 0 • 0 • 4256,8 • NNUYUUU * • I 5 • MATANIJSKA-SU BELUGA RIVER * 151 o.o • IS * 0 * 15000 . 7200\1 * 59.122 . sa CENTRAL • UNDfvELDI'ED • 950 • 2470,0• 48,9 • 15000 • 72voo * • uNt.uouuuu
* TYONEK A•3, • * * • * • • * • • • * * * • • • • . 41U)NPA0175 • BELUGA UPPER • 61 15.'1 • H • 180,0 * 0 • 0 • 111<13 • Nt\UYUUU • • 0 2 • "iA T ANUSKA·SU BELUGA RIVER • 151 15,0 * IS • 0 . 48000 * 2100()\J • 53, b6 * • • SO CENTRAL • UNUEVEt.OPEO * 840 • 2484,0• 1111,8 . 48000 * 210000 • • UNNUUUUUU It
• TYONEK B-4. • . • • • • • * . • • • • • • * * • AK7NPA014d • BOULUHI CREEK • b3 17,2 • H * <ll .o • 0 • ii • 28S3,4
• l 5 • ~ATANUSKA•SU BOULDER CREEK• 1 <!7 'l,9 * IS • 9lob5 • 7000 • 35(}00 • 8!.528 • * . SO CEI< TR AL . UNOEVEL(Jr-tu • 42 • 92,5• 917.u • 701.10 • 35000 • * • . MEALY d•1 • * • • * * • . • • • AK7NI'A017b . BOULDt::R CREEK 1 • 61 40.0 * H • 200,0 • 0 • 0 • 5191,4 • NNUUUUU • • I 5 * MATANUSKA•SU BOULDER CREEK• 14'1 4,9 * IS • 0 • 1'1000 • b9000 • 75.239 • • > • SO CE.NTRAL • UNl!EVtlUPEO • 90 • 113.0• 1315.b • 14000 • 69000 • * UNNUUUUUU * I • * ,_NCHORAGE 0-11, • • • • • • • * N ...... • • • • * * * • • Af,l>i~PA0177 • CACHE • 1:>2 33.9 .. H • 340.0 • 0 • 0 • '8909.2 • NNUUUUU
• I 5 * MATANUSKA-SU TALKEETNA RIV• 11.19 11.0 . IS • 780000 • bo>Oi.iO • 2o'li:>OU • 30,971 • • • so CENTRAl • i.J'WEVELOPEO * 750 • 1450.0• 299.7 .. 6b0VO . 289600 • . UNIWUUUUU • • TALKEETNA 1-<TNS C•5 • • • . • • • • • . • • • • • . • * • Ali6NPA0171) • CARIBOU CREEK • b1 4b,9 • H • 620.0 • 0 • 0 . 15895 • NN¥YYUU • . 1 ~ • MATANUSKA•;,U CARIBOU CREE'K• 14 1 :54,9 • IS • 0 • 1'4000 • 90000 • 17b,bl • • • SO CENTIUL * Ur;OEVcLOPED • 2b0 • 304.0• S2b,4 • 19000 • 90000 • • UNNUUUUUU • • AI<CHURAGI:. o-2 • • • • • * • • • . • • • • . AX6NPA0182 • CHULITNA EF • b3 10,0 . H • 420.0 . 0 • 0 • 6701.7 • NliYYYUU • . I 5 • >lA T Ar<U::.KA-SU E FORK CHULih 149 25.0 • IS • 0 • 12000 . 5900\J • 113.58 • • SO CeNTRAL • U~UEvELOf'I:U • 135 • 331.0• 379.& * 12000 • ':>900G . • UNNUUUUUU
• f1£ALY A•'>, • • • * • • • • • • • * • • • • • • U6NPAQl81 • CHuli Ttl A JURRICAI-E * 63 ll,9 . H • 230,0 . 0 . 0 . 7<lb2.3 • N~<UUI)UU
• I 2 • MATANU::.KA•SO Cf1ULITNA f<IVE• 149 45,0 • IS • (/ • 3'1000 • l6bOOG • ..s. 711 • . 50 CENTRAl. . UNO~VI::LOPEO * 795 • 2622,0• 206,7 • 31.1000 • 1bb000 • • UNYUUUUUU
• HEI<LY A•b, • • . * . • • • • • ~ • • • . • . AKbNPA0179 . CHUI. IT;;A wF . b3 1:>,9 • H • 30o.u . 0 . 0 • !>4bO,Il * NNUUUUU
• I s • MATANU:)KA•SU " FORK CHUL I To 149 3S.2 • IS • 0 • 111000 • 68000 • t>0.300 • • SO CENTRAL • UNDEVElOPED • 355 • 883.0• 2Bo.7 • 1'1000 • 68UOO • • UYYUUUUUU
" " HEALY ~o~e. • • • • • . •
•**********~*••••*~*******************W***•**************~******************************•**********•******************************
> I
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Project Llstlng(contlnued)
**********************************************************************************************************************************
SITE lD * PROJECT NAM~ * LATITUuE *PRUJ.PURP.• DAM HT * ~XlST.CAP. *EX1ST.£N~G•ANUL. COST* ENVlRONMENTAL •
• *PRIMARY CO. ~NAM~ Of STREAM •LONGITUDE * STATUS •TOT. STOR• INC. CAP. •INC.eN~RGY•ENERGY COST• lMPACT COOt •
* OEP
• CuDE
ACTV * O"Nt:R * DR.AREA * AilE. Q •PwR. HD. * TOT. CAP. •TOT .ENERGY• * *
INV * MAP REFERENCE • (0 M.M) * * (FT) • (K"') * (t·1i11H) * (1000 S) * •
* * (0 M.M) * * (AC FT) * (~"') * (Mt'<H) • ($/MWH) * 'SOCIAL *
r.Fm;_ AREA * * (SQ.MI) * (CFS) * (FT) * (KW) * (MWH) • • IMPACT CODE * * ************************•*********************************************************************************************************
* AK7NPA0180 * CHUNlLNA * b2 49.9 * H * 175.0 * 0 * 0 * 2491.11 * NNUUUUU *
• I 5 • MHAriUSKA•SU CHUNILNA CREE• 150 0.0 * IS * 0 * 5000 * 25000 * 99.b56 * • * SO CENTRAL * UNDEVELOPEU * 240 * 524.0• 197.8 * 5000 * 25000 * * U~NUUUUUU *
• •TALr<EETNAB•1. * * * * * * * *
* ..
* AK&~PA0183 * COAL
* E-5 * MATANUSKA•SU
* SO CENtRAL * UNDEVELOPED
* -* TALKEETNA MTNS
* * • AK&NPA0184 * COAL CREEK * I 5 * MATANUSKA•SU
* SO CENTRAL * UNUEVELOPtD • * ANC~ORAGE 0•4,
* *
* * 62 57,3 *
CHULITNA RillE• 149 43,5 *
o-o.
.. 985 *
*
*
* • &1 46.9 *
MATANUSKA RIV• 148 10.0 *
* 1128 *
*
*
*
* * AK4NPA005b * COOK INLET TIDAL * bl 9.6 *
* 150 9.5 * * 1 4 * MATANUS~A-SU COOK INLET
* SO CENTRAL * UNDEVELOPED * * * • ANCHORAGE A•8, * •
* AK7NPAD187 * DEADMAN CREEK
• I 5 * 1-:ATAtHISKA-SU
* SO CENTRAL • UNDEVELOPED
* * * 1>2 55.8 *
DEADMAN CREEK• 148 22.8 *
* 1b0 * * TALKEET~A MTNS 0·3. * * • * * AK6NPA0185 * DENALI U5BR PROPOSAL * b2 42,
* E 5 * MATANUSKA•SU SUSITNA RIVER• 1~47 34. *
*
* •
• SO CENTRAL • UNDEVELOPED * 12&0 * * TALKEETNA MTNS C•2 *
* * * AKa:,PA016b
* E b
* SO CENTRAL
*
* • i.K6t1PA0186
* 0 2 * SO CENTRAL
*
* * DEVIL CANYON
* MATA~USKA•SU * UNUEVELOPEO
USBR PROPOSAL * 62 48.9 *
SuSlTNA RIVER• 149 16.9 *
* 581U *
* TALKEETNA MTNS D-s * * • * DEVIL CANYON
* MA TANUSKA•SU
* UNOE\IELOPED
* TALKEETNA MTS ..
NPA PROPOSAL * 62 48.9 *
SUSITNA RIVER• 149 18.9 *
o-s o-4.
* 5810 *
*
*
*
*
*
H *
IS *
3312.0•
* *
H *
IS *
2208,0•
*
*
H *
IS
0•
*
* H *
IS *
483,0•
*
* 2&5.0 *
0 *
240.7 *
*
* 410,0 *
0 *
290,7 *
* 75,0 *
0 *
12.0 *
*
* 110.0 *
0 *
961.0 *
H • 21>8.0 *
Sl * 4400000 *
3191,0• 397,5 *
*
H *
SI
9510,0•
*
*
*
* b3S.O *
970000 *
57<l,4 *
* HRC • b35.0 *
FP * 1050000 *
9227.0• 574.4 *
*
*
*
*
*
0 *
40000 *
40000 *
*
*
0 *
611000 *
64000 *
* 0 •
0 *
0 *
* *
0 *
34000 *
34000 *
*
0 *
92522 *
92522 •
*
*
0 *
738000 *
73oOuO •
* 0 •
77 bOOO *
776000 *
*
0 *
193000 *
193000 *
*
0 *
3u7ooo •
307000 *
*
0 *
0 *
0 •
*
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0 *
1!:15000 •
lb5000 *
*
*
0 *
396059 *
39bll59 •
*
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0 *
3205000 *
320SOOu *
*
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31110000 *
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•
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•
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*
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* • AKJNP10225 * EKLUTNA DAM * 61 211.b * H * 20,0 * 30000 * 1&4000 * 0 * NNUUUUU *
• I 4 * MATANUSKA•SU EKLUTNA RIVER• 149 9.4 * OP * 213271 * 0 * 0 • 0 * *
• SO CENTRAL * 001 USSR * 119 * 187.8• 851,0 * 30000 * 164000 * * UNNUUUUUU *
* * ANCHORAGE C-5 • * * * * * " ,.
·······~······················••**************************************************************************************************
> I
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1.0
Project Listing(continued )
14***•**************************************************************************************************************~*************
SITE ID * PROJECT NAME * LATITUDE •PAOJ.PURP.• OAM HT * EXIST.CAP. •EXISI.tNMG•ANULo COST * ENVIRONMENTAL *
* PRIMARY CO. -NAN~ OF STREAM •LONGITUDE * STATUS oTQT, ST0N• INC. CA~. •INC.tNtRGYotNEMGY COST• IMPACT CODE *
• DE? ACTV * O~N~A o DR.AREA * AVE. Q oP~R. HD. • TOT. CAP. •TOT.~NER&Y• *
• CODE. 1NV * MAP REFERENCE * (I) M.M) * * (FT) * (~WJ * (t<fiH) * (1000 $) * *
* * * (0 M.MJ * * (AC FT) o (Kw) * (M,ri) * ($/Ml'IH) * SOCIA!. * * GECG. AREA • o (SO.HI) * (CFS) * (FTJ * (K.-.) * (Mi>H) * * IMPACT COOE
·········-························································································································ * AK7NPl0169 • EMERALU o b1 45.3 • H o 285.0 • 0 * 0 * 10533 * NNUUUUU *
* I 5 * MATANUSKA-SU SK~ENTNA RIVE• 152 43.9 * IS * 0 * 37000 * 17700~ * 5~.509 * *
* SO CENTRAL * U~DEVELOPEu • 370 • 1090.0• 3b5,6 • 37000 * 177000 * * UNNUUUUUU *
• • rvur,.c.K O·B • • • • • • * •
* A~6NPA0190 * GOLD
• 0 6 • MATANUSKA-SU
* SO CENTRAL * UNDEVELOPED
* • TALKEEfNA MTS
• * * AK7~PA0l91 • GAINITE GORGE
• I b • M~lAt,lJSKA-Su
• ~0 CENT~AL • UNUEVELGPtO
* • IAL~lflNA MTNS
•
AK7NPA0192 • GREENSTONE
* * * b2 44.0 *
SUS!TNA RIVER• 149 41.9 *
* 611>0 *
C-b D-b 0-:5. • •
* 62 27.0
TALKEETNA RIV• 149 2b.9 •
* 865 as.
• *
I b * MATANUS~A-SU TALKEETNA
* 62 31,9 *
• 149 2,0 *
* Su CENTRAL * UNOEVfLOPEO * 790 * • TALKEETNA ~TNS C~S. * • *
* ~ AKo~PA~lq5 * rliYES
* I 5 * MATANUSKA•SU
• SO CENTRAL * U~DEVELDPEO
• TYONE~ 0-5.
* * • AK6NPA0194 • HICKS SITE
* I 5 * MATANUS~A-SU
• SO CENTRAL * UhDEVELOPfD
• A~.CHURAGE U-3
*
* 61 58,0
SK~ENTNA RIVE• 151 51.0 *
• I 7 30 *
*
• 61 ~7.9 *
MATANUSKA RIV• 147 q8.0 •
• 950 *
..
* H
IS •
10121.0•
* *
H *
IS
1600.0•
H *
IS
H
1587,0•
*
*
I 5 •
'1830.0•
H *
IS •
1794.0•
* * 'KbNPAO!'lS * IRON CREEK * b2 21 0 3 * H
• I 5 * MATANu~KA•SU I~ON CREEK • 149 16.2 • IS • * SO CENTRAL * UNOEVELOPE~ • 21U * 552,0• * TAL~tET~A MTNS B-5. *
* * AK6NP~019o * KASH~ITNA
• I 5 * HIIA~U5~A·SU
* SO CENTRAL • UNDEVfLO?ED
* A~~Cti(JK.t.GC. D-8
* • AKbNPA0197 • KEETNA
* I 2 * MATANUS~A-SU
* SO CENTRAL * UNDEVE!.DPEU
• TALKEETNA MT5
* • bl S7.2 *
KASHWITNA RIV• 1~9 Sb.O •
* 270
* •
* b2 26.5 *
TALKEETNA RIV• 149 lll.b *
• 1250 *
8•6 • *
H *
IS
570.0•
*
H
IS
2400.0•
*
•
230.0 *
0 *
188.8 *
* 200,0 •
0 *
415.5 *
* 160,0 *
0 •
303,6 •
* * 210.0 •
0 *
106.8 •
* •
300,0 •
0 •
280,7 *
* 350.0 *
0 *
199.8 •
*
240.0 *
u *
23~.1 •
•
* 360.0 •
910000 *
285.7 *
•
Q *
2bOOOO *
2b0000 *
*
0 *
7<!000 •
72000 * • •
0 *
51000 *
51000 •
* •
0 *
690011 •
89000 *
• •
0 •
59000 *
59000 •
*
0 *
31000 *
31000 *
*
*
0 *
20000 *
200<.10 •
*
* 0 •
74000 *
74000 •
•
* 0 •
1139000 *
1139000 *
0 *
345000 •
3q5000 *
• •
0 •
2'1bQOO *
24b000 *
*
0 •
<1291!00 *
42'1000 *
0 •
21:1euoo •
2&b000 *
*
0 *
1117000 *
147000 *
*
* 0 •
89176 *
8917!:1.
• •
\) *
324000 •
324000 *
•
2519"1
22.1211
51.1q3.0
15.77&
b733.3
27.371
1591)1
37.253
13779
48.17"1
*
*
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*
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• ..
* • •
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1 7 3'16
195. 7
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• • •
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* •
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~·*~*~********••••··~······················~·································~····················································
;l>
I w
0
Project Llsting(continued }
******************************************************•***************************************************•**********************•
• SITE ID * PROJECT NAME *LATITUDE *P~OJ.PURP,• DAM HT * EXIST.CAP, •EXIST,ENRG•ANUL. COST* ENVIRONMENTAL *
* * PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •TOT. STOR• INC, CAP, •INC,ENERGY•ENE~GY COST• IMPACT CUDE *
* DEP ACTV * OwNER * OR.AREA * AVE, Q •P~R. HD, * TOT. CAP, •TOT.ENERGY• *
* CJDE !NV * MAP REFERENCE * (D M,M) * * (FT) * (Kw) * (MWH) * ( 1000 $) *
* * * (D M,M) * * (AC FT) * (KW) * (MWH) * ($/MO'IH) *
* GEOG, AREA * * (SI.J,t·1l) * (CFS) * (FT) * (o<W) * (MWH) * *
SOCIAL
IMPACT C\JDE
*
*
* •~*****a**************************************************************************************************************************
• AKb~PA019d * KING MTN
• I ·o * HATANUSKA·SU
• SO CENTRAL * UNDEVELOPED
* * ANCHO~AGE 0•5,
* *
* bl 15.0
MATNAUSKA RIV• 148 19,9 *
* lb35 *
*
* * AKbNPA0199 * LAKE CREEK LOWER * b2
*
*
(>,9 *
* I 5 * MATANUSKA•SU LAKE CREEK * 151 o.o *
335 * * SO CENTRAL * UNDEVELOPED * * * TALKEETNA A•2, * *
* * * * AK7NPA0200 * LAKE CREEK UPPER • 62 2b,O *
* !51 27,9 •
* !!5 *
• I 5 * MATANUSKA•SU LAKE CREEK
• SO CENTRAL • UNuEVELOPEO
* * TALKEETNA B•3,
* * • AKbNPA0201 * LANE
• 0 b * MATANUSKA•SU
• SO CENTRAL • U~DEVELOPED
• TALKEETNA C•1
* * ·• AKbNPA0202 * LOwER CHULITNA
* D b * MATANUS~A-SU
* SO CENTRAL * UNDEVELOPED
• • TALKEETNA B•l
* * • AKbNP~0203 • LUCY
* I 5 • MATANUSKA-SU
* SO CENTRAL • UNDEVELOPED
* TALKEETNA MTNS
• * * AKbNPA020~ * MCLAREN RIVER
* I 5 • MATANUSKA•SU
• SO CENTRAL • UNDEVELOPED
* GULKANA D•b,
* * • AKbNPA0205 * MOOSE CREEK
• I b • MATANUSKA•SU
• SO CE~TRAL • UNUEVELOPED
• * ANCHURAGE C•b,
* • AKbNPA020b * OHIO
* I 5 • M1TANUSKA•SU
* SO CENTRAL • UNJEVELDPED
* TALKlETNA MTNS
*
*
*
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~ w
1-'
Project Listing(continued)
*********************************************•*************•**********************************************************************
• SITE ID • PROJECT NAH~ • LATITUDE •PROJ.PURP,• DAM HT • EXlST,CAP, •EXlSI,ENKG•ANUL, CUSi * ENVIRONMENTAL * * PRIMARY CO. •NA~l OF STREAM •LONGITUDE • STATUS •TOT, STOR• INC, CAP, •INC,E~iRGY•ENEHGY COtiT• IMPACT CUOE *
* OfP
• coot:
ACTV • OM,t:R • UR,AREA • AVE. Ll •P,\R, HD, • TOT. CAP, •TOT .t.:,.t:RC.Y• • *
JriV • MAP REFEREt<CE * (0 M,M) • * (fT) * (J<W) * (MWH) * (1000 $)
* * * (0 M,M) * * (AC FTJ * (!<.1'<) * (MhH) * ($/MWH)
* GEOG, AREA * • (SO,Ml) * (CFS) • (FTJ • (KW} * (MWH) •
::iOC IAL
IMPACT CUOE
•
*
·····································~································~··························································· * AK7NPA0207 • PAL~ltH * 61 32,9 * H * 5U,O * 0 • v • 72U0,2 * NNUYUuU *
* I 5 • MATANUSKA•SU MATANUSKA RII/• 1~9 4,9 * IS • 0 * 16000 * 79000 * '11.142 * *
• SO CENTRAL • UNDEVtLOPf.D * 2070 • 4027 ,0• 11'>5,8 • 1b000 * 79000 * * Ut-.YUUUUUU
• ANCHORAGE C•6, * • • • * * *
• AKbtJPA0208 * PU~INTON CREEK
• I 5 * MAIANUSKA•SU
• SU'CENTRAL • UNDEVELOPED
• At<CI'lURAGE D-4,
* • AK7~PA0209 • ~USH lAKE
• I b * MATANUSKA•SU
* 50 CENTRAL * UNDEvELOPED
* ANCHORAGE. 0•4,
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• •
* 61 45,9
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* 1082 •
• *
* • 61 49,9 •
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* 69
• b2 18.3
*
*
* I S • MATANUSKA•SU SHEEP CREEK * 149 27,9 •
366 • • SO CENTRAL * UNUEVELOPEU
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•
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• 61 51.9 •
RIVE• 152 7,0 *
• SQ CENTRAL * UNUfVELOPED
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•
t AK7NPA0212 * STRANCLINE LAKE
* 950 •
• • *
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* I 5 • ~ATA~US,A•SU TALKEETNA
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·······························•*****************************************~···················••••************~****************~···
:r w
N
Project Listing(continued)
*************************************************•******************************************************************************** * SITE 10 * P~UJECT NAME * LATITUOE •PkUJ.PURP.• OAM Hi * EXlST.CAP. wEXlST.tNR6•ANUL. COST * ENVlRO~MENTAL *
* *PRIMARY CO. •NAME OF STREAM •L.ONGITUIJE * STATUS' wTOT. STOR• INC. CAP. •INC.ENEkGV.ENER6Y COSh IMPACT COOt: *
* DEP ACTV * O~~EN • OA.ANEA * AVE. Q •P~R. hD. * iOT. CAP. •TOT.ENERGY• * •
• CODE IIIV • MAP REFERENCE * (0 N.M) * ., (FT) • (K,.;J * (MIIH) • (1000 :i) * w
* * * (0 M0 M) * * (AC FT) * (KW) * (MtiH) • (;l>/MWH) * SOCIAL •
* GEOG. AREA * * (Sil.Ml) * (CFS) * (fT) * (K"') * (M,..H) * * IMPACT CUD£ *
**********************************************************************************************************************************
* AK&NPA021& * TALKEETNA 2 * 62 28.0 * H * 375.0 * 0 * 0 * q487.0 * NNUUUUU * * I 2 * MATAN05KA•SU TALKEETNA RIV• 14q 22.0 * IS * 0 * qQOOO * 40&44& * 23.341 * *
* SO CENTRAL • UNDEVELOPED * 850 * 1650,0• 5&q,b * 90000 * 40b44b * * UNNUUUUUU *
* * TALKEETNA MTNS 6•5, * * * * • * * *
* * * AK&NPA0216 * TOKICHITNA * 1 6 * MATANUSKA•SU
* 50 CENTRAL * UNDEVELOPED
* * TALKEETNA C•l,
* * * AK7NPA0219 * TRAP~ER
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• * TALKEETNA MTNS
* *
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CHULITNA RIVE• 150 11.9 *
• 25&u •
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*
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RIVER• 147 32,0 *
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* SO CENTRAL * UNDEVELOPED * TALKEETNA MTNS C-2. .. * • AKbNPA0222 • WATANA NPA PROPOSAL.
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•
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* NORTHwEST * UNDEVELOPED * 2400 * 130.0• 75.0 * 1400 * 5q500 * * UNNUUYYYY *
* • UNALAKLEEK 8•3 * * * * * * * *
························••***************************************************•*****************************************•*****•**•*
> I w w
Project Listing(continued )
**************"*************•~···································································································· * SITE ID * PROJECT NaME • LATITUDE •PROJ.PURP,• DAM HT • EXIST.CAP. •EXIST,ENNG•ANUL. COST • ENVIRONMENTAL *
* * PRIMARY CO, -NAME OF STREAM •LONGITUDE • STATUS •TOT. STOR• INC, CAP, •INC,ENE~GY•ENERGY COST• IMPACT CUDE • * Q£P ACTV * O.-.~~;ER • OR,AREA * AVE, Q •P11R, HU, *TOT, CAP, •TOT,t::Nt.RGY• •
* COilE IN\/ * MAP REFERENCE * (D M,M) • • (FT) * (KW) • (MWH) • ( 1000 ;~>) *
* * * (D M,M) • • (AC FT) • (KW) * (M..,H) • ($/MV.H) • SOCIAL * * GEOG, AREA • • (SQ,~ll) • (CFS) • (FT) • (KW) • (HhH) • * IMPACT CUOE. *
**********************************************************************************************************************************
* AKbNPA022D * KUllTRlN RIVER * D5 !3,0 • H * 120,0 * 0 * U • 1121!4 * NNUUUUU
* I S * NO¥.£ KUZITR!N RIVE• lt>b 0,9 • IS • 0 • 1'1000 • 67000 • lbl!,'i3 •
* NORTHNEST • U~OEVELOPED • 1790 • 3138,0• 94,9 • 1~000 * 67000 * * UYYUUUUUU * • • 8ENDeLEoEN A•b,
* * • A~7~PA0227 • SALMON LAKE
• I 5 • NOME
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* * SOLOMON 0•6 • * • 4~6~PA0223 * TU~SUK
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* • TELLER A•2,
* * * AK7NPA02~4 • BADGtR BAY LAKE
• • •
• 64 5'1,9 •
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107
•
• 65 13.8 •
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• • • 55 13.0
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• • •
• 55 18. 'I •
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• 20
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• I b • UUTE~ KETCHI CHECATS LAKE • 1!0 48,9 •
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* • KETCHIKAN 8•3, • • •
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• OUTER KETCrli NICHOLS OFFST• 131 31,6 *
* METLAKATLA POWER & LIGHT * 2 *
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•
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* 0UTEK K~TCHI C~ICKAMIN
• UNUEVELOPED
• 6RAOFitLD CANAL A•2
•
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• •
• 5t> o.o
IHV• 130 37,3 •
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······················••••k***********************************•••······················~···········-······························
> I w .p..
Project Listing(continued)
********************************************************************************************************************************** * SITE ID * PROJECT NA~E * LAfiTUOE •PAOJ,PURP,• DAM HT • lXISI,CAP, •EXI5T,ENRG•ANUL, CUST * ENVIRONMENTAL *
* • PRIMARY CO. •NAME OF STREAM •LONGITUDE * STATUS •TUT, STOR• INC, CAP, •INC,ENtRGY•ENE~GY COtiT• IMPACT CODE *
* OEP ACT \I • Olli'<tR * llll,AREA * AVE. Q •PWR, t1D, * TOT, CAP, •TOT .!:.NERGY• * *
• CUDE IN\1 * MAP REFERENCE * (0 M,M) * * (t'T) * (KW) * tMWH) * (1000 Sl " *
• * * {0 M,M) * * (AC fT) * (KWl * (MWH) * ($/MWH) • SOCIAL *
• GEOG, AREA • * (Sfl,Ml) * (CFS) * (FT) * tKW) * (MWH) • * IMPACT CODE *
••••••*****************************************************************************************************•···~··················
* AK7NPA0.!29 * EAGLE * 56 0,0 * H * S,ll * 0 * 0 * 1199,3 * NNUUUUU *
• I 5 • OUTflil KETCH! EAGLE LAKE * 131 25,0 * IS * 0 * 2000 * 9500 * 12o,24 • *
* SOUTHEAST * uNDEVELOPED * 45 * 443,0• 284,7 * 2000 * 9500 * * UNNUYYYYY *
• * BRADFIELD CANAL A•5, • * * * • * * *
* * * .. * * * * * * • A~7~PA0250 * GRANITE CREEK
• l o • OUTER ~ETC~l
* SOUTHEAST • UNDEVELOPED * . • KETCHIKAN C•!,
• *
* 55 40,0 *
GRANITE CREEK• 130 55.0 *
* 9 *
*
*
•
* * AKoNPA0251 * HIDDEN INLET
* OUTEk KETCHI
* UNDEVELOPEu
LAKE * 54 58,0 *
• I 5
• SOUTHEAST
* IIETCHIKAN A•1.
* * * AKbNPA0252 * HUMPBACK LAKE
* I o * OUTER KETCH!
• SOUTHEAST * UNDEvELOPED
* JUNEAU A•S.
* • AK7NPA0230 * LEDUC
• I b * OIJTE~ KETCH! * SOUTHEAST * ~NOEVELOPED
* * KETCHIKAN 0•3,
* * * AK6NPA0231 * MARTEN ARM LAKE
WATERFALLS CR• 130 22.0 *
• 10 *
* *
* * 55 0.9 •
HUMPBACK CREE• 130 37,9 *
LEDUC RIVER
• 34 *
*
*
* • * 55 51>,0 •
* 130 51.0 *
• 7 *
*
*
* *
• I b • OUTER KETCHI MARTEN LAKE
• 55 a.o • * '"t30 37.0 *
* b * * SOUTHEAST * UNDEVELDPEU
* * KETCH!IIAN A•2
* * AK6N?A0233
• I b
• SOUTHEAST
*
• * PUNCHBOwL LAKE
* OUTER KETCH!
* UNDEVELOPED
• KETCHIKAN C•3
* * .l.!';bNPA0234 * PtJUCHHOt<t.. LAKE
* I 6 * OUTER KETCH!
• SOUTHEAST * uNDEVtLDPED
* • KEfCHI~AN C•3
*
* *
•
* LOviER * 55 30.9 *
Pu~CHBOwL CRE• 130 47.0 •
* 12 *
* • •
* UPPER * 55 26,0 *
PUNCHBOWL CRE• 130 44.0 *
* 3 *
*
*
•
*
H
IS
H
IS
*
* 113.0•
" *
*
* 105,0•
*
*
H *
IS *
H
IS
310,0•
*
* ..
* 84.0•
*
*
H *
IS *
H
IS
H
!S
48,0•
•
*
*
* 153,0•
*
* *
* 37 .o.
*
*
60,0 *
0 *
862.1 *
* •
150.0 *
0 •
299.7 *
*
* 25.0 *
0 *
2S9.7 *
*
* 15.0 •
0 *
1241.0 *
* *
10.0 *
0 * 509.4 •
*
* 21.0 *
0 *
b31.3 •
*
* 35,0 *
0 •
12oo, 1 •
*
0 *
8000 *
8000 *
• • 0 ..
5000 •
5000 *
*
*
0 *
14000 *
14000 *
* • 0 •
14000 *
111000 *
• •
0 *
3500 *
~500 *
* 0 •
15000 *
15000 *
* •
0 *
7000 •
7000 *
* •
0 *
39UOO *
39000 *
*
" 0 •
20000 *
20000 *
* •
0 * &2000 •
oi?OOO *
* * 0 *
o2000 •
62000 *
•
* 0 •
16000 *
16000 *
*
*
0 *
b4.Ho *
o437o *
*
0 •·
31234 *
31234 *
*
*
1534.7
39,353
1852.4
92.o24
2603.4
111.990
199 I , 7
32.124
* * * •
*
* • • ..
* ..
* • •
* •
* • •
* 9oo.35 •
o0,397 •
1861.7
28.'l20
1135.0
3b,3'10
•
*
* .. ..
* * •
* * • •
*
YNUUUUU
UNNUUUUNU
YNUUUUU
UNNUUUUI<U
YNUUUUU
UNNUUUUNU
YNUUUUU
UNNUUUUI<U
YNUUUUU
UNNUUUUUU
YNUUUUU
UNNUUUUUU
YNUUUUU
UNNUUUUUU
*
" * •
* •
*
* •
* •
*
*
*
*
*
* • •
*
*
* .. .. ..
•
*
* ..
•
* ..
* ..
* • .I.K7lliPA0232 * PUNCH60"'L CREEK * 55 31.9 * H * 75.0 * 0 * 0 * 2930.2 * YNUUUUU * * I 6 * OUH.t< KETCHl PUNCHBOWL CR * 130 45,9 * IS * 0 * 15000 * &11000 * 45,785 * *
• SOUTHEAST • UNOEVEi.OPEO * 1Q * 174.0• o21,3 * 15000 * 64000 * * UNNUUUUYU *
• • KETCHIKAN C-3,0•3. * * • * * * * *
····~········································································································k********************
:>
I w
V1
Project Listing (continued)
•*********************************************************************************~***********************************************
SITE ID w P~OJECT NAME * LATITUUE •PkOJ,PURP,• OAM HT * lX!ST,CAP. •EXIST,tNRG•ANUL. COST* ENVl~UNMlNTAL *
* *PRIMARY CO. •NAM~ OF STREAM •LONGITUUE * STATUS •lOT, STOR• INC. CAP, •INC,EtltR6Y•ENE~GY COST• IMPACT COOl *
* OEP
* CODE
ACTV * ONNC:R * DR,i\REA * AVE. Q •Pwll, HO, • TOT, CAP, •TOT .i:.NERGY• * *
JNV • MAP REFERENCE * (0 M,M) * * (FT) * (Kv.) * {~1WH) * { 1000 $) * *
* • (0 M,M) • • (AC FT) * (KW) • {MWH) * ($/MI'iH) * SOCIAL *
* GEGG, AREA * * (SU,Mll • (CFS) • (FT) * (Kw) • (MwH) • * IMPACT CuDE *
*************************************************************************************************************************•******** * AK!NPA0253 • PURPLE LAKE • 55 3,9 * H * 24,0 • 3000 * 10400 * 15';),34 * NNUUuUu *
* I 5 * OUTEr/ KETCHI PURPLE LAKE * 131 1~,9 * OP * 0 * 1400 * 0 * 0 * *
* SOUTHEAST • CITY OF METLAKATLA • 7 • 70,0• 320,0 * qqQO * 2770 * * UNNUUUUUU *
* •KETCH1KANA•5 * * * * * * * *
• AK7NP10235 • REO LAKE
• I b * OuTEA KETCH!
* SOUTHclST • UNDEVELOPED
~ • K~TCH!KAN A•2,
* A~7NPA0236 * RUDYERD
• I 6 * OUTER KETCH!
• SOUTHEAST * UNDEVELOPED
* • KETCHIKAN C•2,
* • AK7NPA0237 * SAKS COVE
* • * 55 8,0 *
R~D R SOCA DE• 130 30,9 *
* 114 *
* • *
* • 55 35.9 *
NONAME MINOR * 130 36,0 *
* 8 *
*
*
•
• 55 58,0 •
• I 5 • OUTEN KETCH! SAKS CREEK * 131 4,9 *
• 22 * * SO~THEAST * UNDEVELOPED
* * KETCHIKAN 0•11,
• •
* AK6NPA0238 • SALMON RIVER
* I S * OUTE~ KETCni
• SOUTHEAST • UNDEvELOPED
*
* •
.. s& 02. •
SALMON RIVER * 130 10.0 •
65
• BRADFIELD CANAL A-1.
• •
*
•
*
* •
• AKbNPA0239 * SH~LUKUM
• I ' • OuT£~ KETCH!
• SOUTHEAST • UNDEVELOPED
• • KETCHIKAN 0•5,
• * A K7 NPA 024 0 * SHORT CREEK
• l b • OUTER KETCH!
• SOUTHEAST • UNUEVELOP£0
* ~5 58.0 •
SHELOKUM CREE•~131 37,9 *
• 17 ..
• •
* • 56 0,0 *
R~FLECT!ON LA• 131 30,9 *
* 1 9 • * dRAOF!ELO CANAL A•5 •
*
•
* 9,0 *
3,9 •
* AK7NPA0241
• l b
* SOUTHEAST
•
*
* • SPUR
• OUTEI< KETCHI
• UNOEVELOPEU
• SwAOFifLO CANAL
• * AKbNPA0212 • ~ILSU~ RIVER
* I 5 * JuT£~ KETCH!
• SOUTHEAST • uNDEVELOPED
* KETCHIKAN 8-2.
• so
NONAME MINOR * 131
A•ll, *
* •
111 *
* * 58 28.0
WlLSON RIVER • 130 37,0 *
• 7 0 ..
• •
H
IS
H
IS
•
566,0•
•
*
* •
87,0•
•
H *
lS *
207,0•
• ..
H *
IS *
•8o6,3•
•
H *
IS •
H
IS
H
IS
21o,O•
• •
•
211>.0•
•
•
115,0•
•
H *
IS
773,0•
~
* 165,0 •
0 •
346,b ..
* * 5,0 •
0 •
1673,3 *
• •
125,0 *
0 *
1)20,3 •
•
* 50,0 •
0 *
59,9 •
*
* 40,0 •
87000 •
349,6 •
•
45,0 •
61>000 •
32'1.b •
•
* 25,0 •
u •
17oo,o •
!70.v •
I) •
165.8 •
* 0 •
2'1000 •
24000 •
* •
0 •
19000 •
19000 •
•
0 •
15000 •
15000 •
•
* 0 •
8000 •
8000 *
*
* 0
10000 •
10000 •
•
•
0 •
10000 •
10000 *
0 ..
2401.10 •
2'1000 •
*
*
0 *
15000 •
150110 •
•
•
0 *
104000 *
104000 •
*
0 *
83000 •
83000 •
*
0 •
72000 *
72000 •
•
0 *
]4b00 •
34b0\i •
0 *
50331 *
50.B1 •
*
0 •
'lb739 *
46739 •
0 •
105000 "
105000 *
•
0 *
71000 •
71000 •
•
4033,5
38,784
2211!>,7
21, ae·
s5.sa.s
76,923
21'15,'1
b3,'151
20v2.q
39,785
2251,2
48,11>5
2108,7
20, 83
55&5,0
711.381
• • • •
* • • • ..
•
*
*
* • • •
* •
*
* •
* •
*
* • •
* •
* • • •
*
*
* • •
YNUUUUU
UNNUUUUI';U
YNUUUUU
UNNUUUUUU
YNUUUUU
UNNUUuUNU
NNUuUUU
UNNUYYYI'<Y
NNUUUUU
UNNUYVYNY
NNUUUUU
UJIINUYYYNY
YNUUUUU
UNNUUUUYU
YNUIJUUU
UNNUUUUYU
*
*
* •
" •
* •
*
• •
*
* • •
*
* • • •
* •
*
* •
•
* •
* •
* •
* • • •
•••*••••***********************•*****w*************•••****************************************************************************
:r
VJ
0'
Project Listing(contlnued)
*************************************************•******************************************************************************** * SITE ID * P~OJECT NAME * LATITUDE •PROJ.PURP,• DAM HT * EX1ST,CAP, •EXIST,tNNG*ANUL. COST * ENVlRUNMENTAL *
• • PRIMARY CO, -NAME OF STREAM •LONGITUDE * STATUS •TOT, STOR• INC, CAP, *INC,I:.NtRGY•ENENGY COST• IMP,CT CODE *
• DEP ACTV * OV~NI:.R • IJFl,ANEA * AVE, 0 •PWf.l. HD. • TOT, CAP, •lOT ,ti~ERGY• * "
• CODE !NV • MAP NEFERENCE * (D M,MJ * * (FT) * (KI'i) * (MWH) • (1000 $) * *
• * * (0 M.M) * * (At FT) * (K"') * (MO\H) * ($/MWH) * SOCIAL *
• GEOG, AREA * * (SQ.~ll) * (CFS) * (FT) * (KW) * (M,..H) * • IMPACT CODE •
****************************************************************************************************•••···························
• AK7•H'A02Q3 * WINSTANLEY * 55 24,2 * H * 50,0 * 0 * 0 * 147&,6 * YNUUUUU *
• I 5 • OUTEN KETCH! i'IINSTANLEY CR• 130 52,5 * IS • 0 * 5000 * 24140 * 1>1,170 • *
• SOUTHEAST * U."\IOEVELOP£1.1 * 13 * -105,1• 344.o • 5000 * 24140 • * UNNUUUUVU •
* •KETCHII'.ANS-3, * * * * * * * *
* .. * ~ AK7~PA0104 * BLACK BEAR LAKE
• I 2 • PRINCE UF WA BLACK
* ':I& 3i!.9 •
SEAR CR• 132 0,5 •
• SOUTHEAST • UNDEV~~OPEO
* * CRAIG C•l
* • 4K7NPA0268 * KEGAN CREEK
* 1 S * PRINCE OF rlA
* SOUTHE4ST • UNDEVELOPED
• CRAIG A-1.
* * AK7NPA02&9 • KLAKAS LAKE
* I 5 • PRiNCE OF rlA
• SOUTHEAST * UNDEVELOPED
• * AKbi\IPA0271
• I 5
SOUTHEAST
*
• .I.K7NPA0395
* I c * SOUTHEAST
* * AKPNPA0272
* CRAIG A-1,
* * KUGEL LAKE
• PRINCE OF rlA
* UNDEVELOPED * CRAIG A•1,
* LAKE MARY
* PRINCE OF wA
• UIIIOEVELOPED
• CRAIG 8•2
* LINKUM
KEGAN CREEK
UNNAMED
KUGEL CREEK
* 1 * • ..
• 55
* 132
*
*
*
*
* 1.1 •
9,2 •
9 * • • * 55 o.o •
* 132 22.9 *
• 11 *
• *
* * * 55 1.9 *
* 132 15.0 •
* 8 *
* • * ..
" ss 2o. o •
OLD Ff.IANKS CR~ 132 29.0 •
• 27 * •
*
*
* 55 31.7 *
• I b * ~WINCE Or WA LINKUM CR KAS• 13? 23,9 •
• SOUTHEAST
• .lK6~PA0254
* I 5 * SOUhtE.lS T
• •
• PACIFIC AMERICAN FISH
• CRAIG C-2
* LUCK LAKE
• PRINCE OF wA
* uNDEVELOPED
* CRAIG
EAGL£ CREEK
* 1 *
*
* • 55 57,0 *
• 132 42.9 *
* 23 •
* • •
H
IS • •
I 3. 5•
*
*
H *
IS *
•'19,8•
* *
H *
IS •
130, O• .. ..
H *
IS •
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IS
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OP
70,0•
*
*
2'10,0•
•
*
* IO.O•
*
H *
IS *
200.0•
*
*
* zs.o •
6900 *
14511.5 *
* * 20,0 *
0 •
109,8 *
*
* so.o *
0 *
119.8 ..
* * 40,0 *
0 *
42&,5 *
*
* 30,0 *
95000 •
2&4.7 *
•
* 7,0 *
0 *
300,0 *
• •
120.0 •
0 * 119.11 •
*
*
* 0 •
5000 *
5000 * • •
0 *
1300 *
1300 * • •
0 *
2000 *
2000 •
•
*
0 *
4000 *
4000 •
•
* 0 *
9oOO *
'1&00 •
*
* 17 •
4543 *
45b0 * •
*
0 *
3000 *
.sooo *
*
*
•
0 *
22000 •
22uoo •
*
0 *
5&00 *
SciiO •
*
0 *
10UOii •
10000 *
* •
0 •
19000 *
19000 •
* • 0 •
42300 *
42300 *
* * 45 *
8872 *
8917 *
*
*
0 *
15000 *
15000 *
*
*
97o. 9
44.367
940.92
1&8, 2
*
* •
*
" *
*
* *
* * 999,88 •
99.988 *
* *
* 9"4&,88 •
49,'l41 *
•
* • 210b.9
49,1109
'192.89
55.551
2245.2
1'19.o&
*
*
* *
*
*
*
* * •
* *
*
YNNYYNN
UNNNYUUYY
YI;UUUUU
UNNUUUUIIIU
NIWUUUU
UNNUUUUUU
NNUUUUU
UNNUUUUUU
Nr>IUUUUU
UNNUUUUUU
NNUUUUU
UNNUUUUUU
NNUUUUU
UNNUUUUUU
•
*
*
*
* ..
*
*
*
*
*
*
* •
* •
* ..
*
* •
" *
*
*
*
* •
*
* • ..
*
* • * AK7NPA02SS • MELLEN LAKE * 55 12.0 * H * 35.0 * 0 * 0 * 1250,4 * NNUUUUU * * I 2 *PRINCE OF ;;A REYNOLDS CREE• 132 .S&.O * IS * 0 * 8000 * 30000 * 41.b82 • •
* SOUTHEAST * UNDEvELOPED * b * &2.0• 1164,1 * oOOO * 30000 * * UNNUUUUUU •
• • SITKA 0•3, • • * * * * * .,
*•********************************************************************************************************************************
if w
'-1
Project listing(continued)
****************************************************************************************************************•***************** * SITE 10 * PROJECT NAME • LATITUDE •PROJ.PURP.• DAM HT * tXIST.CAP. •EXlSf.tNHG•ANUL. CUST * ENVIRUNMENTAL •
* PRIMARY CO. •NAME UF STREAM •LONGITUJE * STATUS •TOT. STOA• INC. CA~. •INC.lNtRGY*ENERGY C05T• IMPACT CUDE *
• OEP ACTV * O~NEN • OR.AREA • AVE. Q •PwR. HO. * TOT. CAP. •TOT.tNEHbY*
• CuDE lNV • i'IAP REFERENCE * (0 ~I.M) * * (~T) • (KO'i) * (MIIH) * ( 1000 $)
* • (D M.Ml • * (AC fT) • (K"') * lMIH1) * ($/M'i!Hl * SOCIAL
• GEOG. AREA • * (~Hl.Ml) • (CFS) * (FT) * (K") * (M,~H) * • l,~PACT CUOE *
············································································································~·············~······· • A~7NPII(l25c • MYRTLE CREEK * 55 4.3 • H • 21.0 * 0 * 0 * i>09.9c * NNUUUUU *
* I 5 • PRINCE OF I¥A MYRTLE CREEK • 132 3.8 * IS • 0 • 1200 * 5700 * 107. 1 * "
* SOUTHEAST • UNDEVELOPED * 4 • 7b.O• 111.8 • 1200 * '5700 * * UNNuUUUUU *
• CR~IG A•1 • * * * • * * * • * • AK7NPA0257 • ~ECK ISLAND LAKE * 56 S.'l
7.9 •
18 * •
*
* ! 5 • PRI~CE OF NA NlCK ISLAND L• 133
? SOUTHEAST • Uf;DE VELllPED *
. • PEfERSdu~G A•Q *
* •
• AK7NP40258 • NIBLACK LAKE
* I 5 * PRINCE OF ~A
• SOUTHE~ST * UNUEVELOPEO
* * CRAIG A•1
• AK7NPA0259 • REYNOLDS CREEK
~ l 5 * PRlNCE OF ~~
• SOUTHEAST • u~OEVELO~Eu
• CRAIG A•2.
• * AKbNPA0260 • SALMUN LAKE
* I 5 * PRINCE OF WA
• SOUTHEAST * JNOEVfLOPED
• C~AI" C-2.
* AKbNPA02c1 • SH!PLfY LAKE
* * 55
MYRTLE CREEK • 132
•
*
4.9
7.9.
:s
•
* • 55 14. 0 •
RtYNOLDS CREE• !32 34.9 *
* •
7 •
• * 55 32.9 •
KART4 RIVER * 132 33.9 *
• 4d •
* * • 56 4.9
• l 5 * PRINCE OF NA UNNAMtD ;; 133 30.0
* SOUTHEAST • UNDEVELOPED
• PETEHS~URG A•6.
* • AX7NPA0262 * SUKKNAN LIKE
• l 5 * P~I~CE OF ~~
• SDUTHEAST * U~U£VELOPED
* CRAI~ A·3.
* •
b
* • 55 2. 3 *
SUKKNAN LAKE * 132 45,3 *
* 7 *
* • *
H
rs
H
IS
H
rs
H
IS
*
* •
170.0•
*
* •
64.0•
* ..
*
* 75.0•
*
* 459,0•
•
H *
IS
cB.O•
* H
IS *
-36.3•
* * AK6~PA02c3 * 3uMM!T LAKE * 55 34.9 * H * ! 5 • PRJ~CE OF ~~
• SOUThEAST • UNiJEVELOPED
* CRAIG B•i:
• AK7NPA0i61l * THORNE
• I 5 • PRJ~Cc OF ~~
• SOUTHEAST • UNJEvELOPEU
• CRAIG C•2,
SUMMIT LAKE • 132 33.9 * IS *
* 4 • 37.0•
*
* * • 55 112.0 *
THOH~E NIVER • 132 37.9 *
lb6 *
*
•
H *
IS •
1516.0•
*
55.0 •
0 *
119,1:; *
s.o •
0 * 293.7 •
•
20.0 •
0 *
114.<> •
* 43.0 •
0 •
89.9 *
* * '15.0 *
0 •
109,6 •
40.0 *
0 *
409.S •
20.0 *
0 *
392.& *
* 25.0 •
0 *
102.8 •
*
*
0 *
3000 •
:sovo •
•
0 *
3000 ..
3000 *
*
0 *
11000 *
11000 •
•
0 •
6000 *
6000 •
•
0 •
1200 •
1200 •
*
* 0 •
2300 •
2300 *
" *
0 *
2000 •
2000 •
* * 0 •
17000 •
17000 *
*
0 •
135au •
13580 •
*
0 *
12526 •
12526 *
•
0 *
S4u00 •
54000 •
•
*
0 *
27500 "
27500 •
* •
0 •
4'179 *
4979 *
• •
0 *
10000 *
10001! •
*
0 •
9680 *
91>80 •
•
0 •
80000 •
80000 *
1442.2
l09.b8
825.14
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*
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* •
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*
* •
*
*
*
*
*
**********~********•*****************•******************************************************************************************•*
:r w co
Project Listing(continued)
**********************************************************************************************************************************
* SITE IO * PROJECT NAME *LATITUDE •PROJ.PURP.• OAM Hi * EXIST.CAP. •EXIST.tNRG•ANUL. COST * ENVIRONMENTAL *
* • PRIMARY CO. •NAME OF STREAM *LONGITUDE * STATUS •Tot. S70R• INC. CAP. •INC.ENEAGY•ENENGY COST• IMPACT CODE ~
* OEP ACh' * Q..,NE.R * OR.AREA * AVE. Q •PWR. HO. • TOT. CAP. •TOT .ENERGY• • ~
• CODE HlV • MAP REFERENCE * (0 M.M) * * CFTJ * (K..,l * (MtjH) * (1000 S) * * * • * (D M.M) * * (AC FT) * (KW) * (Mf<H) • ($/Ml'!H) * SOCIAL *
* GEOG. AREA * * (SO.Ml) * (CFS) * (FT) * (KWJ * (MriH) * * IMPACT COO£ *
*******•*****•****************•**************************************************************************************************w
• A!<7NPA02b5 • viATERFALL LAI(E * 54 58.2 * H * 3o.O * 0 * 0 * 59<!.57 * NNUUUUU * * I S • PRINCE OF tiA .-.ATERFALL LAK* 133 b.O * IS • 0 * 2000 * 990<! • t>0.413 * •
• SOUTHEAST • UNOEVELOPEO * 3 * •16.3• 499.5 * 2000 * 9908 • • UNNuuuuuU
* * OUON ENTRANCE 0•4, • * * • * * • *
* • * * • * * * * * * AK7NPA026b * ~EIGLE LAKE
* l 5 * PRINCE OF WA * SOUTHEAST * uNDE~ELOPEO
* •
* CRAlu A-1.
*
WEIGLE LAKE
* 55 3,9 * H
• 132 11.11 • IS
• 5 •
* •
..
*
•
* 35.0•
• ..
* AKINPA0285 • COOPER LAKE DAM * 60 2b.O * H •
* I 4 • SE~ARO COOPER CREEK • 149 49,1 * OP *
• SO CENTRAL • CHU~ACH ELECTRIC ASSOC. * 31 *********•0*
* • SEiiARO B-8 * * *
• • * AK7NPA0273 • CRESCENT LAKE
* I S • SEhARO
* SO CENTRAL * UN0EVEL0PEO
* * SE..,ARO 6•7,
~ * * AK7NPA0274 * GRANT LAKE
• l 5 * SE~ARO
• SO CENTRAL * UNUEVELOPEO * SEt<ARO B-7
* • * AKbNPA0~75 * JUNEAU
• I 5 • &ENARO
* SO CENTRAL * UNDEVELOPED
* • SE~ARO C•8
* • * AK6NPA027b * KENAI LAKE
* 0 5 • SE,.ARO
• SO CENTRAL * UNDEVELOPED
* • SEiiA~D ~-8,
* * • A~6NPA0277 * LOST LAKE
* I 5 * SEWARD * SO CENTRAL • UNDEVELOPED
* * SEwARD A-7.
• *
* ..
2 • 60 40.0 *
CRESCENT LAKE• 149 29,0 *
GRANT LAKE
* 23 *
* *
* * • bO 28.0 * * 14'1 21,0 ..
• 44 *
*
*
*
* * 60 29.11 *
JUNEAU CREEK * 1~9 54.0 •
KENAI R!VfR
LOST CREEK
* so • •
60 211.0 *
* 1119 37,0 *
o60 •
* • * * 60 15.9 *
* 149 22.0 •
* 7 * •
*
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* AKbNPA0279 * NELLIE JUAN RIVE~ * 60 27.0 * H * 195.0 * 0 * 0 * 4048.3 * NNUUUUU *
* I 5 • SE~ARO NeLLIE JUAN R• 1118 47,0 * IS * 230000 * 10000 * 47000 • 8b,l35 * •
• SO CfNTRAL • UNDEVELOPED * 130 * 977.0• 239.7 * 10000 * 47000 * * UNNUUUUNU •
* • SEIIARO 8•5. * * w * * * * *
**•**********····························••****•••****************************************************************•••••••••*******
;l>
I w
1.0
Project Listing(continued)
*************************************************•********************************************************************************
SITE lD * PROJECT NAME * LATITUDE •PROJ,PURP,• QAM Hf * EXISI,CAP, •EXIST,ENNG•ANOL, COST * ENVIRONMENTAL
*PRIMARY CO, •NAME OF STREAM •LONGITUDE • STATUS •TOT, STOR• INC, CAP, •INC.ENfRGY•ENERGY COST• IMPACT CODE
* DEP ACTV * O~NER * OR,AREA * AVE, U •PwR. HO, • TOT, CAP, •TOT.ENcRGY• *
• CODE IN\1 • MAP REFERENCE * (D M,M) * * (FT) * (K"'l • (H..,H) * (1000 ~) *
* * * (0 M,M) * * (AC FT) * (KW) * (MI<H) * (:11/MilH)
* GEOG. !.REA * • (Sil,IH) * (CFS) • (FT) * (K~I) • (M>'IH) *
SOCIAL
IMPACT CUOE
*
*
" *
*
···~···········································································································~·················· * AK7N~A0271 * NELLIE JUAN RIVEN U~PEN * bU 2•.u * H • ~U,U * 0 • 0 • jU.q,S * NNUUUUU *
* I 5 * SfriAMD NELLIE JUAN A• l4a qq,q * IS • 120000 • 12000 • 5700U • ~3.500 * *
* SO CENHHL • UNUEVELOPEO • 35 • 2b2.0• 420,':> * 12000 • 57000 • * UNNUYYYNY
* • SE>'lARO B•b, • * • * * * * * • • * * A~7NPA0280 • PTARMIGAN LA~E PrtOJECT • bO 15,0
CI<E• 14q 11.' •
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IS
•
*
* * E 5 * SEI<ANU PTARMIGAN
• SO CENTR•L * UNUEVELOPED
• SEI<AkD Bb,7
*
* 30 •
•
*
•
*
138,0•
* • • ~K6NPA0281 • RESURRECTION RIVER • bO 51,q • H
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• SO CENTRAL • UN0EVELOPED
* * SE..,AkD A•7, •
• AK7NPA0283 • SNO"'
• I 2 * SE~ARO
* SO CENTRAL • UNDEVELOPED
* * SEWARD 6•7, • • AKbNPAD284 • SUNRISE LAKE
* I 5 * SE~<AkO
* 50 CENTRAL • UNDEVELOPED
* • SENA~D 0·7.
• * AK7NPA0313 • ANDEAN LAK~
• I 5 • SlT~A
* SOUTHEAST * UNDEVELOPED
• PORT ALEXANDER
• AK7NPA03lQ • ANTLER LAKE
• I b • SITKA
* SOUTHEAST • UNDEVELOPED
* JU;~f:AU 0-3,
• * U7NPA0315
• I 5
• SOUTHEAST
* AK71<PA03lb
• 1 b
• SJUTH£AST
•
• I:IARANOF LAKE
* SITKA
• UNDEVELOPED
• SITKA A~3.
* • BATURIN LAKE
* SITKA * UI;DE 1/ELOPEO
* PONT ALEXANDER
R~SURRECTION * 14q 41,q •
• 141 • 828,0•
• • * * bO 17,9 * H *
51\10111 ><IVER • 14~ 18,0 • IS •
85 • 710,0•
• •
* •
• bO 51,9 •
SIXMILE CREEK• 149 2b,q •
.. 238 *
• • *
* • So 18.9 •
ANDEAN CREEK * l34 47.2 •
2 •
B-3. • • • •
• 58 4&,, •
ANTLER RIVER * 134 30,0 *
* 5 •
*
• 57 '·0 •
BARANOF RIVER• 134 52,q •
32 *
* • •
• 56 24,0 *
BATURIN CREEK• 134 48,0 *
3
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* •
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•
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•
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•
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•
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10.483
*
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*
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•
* •
*
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*
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* •
······················*****•*****************K********************•****************************~********************************•*
:r .p.
0
Project Listing( continued)
*******************************************************************************************************************************~ * SITE IO * PROJECT NAME * LATITUDE •PROJ.PURP,• DAM HT • EXIST.CAP, •EXIST,ENNG•ANUL, COST * ENVIRONMENTAL •
* *PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •TOT, STOR• INC, CAP, •INC.~NtRGY•ENE~GY COST• IMPACT CODE *
* OEP ACTV * 011NER * Dll,AREA * AVE, Q •PwR, hD, * TOT. CAP, •TOT ,ENERGY* * *
* CODE lNV * MAP REFERENCE * (0 M,M) * * (fT) * (KW) * (MWH) * (1000 Sl * * * * w (0 M,M) * * (AC FT) * (rOi) * (MI'iH) * ($/MWH) w SOCHL *
* GEOG, AREA * * (SQ,MI) * (CFS) * (FT) * (KW) * (MWH) * * IMPAI.:T CODE *
••••******************************************************************************************************************************
* .lo.KbNPA0317 * BENZEMAN LAKE * So 45,0 * H * 30,0 * 0 * il * 27o2,7 * NNUNUUU *
* I 5 * SITKA 6ENZEMAN RIVE• 135 0,0 * IS * 0 * lb323 * 27b95 * 99, 75t. * *
* SOUTHEAST * UNDEVELOPED * 32 * 400,0• 103,8 * b323 * 27695 * * UNNUUUUUU *
* * POilT ALEXANDER 0•4, * * * * * * * •
* * AK6NPA03!8
* 1 5 * SOUTHEAST
*
*
* * BLANCHARD LAKE
* SITKA
* UNDEVELOPED
* PORT ALEXANDER
* * AKINPA0339 * BLUE LAKE DAM
• I 4 * SITKA
• SOUTHEAST * CITY OF SITKA
• SITKA A•2
* * AK7NP.A0319
• I Z * SOUTHEAST
•
*
* * SOkODINO LAKE
* SITKA * UNDE\IELOPEll
* PONT ALEXANDER
* IK7NP.A0320 * BRENT~OOO CREEK
* * * 56 3o, 9 *
BLANCHARD CRE• 134 40.0 *
c-3. * 3 *
*
* * * * 57 3. 7 *
SA~MlLL CREEK• 135 11,4 *
* 38 *
*
*
*
* • Sb 22,3 *
BIG PORT ~ALT• 13U 42,9 *
8·3.
.. 3 *
* *
*
*
* I 6 • ~ITKA B~ENTWOOO
* 5b 31.3 *
CRE• 134 UO,O •
* SOUTHEAST * ~HOEVELOPEO
• • PORT ALEXANDER C•3,
* * * AK7NPA0321 * CARBON LAKE
• I 2 * SIT~A UNNAMED
• SOUTHEAST * UNDEVELOPED
* SITKA A•3,
* • AK7~PA0322 * CLIFF LA~E
• 1 5 * SITKA UNNAMED
• SOUTHEAST * UNDEVELOPED * PORT ALEXANDER C•3,
* 7 *
* *
*
* * 57 1.9 * * l3U 28,1 *
* 2'f *
* *
* * .. 51> 31,9 *
* 134 45,9 *
* 6 *
*
*
* * • 4K7UPA2o0b • DAVIUOF LAKE
• I 5 * SITKA
* 56 31>,3 *
OA\IIDOF CREEK* 134 50,2 •
• SOUTHEAST • UNDEVELOPED
* PO~T ALEXANDER C•3,
* • AK7NP~2b09 * DEEP LAKE
• I 5 * SITKA DEEP CREEK
• SOUTHEAST • UNDEVELOPED * * POkT ALEXANDER 0•3.
* II *
* *
* * • so 51.3 •
* 134 44.0 *
* 7 *
* *
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IS
*
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0 *
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* 170,0 *
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*
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*
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*
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* * 20,0 *
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0 *
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*
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*
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*
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* * •
* •
*
* * *
* ··~·***************************************************************************************************************••*************
~
+:-......
Project Listing(continued )
********************************************************************~************************************************************* * SITE 10 * PNOJECT NAME * LAIITUUE •PHuJ,PUNP,• DAM HT * EXIST,CAP, •lXIST,ENNG•ANUL. CUSI * ENVIHUNMENTAL
* * PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •JOT. STOR• INC, CAP, •INC.ENERGY•ENENGY COST• IMPACT CODE
* OEP ACTl/ * Ofir.f.H • Qk,Af<EA • AVE, U tf'o'IR, HO, * TOT, CAP, •TOT ,t:r.t:t<GY• *
• CODE !NV * ~AP REFEkENCE • (0 M,M) • • (FT) • (~Wl • (M~H) • l1000 $) •
* * • (D M,M) * • (AC FT) * (KW) * (MWH) * ($/MI'<H) * GEOG. AI-lEA • • (SO.MI) • (CfS) • (fT) • (l(>'i) • (M..,H) • *
SOCIAL
IMPACT CODE
• •
•
··~·~-·-··········~···•***********************************************•*********************************************************** * AK7NPA0323 • DEER LAKE • 56 ~1.7 * H • 40,0 • 0 * U • 1770,7 * N~UUUUU *
* I 5 * SIT~A UNNAMED PARAN• 134 40,0 * IS • 0 * 7000 * 31000 • 57,120 * *
* SOUTHEAST * UNDEVELOPED * 7 * 160,0• 338,6 * 7000 • 31000 * * UNNUUUUUU *
* PORT ALEXANDER C•3 * * * * * • * • * * • ..
• AK7NPA032S * OI,NA LAKE * 56 53,0 * H
* I 2 * SITKA UNNAMED * 135 3,0 * IS •
• SOUTHEAST • UNDEVELOPED * 4 * 36.0. * PO~T ALEKA~DER D-4, * •
* AK7NPA0326 * OIDR!CKSUN LAKE * • 57 115,0 • * I 5 • SIT~A DlDRICKSON L'* l3u 11.0 •
• SOUTHEAST • UNDE~ELDPED
•
• AK7NPA03Z7
" I b
• SOUTrit.AST
*
• SITKA C•S.
* fli<GER LAKE
* SITKA
* UNi.JE.VELOf'EO
* PORT ALEXANDER
• 15
•
* * • 56 36,1
FlNGER CREEK • 134 41,3 *
2 •
C•3,
• •
* • AK7NPA0326 * FOUR fALLS LAKE • 57 1,9 •
* l 5 • SITKA UNNAMED • 134 45,9 •
1 • * SOUTHEAST * U~DEVELOPEO
•
• A~7>;PA0329
• E 5 * SQUTHEASi
•
• SITKA A-3,
• * I'Ui<UHE:LM
* SITKA
• U~WfvELOPED
* PORT ALE XANOER
* AK7NPA0330 • GOULDING LAKE
• E 5 • SITKA * SOUTHEAST • UNi.JEVELOPED
• SITo<.A 0·7
• AK7NPA0331 • GOULDING LAKE
• E 5 * ~ITo<.A
* SOUTHEAST • uNUEVELOPED
• SITKA 0•6,
•
• AK7~PA0332 • GREEN LAKE
• I 2 • SITKA
• 5~JTHEAST • UNDEVELOPED
* PGr<T ALf.XANDER
•
• 56 23,0 •
FURUHELM RIVE~ 134 48,0 *
16 •
8•3, •
*
* • LO~E~ • 57 qb,9 *
GOULDING LAKE• 136 14,0 *
27 *
* UPPER * 57 ~8.3 *
GOULDING LAKE• 13b 12:,9 *
25
* 56 95,30 *
VODOPAD RIVER• 135 11,&0•
2o
D-4
H
IS
H
IS
*
•
180,0•
*
* •25,'h
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23,0•
•
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2()0,0•
•
* •
340,0•
•
* 270.0•
*
* •
291.0•
* 5,0 •
0 •
1473,5 •
•
36.0 •
0 •
119,8 *
* •
40,0 •
0 •
73'1,2 *
*
* t~:.,o *
16500 *
LS48,b •
25.0 •
0 •
99,9 •
•
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914,21
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****•************************************•***********************•**********************•**************•**************************
:r
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Project Listing(continued)
**********************************************************************************************************************************
SITE 10 * PROJECT NAMt * LATITUUE •PROJ,PURP.• OAM HT * tXIST.CAP, •~XIST.tNRG•ANUL. COST * ENVIRONMENTAL *
* * PRIMARY CO. ·NAME OF STREAM •LONGITUDE * STATUS •TOT, STOR• INC. CAP. *INc.~NSNGY•ENERGY COST• IMPACT COOt *
• OEP
* CODE
ACTv * OI'INER * OR,Af.IEA * AVE, a •PWR. HD, * TOT. CAP, •TOT .ENERGY* * *
IN\1 * MAP REFERENCE * (0 M,MJ * * (FT) * CKW) * (MI'IH) * (1000 li) * *
* * (0 M,M) * * (AC FT) * (KI'I) * (M.-;r1) * (li/M>'tH) * SOCIAL
* GEOG, AREA * * (SQ,Ml) * (CFS) * (FT) • (KW) * (MWH) * • IMPACT COOl:. ..
*******************************************************************************************************************•**************
* AK&NPA0333 * HIDDEN FALLS LAKES * 57 13,0 * H * '5,0 * 0 * 0 * 1Q34,5 * NNUUUUU * * I & * SITKA UNNAMED CREEK• 134 52,9 * lS * 0 * 3000 * 3&277 * 19.'543 * *
• SOUTHEAST • <.HIOEVELOPEO * 8 * •105.9• 49Q.~ * 8000 * 51:.211 * * UNNUUUUUU •
* * SITKA A•.5. * * * * * * * *
* * AK6NPA0334 * HIDDEN FALLS
• D & * SITKA
* SOUTHEAST * uNDEVELOPED * SITKA A•3.
*
LAKE UPPER
UNNAMt.O
.. •
• S7 13.0 •
* 134 52,9 *
2 •
*
*
* • * 4K7NPA0335 * KASNYKU LAKE
* 1 2 * SlT~A
• 57 11.0 *
KASNYKU FALLS• 134 49,9 *
• SOUTHE4ST • UNDEVELOPED
* • SITKA A•3,
• • * AK7NPA033b * KELP
* I '5 * SITKA UNI'iAMEO
• SOUTHEAST * UNDEVELOPED * * SITKA ~.q,
* * • 4~7NPA0337 • LAKE EK4TERINA
* I 5 * SITKA UNNAMED * SOUTHEAST * UNDE~ELOPED * • PURT ALEXANDER 0•4,
• • * AKbNPA0289 * LAKE IRINA * I 5 * SITKA UNNAMED
• SOUTHEAST * UNDEVELOPED
* .I.K7NPA02'1l
* I 2 * SOUTHEAST
• * AK7NPA0294
• I 2 * SOUTHEAST •
• POKT A~EXANOER 0•4
* ~AKSOUTOF RIVER
• SITKA MAKSOUTOF
* ut<OE VEI..OPED
• PORT ALEXANDER C•3.
• MILK LAKE
* SITKA * UNDEVELOPED
• PO!lT ALEXANDER
•
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*
*
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* '57 20,9 * * 13S 4,9 •
• 21 •
•
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* • Sf> 58,0 * * 134 47,0 *
• 11 *
* • * • * U7NPA0295
* I '5 * SOUTHE.4ST
• NAKVASSIN LAKE
* SITKA
• so 27.o •
NAKVASSIN CRE• 134 44,0 *
* UNDEVELOPED * 4 * • * PORT 4LEXANOER 8•3 • •
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H
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* ******•********************•*****************************************************************************•*****************~******
:J>
I
-1>-w
Project Listing(continued)
*************************•*************************************************************************************************•****** * SITE 10 * PROJECT NA~lE • LATITUDE •PROJ.PURP,• DAM HT • EXIST,CAP, •EXIST,EN~G•ANUL, CuST * ENVIRONMENTAL *
* DEP
• CODE
•
• PRIMARY CO, •NAME OF STREAM •LONGITUDE • STATUS •TOT, STOR• INC, CAP, •INC,ENERGYoENE~GY COST• IMPACT CODE
ACTV * O~NER • DR,AREA • AVE. U •PwR. HO, * TOT, CAP, •TOf,ENERGY• *
WV * MAP REFERENCE • W M,M) • • (FT) • (Kw) * (r~o'IH) • (1000 $) *
• (D M,M) * * (AC FT) * (KW) • lMViH) • ($/Mi'oH) *
* GEOG, AREA • • (SQ,MI) • (CFS) • (FT) • (KW) * (MWH) *
SOCIAL
IMPACT CODE
•
•
****************************************************************•***************************************************************** * AKb.;PA02'lo • l'lELS(Jr; LAKE * 5b Sb,O * H * 4(1,0 * 0 * 0 • 1178,7 * I;NUUUUU *
• I b * SITKA UNNAMED • 134 45,0 * IS • 35000 * ~bOO * 24800 * 47,529 * *
* SOUTHEAST * u:JOEVELOPED * b * 85,0• 113'l,S • SbOO * 2'1800 • * UNNUUUUUU
• PORT AL~XANDER 0·3 • • • • * * * * • * AK7NPA0297
•·I 5 * SOUTHEAST
•
• * OSPREY LA~E
* SITKA
• UtiOEVELOPEO
* POr<T ALEXANDER
* * AK7NPA0291l • PARRY LAKE
• • • 56 24,0 *
NE~ PORT WALT• 134 40,0 *
* 2 * 6•2
* • 56 39,0 •
H
IS
H
•
55,2•
*
* I b * SITo<A PARRY CREEK * 134 4!,0 *
* () *
*
IS • * SOUTHEAST • UNDEVELOPED * • PORT ALEXANDER C•3
•
* AK&NPA0299 • PAlTERSON
* I 5 • SITKA
* SOUTHEAST • UNDEvE~OPEO
* • SIT~A C•b
• • • AKINPA0346 • PELICAN CREEK
* I 2 • SITKA
*SOUTHEAST •'PELICAN UTIL.
* SITKA 0•7
* • AK7NP40300 * PLUTNI~OF LlKE
•
• 57 38,0 •
PATTERSON LAK• 135 48,0 *
5
•
*
• • * 57 34.7 •
PELICAN CREEK• 13& 7,8 •
co. • 12
• •
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IS
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OP
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• •
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•
* • •
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• Sb 311,'l *
• ~ 134 s 7. 9 • IS •
• SOUTHEAST • U~UEVELOPED
• PORT ALEXANDER C•3
• AKbNPA0)03 • POINT SULLIVAN
* I b * SITKA UNNAMED
• SOUTHEAST • UNDEVELOPED
• PORT ALE~ANOE~ C•Z •
• AK7NPA0302 • PORT ARMSTRONG
* 20
* * • So 41,0 * H
• 134 19,9 • IS
1
• •
• 51:> 17. 5
• I 5 • SITKA SHECKLEY CREE• 13'1 39,4 •
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IS
• SOUTHEAST * UNUEVELD~EO * 7 * * PD~T ALEXANDER ll-2. • •
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* • * AK7NPA0292 * PULP MILL * 57 !,3 • H * 30,0 * () * 0 • b81!,'1S • NNUUUUU *
* I 5 * SITKA MEDVETCHA • 135 7,0 • IS * 0 • 1500 • 7400 * 93,101 * * * SOUTHEAST *UNDEVELOPED • 7 * •52,'1• 209,7 • 1500 * 7400 • * UNNUUUUUU *
* Slfo<A A•3 * * • * * * * *
········································································••********************************************•****••••···
~
""" """
Project Llsting(continued)
••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••
• SITE IO * P~uJECT NAME *LATITUDE •PROJ,PU~P.• DAM HT • EXlST,CAP. •EXlST.lN~GtANUL. CuST * ENVIRONMENTAL *
* * PRIMARY CD. •NAME OF STREAM *LONGITUDE * STATUS ~TOT, STOR• INC, CAP, •INC,ENE~iY•ENfRGY COST• IMPACT COOf *
* OEP ACT\/ * Or;NER * OR,AREA * AVE, Q •PwR, HO, * TOT, CAP, •TOT ,ENt:.RGY•. * *
* CODE Itl\1 • MAP REFERENCE * (D M,M) * * (fl) * (KN) * (Mt'IHJ * (1000 S) * *
• * • (0 M,M) * * (AC FT) * (Kill) * (MWH) * (~/MIIH) * SOCIAL * * GEOG, AREA * * (Stl,MI) * (CFS) * (FTJ * (KW) * (MWH) * * IMPACT CODE *
······················~··········································································································· * A.K7NPA2603 * REDOUBT LAKE * 5& St.,O * H * 12,0 * 0 * 0 * 2021.1 * NNUUUUU *
• I 5 * SITKA UNNAMED CASCA• 135 15,9 * IS * 1110000 * 1&00 * 7049 * 28t.,72 * "
* SOUTt<EAST • UNDEVELOPED * 1.10 * •28t..2• 19.9 * 1&00 * 70119 * * UNNUUUUUU *
* • POHT ALEXANDER D•ll * * * • * * * *
* * * * * * * * * • * AK7NPA0304 • ROSTISLOF LAKE
* I S * SITKA
* SOUTHEAST * UNDEVELOPED * PORT ALEXANDER
* * • AKbNPA030t. * RUST LAKE 2
• D o * SITKA
* SOUTHEAST * UNDEVELOPED
* * SITKA C•b • * * AK6NPA0307 * SADIE
* I 5 * ~ITKA
• SOUTHEAST * U~DEVELOPED
* * SITKA A-3,
* * AK7NPA030ll * SASHIN LAKE
* I 5 • SITKA * SOUTHEAST * UNDEII!LOPED * * PORT ALEXANDER
* * * AKSNPA0341 * SHECKLEY
• St. 28,2 •
ROSTISLOF CHE• 134 111,3 *
8·3
RUST CREEK
* 4 *
* * * * • 57 35.9 * * 135 59.0 •
* 7 *
*
*
*
* * 57 ~.~. 'il *
~AXMAN CREEK * 1311 1.18.9 *
* ~ *
*
"
*
*
• Sb 21.3 *
SASHIN CREEK * 1311 41,3 *
3 •
6•3 •
* • S& 17,9
*
*
* l 5 * SiiKA SKECKLEY CR
• SOUTHEAST • SUCHAN & HEINEN PACKING CO
"• 134 1.11.9 *
* !:> * * • PORT ALEXANOtR B-2 *
*
*
* * * • AK7NPA0309 * SULOIA LAKE
* I S * SITKA
* SOUTHEAST * UNDEVELOPED
* * ~ITKA 6-5,
* * * SUPERIOR
* SITKA
* 57 25.0 •
SOLOIA CREEK * 135 41,9 •
• 9 *
*
*
*
* * 57 47,1 •
HARLEY CREEK * 135 5,1 *
* AKSNPA0258
* 1 b
• SOUTHEAST • SUPEI<lOR
* SITKA D•ll
PKG CO * 3 *
*
* * • AK7NPA0311 * TAKATZ CREEK
* 1 2 * SITKA * SOUTHEAST * UNOE\IELOPEO
* * SITKA A•3.
* • * ..
* 57 t..9 *
TAKATZ CREEK * 134 51.0 *
• 10 *
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> I
-1:-
ln
Project Llsting(continued)
•••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••• * SITE ID * PROJECT NAME * LATITUOE •PROJ,PURP,• DAM ~T * EXIsr.CAP, •EXIST,EN~G•ANUL. COST * ENVIRONMENTAL *
* *PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •TOT, STOR• INC, CA~. •INC,ENERGY•ENERGY COST• IMPACT COO~ •
* DEP ACTV * ONNER • OR.AREA • AVE, Q oP~R. HO, *TOT, CAP. •TOT,ENERGY• • * * CODE HJV * MAP REFERENCE * (0 M,M) • • (FT) * (Kw) • (MVIH) • (1000 S) * *
* * * (0 M.M) * * (AC FT) * (ri:ov) * (Ml'lH) * ($/MI'tH) • SOCIAL *
* GEOG, AREA * * (SQ,MI) * (CfS) * (FT) * (KW) * (MWH) • • IMPACT CODE *
··~···················k************************•***********************************************************************•**********
* h>71<;>A03Sil * ABYSS l.A~E • ~8 30,0 * ~ * 100,0 * 0 • 0 * 1'51:>2,2 * YNUUUUU * * I ~ • SKAGI'tAY•YAKU DUNDAS RIVER * 13& 33,0 • IS • 11000 * 3'500 * 17'17b * ~9.395 * *
* SOUTHEAST * UNDEVELOPED * 6 • 100,0• 499,5 * j500 * 1747o * * UNNUUUUNU *
* • MT FAlri>~EATHER C•2, * • • • • • * *
• * * ~K&NPA0355 • ALSEK RIVE~
* I b * SKAG~AY•YAKU
* SOUT~EAST * U~OEVELOPEO
• Y~tiUTAT 6•1, • * AK4NPA0078 * OAYESAS CREEK
* I 2 • SKAG,AY·YAKU * SOUTH€AST * UNDEVELOPED
* * SKAG~AY ~-1 • * * AKINPA0359 * DEIIEY LAKES
* I 2 * SKAG~AY•YAKU
* SOUTHEAST * •
• AK7NPA0357
• I 2
• SOUTHEAST
*
*
* SKAGIIAY tl•l
* * GOAT LAKE
* SKAGtiAY•YAKU
* UNDEVELUPED
* SKAGI'IAY C•!. • • AK7NPA0358 • KOOK LAKE
* I S * SKAG~AY•YAKU
• SOUTHEAST • UNDEVELOPED
* SITKA C•4,
* • AK7NPA03qa * PELICAN
* I 5 * SKA~~AY•YAKU
* SOUTHEAST • UNUEYtLOPtO
* •StrKAD•7
* • AK7NPA0349 * SITKOH LAKE
* I 5 * ~KAG~AY•YAKU
• SOUTHEAST • UNDEVELOPED
*SITKA C•4,
• *
ALSEK RIVER
• * 59 22. 1 *
• 1 38 1. 1 *
11000 *
• * •
• 59 17.2 •
OAYEBAS CREEK• 135 2.0 •
* 11 • • • * • S9 2b.'< •
DEWEY CREEK • 135 18.9 *
* 7
* 59 31 • .:1
•
*
PITCHFORK FAL• 13S 11.0 *
KOOK CREEK
* 4 •
* •
.. 57 '10,0 *
• IH 59,0 •
* 2<;1
*
*
•
* * 57 57,2 *
PELICAN COVE * 13& 12,9 •
n
*
* • * '57 30,3 *
SITKOH CREEK * 135 4.9 *
* 9
* AK7NPAOJ51 • WEST CREEK TAIYA * S'il 31.7
CREEK TA• 135 21.0 • * I 5 • SKAG~AY•YAKU t~EST
• SOuTHtA~T * UN~EVELOPED * 3'1 * * * SKAGt~AY C•1,C•2. * •
*
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0 •
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*
* 20,0 *
0 *
59,9 •
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0 *
185.0 *
110,0 •
0 •
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*
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*
* 0 •
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• •
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1500 •
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• • 0 •
1400 •
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•
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* 0 •
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*
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*
* 1000 *
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*
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*
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* 0 •
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•
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* 112495 •
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*
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YNUUUUU
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~························-·····································································································•**
> I .p-
er-
Project Listing(continued)
••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••
SITE IO * PROJECT NAME *LATITUDE •PROJ.PURP.• DAM HT * EXIST.CAP. •EXIST.ENRG•ANUL. COST * ENVIRUN~ENTAL *
* • PRIMARY CO. -NAME OF STREAM •LONGITUOE * STATUS •TOT. STOR• INC. CAP. •INC.fNERGY•ENERGY CO~T· IMPACT CODE *
* DEP
* CODE
ACTV * O"'NER * OR.Af<EA * AVE. l.l •Pr.R. HD. * TOT. CAP. •TOl.ENt:fiGY• * •
INV * MAP REFERENCE * (0 M.M) * * (Ff) * (K!'!) * (MWH) • (1.000 $) * *
* * * (D M.M) * * (AC Fl) * (KW) * (MwH) * ($/Mi'!H} * SOCIAL *
* GEOG.. AREA * * (S~.MIJ * (CFSJ * (FTJ * (KW) * (MWH) * * IMPACT COOE *
***********************~**********************•********************************•*****************************************•********
• AKoNPA0352 * NOOO * ~8 34.9 * H * 3S.u * 0 * 0 * 11c0.7 * YNUUUUU •
* I 5 * S~AG.vAY-YAKU 1'<000 LAKE * 13b 21.q * IS * 0 • 3000 * 13315 * 8<1.172 * •
* SOUTHEAST • UNDEVELOPED * 10 * 100,0• 199,8 * 3000 * 13315 * * UNNUUUUNU •
• •MTI'AIR,..EATHERC-2, * * * * * * * "
* * AK7NPA0353 * YUKON•TAlYA
* I b * SKAGWAY•YAKU * SOUTHEAST * UNDEVELOPED
* * SKAGnAY C-1,
* * AKcNPA03b0
.. l b
" YUKON •
*
* *BIG DELTA
* S,E. I'AIWBAN * UNOEVELOi'Eu
• BIG DELTA A•ll,
*
TAIYA
* • s<~ :n. q *
* 135 19.9 *
* 25700 *
*
*
*
* * bll q,:s *
TANANA RIVER * 1<15 ~.0 *
* 15300 *
* *
*
* • AKI)t;PA03bl * CATHeDRAL BLUFFS * b3 23.2 *
* () I) * YUKON
* S.E, FAIRBAN TANANA RIVER * 143 44,3 *
* I.HILlfVELOPEO * 8550 * * T ANACR(JS;, l:l•b. *
* * Ai<7NPA03b2
* I b * YUKON
*
* CHISANA RIVER * S,E. FAH<BAN
• UtiOlVELOPED
• N~tlESNA 0-3
• AKbNPA0363 * GOODPASTER
* I 5 * S.~. FAIRBAN
* YUKON * UN~EVtLOPED * BIG DELTA 6•5,
* • * AKbNPA2bl5 * JOHNSON
* I b • S,E. FAIRBAN
tt YUKON • UNDEVELOPED
* * ~ISE~AN A-4,
* * AKbNPA2b31 * NAU[SNA
* I 5 • S.E. FAIRRAN * YUKON * UNDEVELOPED * * NAtlESNA 0•3
* * * b2 1 b. 9 *
CHISANA RIVER* 142 q.9 *
* 73(! *
• • * &4 30,0 *
GOODPASTER RI• )44 30,0 *
* 517 *
* • * b3 43,2 *
TANANA RIVER tt 144 37,0 *
* 10450
* *
* • * b2 45,5
NA6ESNA RIVER• 142 10,0 *
* 2145 *
* *
* H *
lS •
18bii7.0•
* •
H *
IS *
1721>1>.0•
*
*
* 100,0 *
0 *
1911.0 *
* * 120.0 *
0 •
98.9 •
* •
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IS * 5800000 •
8011.0• 145,8 *
* •
H *
IS *
H
IS
600,0•
*
* •
497.0•
* *
H *
lS •
10800.0•
* * H *
IS *
1300.0•
*
*
* 200.0 *
0 *
882. 1 * • • 200.0 •
270000 *
169.8 •
*
* 140.0 •
0 *
148.8 *
*
* 200.0 *
0 *
19(1,8 *
*
0 * 0 *
3200000 * 21000000 *
3200000 * 21000000 *
*
0 *
22b000 *
221>000 *
* 0 •
158000 *
158000 •
* •
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*
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•
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* 0 •
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*
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987000 *
987000 *
* •
0 *
693000 •
6'1300(1 *
*
0 *
7'17000 *
79700u •
*
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!Sb250 •
S6250 •
• •
il *
'l20000 •
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•
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320000 •
32000\1 *
*
1)9448
3.3010
30344
30.744
15820
22.629
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b125,b
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*
* ..
*
•
* •
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* • • •
*
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•
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*
• * * * * * * * *
NNUUUUU
UNNUUIJUUU
NN\'YUUU
UNNUYVYNY
NNY YYUU
UYYUUUUNU
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UNNUUUUNU
NNUUUUU
UHUNUUNN
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UNNUNUUNU
*
* ..
* • •
* •
*
*
* •
* • •
* • •
* • ..
* *
*
*
*
* * *
*
* AK7NPA2b33 *HOCK LAKE * 61 57,0 * H * 30,0·• 0 * 0 • 328S,q * YNUUUUU *
• I 5 * S.E. FAI~BAN PTARIGAN CREE• 141 1'l,9 * IS * 0 * 12000 * 58000 * Sb.b54 * *
* YUKON * UNDEVELOPED * 93 * 193.0• 513.4 * 12000 * S8UOO • * UNNUUUUNU *
* * ~lCCAHTHY D-1. * * • • * * * *
•*•******•********************************~***************************************************************************************
Project Listing( continued)
**********************************************************************************************************************************
SITE ID • PROJECT NAME • i..ATITUUE •PROJ,PURP,• DAM HT • EXIST,CAP, •~XISI,ENNG•ANUI.., COST • ENVIkUNMENTAI.. • * PRIMARY CO, •t<AME OF STREAM •LONGITuDE • STATUS, •TOT, STOR• INC, CAP, •INC,ENERGY•E~EMGY COST• IMPACT CODE •
• DEP ACT\1 • o""'tR • UR,ANEA • A \IE, Q •PI\fl, 110, • TOT, CAP, •TOT ,EJ<ERGY• • * CUOE INV • MAP RtFERENCE • (0 M.M) • * ( f'T) • (KW) • (Mt<H) • (1000 i) • • • • • (0 M,M) • • (AC FT) • (KW) • (MI'IH) * (l/MWH) • SOCIAl.. • * GEOG. AREA • • (SQ,Mll • (CFS) • (F T) • (KW) • (M,..H) • • IMPACT CODE •
********************************************************************************************************************************** • Al<oNPAOlb'l * :SALCHA RI\IER • bll 38.2 . H • 190.0 • 0 • 0 • 15382 • NNUUUUU • • I 5 • s.t:. FAIRBAN SALCHA RIVER • 1115 2!>,9 • IS * 550000 • 25000 • 123000 • 125. 5 • • YUP<ON * UNUEVELOf'EO • 1990 • 1b00,0• 135,8 • 2~ouo • 1.!3UOO • * UNNUUUNYU
* 8IG DELTA C-5, • • • • • • * • • • * • • • • * • A~7NP~03&5 * AFTEI<BA Y • 00 54.8 • H • 120,0 • 0 • 0 • 81155,Q • NNUUUUU
• E 5 * UPPEI'i YUKON E F CHANDALAR• 147 10,0 • IS • 1118000 • 25000 • 1<!2000 • o'io,30b * • YUKON * UNI)f VELOP£(1 • 5500 • 2070.0• 98,9 • 25000 • 122000 • * YNNUUUNUU • • * CHAN!JALAi< A•1 • • • • • • • • .. • • • . • • • • • ~1<6NPA03bb • BIRCH • 65 20,'l • H • 210,0 * 0 • 0 • 1>813. b • NYUUUUU
• I 5 • Uf'f'ER YUKON BIRCH CREEK • 144 '17,0 • IS • 0 * 372'11 • 117&01 * 57.938 • • YUKON * UNUEVELOPEO • 730 • 550,0• 199,8 .. 37291 • 1171:>01 . • UNNUUNNYU
• * CIRCLE 8•2 • • • • • • • • • • • • • • • AK7NPA03b7 • EAST FORK CHANOALAR • o8 1,9 • H . 110.0 • 0 . 0 • 64&1,1> * NNUUUUU
> • 0 5 * UPPER YU~ON E F CHANOAI..Aih 145 52,9 • IS • 0 • 1'1000 • 90000 • 94, 16 *
I • YUKON * UNOE\IELOPED • 2~00 • 938,0• 11>2,0 * 1'1000 • 90000 • • YNNUUUNNU ..,.. • • A'iCTIC • • • • • . •
-..,j • • • * • * • . • ..
• AKb~PA03b8 • FORTIMILE • b'l 1o.o • H • '100,0 • 0 • 0 • 11613 • NYUUUUU •
• 0 /,) * UPPEr< fUKON FORTYMILE RIV• 1111 14,0 • IS • u • 1&&000 • 723000 • lb, b2 • • YUKON * U"'OEYELOPEO • bOoU • 446.2,0• 323,& "' lbbOOO • 7c3UOIJ • • UNNUUUNNU * • EAGLE U•l, * • • • • • • •
* • • • "' • • • • AK6NPA03o9 • FORTYMILE N E • bll 20.0 • H • 300.0 • 0 * 0 • 72'H .a • NYUUUUU • • D 5 • uPPE!l YUKON NORTH FORK 1'0• !Ill 57.9 . IS * 0 * 51000 • 245\JOO • 29.7b2 • • YJKDN • U'<:lEVELOPfO • 2065 . 12'l8.0• 2q8.7 . 51000 • 245000 ~ • UNNUUU!IINU
• fAGU. d•2, • • • • • • * • 41<611PA0370 • FORTYMII..E SF • bll :51.9 • H • 230.0 • 0 • I) . <~ob:5,8 • NYUUUUU
• 0 5 * UPf'HI YUKON SOUTH FORK FO• 1'12 o.o • IS • 0 • 51000 • 2'15000 * 3'5.3b2 • • YUKON • UI;DE\/ELOP£0 • 2800 • 2070,0• 227.7 • 51000 * 245000 • • UNNUUUNNU
• EAGLE A•2. • • • • * * • • • • • • • • • • •
• AKoNP.1.2t>28 • LITTLE ROCK • b7 13.8 • H • !60.0 • (I . v • 'l9oS.e • YNUUUUU * * D 5 * uPPfrl ~tHO.~ E F CHAND ALAR• 14b 8,9 • IS • 0 • 25000 • 119000 • 83,7'10:. • • • YUKON * ur-.uEVE.LOPt.O * 4200 • 3700.0• 1:51,8 • 25000 • 1l'l000 • * UNNUNUNNU •
• CHRISTIAN C•S. • • * • • • • * • • • • • • • • Ubi<PA0371 • I'IOUOCHOPPER • 65 21,2 • H • 385,0 • 0 • v • l':ilOOO • YNUUUUU
• r b • UPPER YUKON YUKON RIVER • !Q3 21.0 • IS •1>9500000 • 21ooooo • 14200000 • 1 o. o.B • • YUKON • UNOEVEi..OPED • 122000 • 7951>2.0• 299.7 • 2l&OOvO * 142oooov • • UNNUUUNNU •
* * CHARLEY a-5. • * • • • • • *
*************5*l*****************•••·································································~···········*****************
~
+'-
00
Project Listing(contlnued)
*********************************************•*************************************************************•··~··················· * SITE IO * PROJECT NAME * LATITUDE •PRUJ,PURP,• DAM Hi * EXIST,CAP, •EXIST,lN~GoANUL, COST * ENVIRONMENTAL * * *PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •TOT. STOR• INC, CAP, •INC,ENERGY•ENEHGY COST• IMPACT COO~ *
* OEP ACT\1 * O,..Nf.R * OR,AREA * AVE, Q •Pt<R, HO. * TOT, CAP, •TOT ,Ei~t:RGY• * * * CODE INV * MAP REFERENCE * (0 M,M) * • (FT) * (KW) * (MWH) * (1000 :5) * *
* * * (0 M,t-0 * * (AC FT) * (KW) * (MfiH) * (:li/MI'!H) * SOCIAL * * GEOG. AREA * * (SQ,tH) * (CFS) * (FT) * (I<W) * (MWh) * * IMPACT CODE *
***********•********************************************************************************************************************** * AK6NPA0372 * ZIMMERMAN * 67 0,0 * H * 190,0 * 0 * 0 * 148B * NNUUUUU * * 0 5 * UPPER YUKON UNNAMED * 147 Q,3 * lS • 0 * 4'1000 * 210000 * 70,b3S * *
* YUKON * UNDEVELOPED " 5500 * 2070,0• 11>8.8 * 44000 * 210000 * * YNNIJUUN!';U *
* * CHAIIIDALAR B•l, * * * * * * * *
• * * * * * * * * * AKbNPA2b19 * PORCUPINE
• I b * UPPEri•YUKON
* YUKON * UNDEVELOPED * * COLEEN B-1.
* * * AK7NPA0041 * ALLISON CREEK
* l 2 * VALDEZ-CHIT• * SO CENTRAL * UNDEVELOPED
• • VALDEZ A•7
* • * AKbNPA0374 * GAKONA SITE
* I b • VALDEZ•CHIT•
• SO CENTHAL * UNDEVELOPED
* • GULKANA B-3.
* * * AKbNPA0373 * GERSTLE * D 5 * VALDEZ-CHIT• * YUKON * UNDE~ELOPED
* b7 19.2 *
PORCUPINE RlV• 141 25,0 *
* 23400 * •
*
* * * b1 7,1 *
ALLISON CREEK• 146 10.2 *
* 5 *
*
*
*
* * b2 21>.0 *
COPPER RIVER * 145 40.0 *
* 3935 ..
* .. •
* * 63 '19,9 *
TANANA RIVER * 1Q'I 48,0 *
* 10700 * * * MOUNT HAYES 0•2. *
*
* * * * * AKbNPA0378 * GULKANA RIVER
* D 5 * VALDEZ-CHIT-* SO CENTRAL * UNDEVELOPED
* * GULKANA 8•3.
* * AK7NPA0375 * GULKANA RIVER
* 0 6 * VALOEZ•CHIT•
* SO CENTRAL * UNOEVELOPEO * * GULKANA B•J, • * * AK7NPA037b * GULKANA RIVER
* 0 5 * VALOEl·CHIT• * SO CENTRAL * UNDEVELOPED * * GULKANA C•S,
* * * AK7NPA0377 • GULKA!';A RIVER * I 5 * VALDEZ-CHIT· * SO CENTRAL * UNDEVELOPED * * GULKANA C•4,
UPPER * b2 27,0 •
GULKANA RIVER• 145 30,0 *
* 1770 *
*
*
•
* LO~ER • 1>2 34,9 •
GULKANA RIVER• 1'15 29,0 •
' 1850 *
•
*
*
* ~EST • b2 34,, •
W FORK GULKAN• 146 4,9 *
* 398 *
* *
•
* * b2 34,9 *
GULKANA RIVER• 145 Sb,O *
* 575 •
* *
H *
IS *
13000.0•
H
IS
*
*
* 49,0•
*
*
H *
IS *
1>072,0•
*
*
H *
IS *
13122.0•
*
*
H *
IS •
2b22.0•
*
*
H *
IS •
27b0,0* ..
*
H *
IS •
607.0• •
*
H *
IS •
851:.,0•
*
340.0 *
0 *
312.1) *
•
1 • 0 *
19,81) *
111>8,8 *
* * 280,0 •
0 *
21>5,7 *
*
* 100,0 *
0 *
58,9 *
* •
150,0 *
0 *
123,8 •
*
* 50.0 *
0 *
231.7 •
*
* 80.0 *
0 *
191,8 *
•
* 200.0 *
0 *
404,5 *
*
0 *
530000 *
530000 *
•
0 •
8000 *
8000 *
•
*
0 *
150000 *
150000 •
*
0 *
100000 •
100000 *
* * 0 •
9000 •
9000 *
*
0 *
9000 *
9000 *
*
*
0 *
1'1000 *
14000 •
*
* 0 *
3'1000 *
34000 * •
0 •
2320000 *
2320000 *
*
* 0 •
37250 *
37250 •
*
*
0 *
727000 *
727000 *
*
0 *
438000 *
438000 *
*
*
0 *
45000 •
45000 *
•
* 0 *
42000 *
42000 *
*
0 *
b'IOOO •
6'1000 *
* 0 *
11>4000 *
16'1000 *
294<)6 *
12.714 *
*
1198,0
32,163
*
*
*
*
*
*
* 21'11b *
37,793 *
•
*
19924 *
45,490 *
4<175.5
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4713.4
112.22
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10597
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*
*
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* •
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UNNUUUUNU
NNUYNNII;
NNNNYNYYY
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UNMiUUUNU
NNUUUUU
UNNUUUUUU
NYUUUUU
UNNUUUUUU
NYUUUUU
UNNUUUUUU
NYUUUUU
UNNUUUUUU
NYUUUUU
UNNUUUUUU
* * *
* *
*
*
* * *
*
* * *
* •
* * * * •
* *
* *
*
* *
* * •
*
* *
* •
* * ***************•*************************•**********************•********************•********************************************
Pj
+:-
\.0
Project Listlng(continued)
********************************************************************************************************************************** * SITE 10 • PROJECT NAME • LATITUDE •PROJ,PURP,• DAM HT * £Xl5T,CAP, •EXIST,tNHG•ANUL, COST * ENVIRONMENTAL * * *PRIMARY CO. -NAME OF STREAM •LONGITUDE * STATUS •TOT, STOR• INC. CAP, •INC,EI<£HGY•ENE~GY COST• IMPACT COO£ *
* OEP ACTV * Or;NER • DR,AREA * AVE. Q tPWR, HO, • lOT. CAP, •TOT .ENERGY• * *
* CuDE lNV * MAP REF£kENCE • (0 N •• ~) * * (FTJ • (1\•~) • lt-1WI1) * tlOOO $) * *
* * t (D M,N) * • (AC FT) * (KW) * (MI'<n) * l$/MWH) * SOCIAL
* GEOG, AREA • • (5\l,MI) • (CFS) • lfT) * (1\"l * (MwH) • * IMPACT CODE *
********************************************************************************************************************************** * AKoi<PA037'1 • KOTSINA RIVER • b1 31::1,0 * H * ll25,0 * 0 • U • 4.SOll5 • VtWUUUU *
* I 5 * VALDEZ-CHIT• KATSlNA RIVER• 144 11,0 * lS • 0 • 28000 * 133000 • 323,q4 * *
* SO CENTRAL • UNI)c VELOPEO • 20q • b07 ,0• 523,4 * cllOOO * 133000 * * UNr.UUUUUU *
* * VALDEZ C•1. * * * * * * * *
* * * AK7NPA0380 * MCCLURE HAY
* I ~ • YALDEZ-CHIT-
* SO CENJRAL * UNDEVELOPED
* * SE~ARO C-4
* * A~b~PA0381 • NELCHIN~ RIVER
* I ~ • VALDEZ-CHIT-
* SO CENTRAL • U~UEVELOPED
* * GUL~A~A A•Q
* AK6NPA03B2 • SAhFQAD
* I 5 • VALDEZ-CHIT-
* SO CENTRAL * UNDEVELOPED
* * GULKANA 8•3.
• • * A~7NPA0383 * ~ILVER LAKt
* I 5 • VAL0£l-CH!T~
• SO CENTRAL. • U~DEVELOPEO
* * CORDOVA 0•7.
* * AK7NPA038q * 60LOMON GULCH
* I 2 * VALOtl•CHIT•
* SO CENTRAL • UNDEVELOPED
*
*
* VALflf;Z A•7
* IK7NPA038S • SUM~IT LAKE
* I 5 * VILDEZ-CHIT-
• SO CE~TAAL • U~UfVELOPEU
* MT HAYES A•4
* * AKbNPA036~ • TAZL!NA
* I b * V~LOEZ-CHIT•
* SO CENTRAL * ONOEVELOPEO
• GUL~AII>A A•5.
•
• A~7NPA0387 * TOLSONA CREE~
* I 5 * VALUEZ•CHIT-
~ SO CENTRAL • U~~EVELOPED
* * GULKANA A•4
* • 1>0 33,9 *
HANLEY CREE~ * 148 10,3 •
* 71
*
*
*
* b2 0.3 *
NELCHINA RIVE• 14b 38,9 •
• 820
*
* * b2 19.9
*
COPPER RIVER • 145 21.0 •
33b5
* •
*
* H
IS *
184,0•
*
H *
IS
12'l7,U•
*
*
H *
IS •
5106,0•
*
• bO 5b.O • H
DuCK RIVER • l4b 19,9 • IS
* 2':> • 248.0•
* • *
* * 61 30,9
SOLOMON GULCH• 146 15,9 •
* 18
*
* * b3 4.9 *
GULKANA RIVER• 145 32.u •
• 83
•
* •
• b2 0,9
TAZLINA RIVER• 14b 8,9 •
1970 *
•
• b2 4,'1 •
TDLSONA CREEK• 145 57,9 •
• I 7 4 *
* *
H
IS •
138,0•
*
H *
IS
12l.u•
H
IS
3174,0•
•
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IS
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* 25.0 •
0 .f<
2'lb.7 *
* * 2qo.o •
0 •
284.7 *
340,0 *
0 *
177,8 •
*
* 100,0 *
0 •
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• • 1v.o •
0 *
b07.3 *
•
5.0 *
0 •
sou,o •
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90000\J •
272.7 *
250.0 *
0 *
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*
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*
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*
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•
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51,117
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•
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·············~········•••*********************••···················································································
:>
I
V1
0
Project Listing(continued)
**********************************•**•***********************************************'*************************************'****** * SITE IO * PROJECT NAME * LATITUDE •PROJ.PURP.• DAM HT * EXIST.CAP. •EXIST,ENRG•ANUL. COST * ENVIRONMENTAL * * * PRIMARY CO, -NAME OF STREAM •LONGITUDE * STATUS ~TOT. STOR• INC, CAP, *INC,ENERGY•ENERGY COST• IMPACT CODE *
* OEP ACTV * OiiNER * DR,AREA * AVE. Q •PWR, HO, *TOT. CAP. •TOT.EI\It:.RGY• * •
* CODE !NV • MAP REFERENCE * (0 M.M) * * (fT) * (KW) * (MWH) * {1000 $) * * * * * (I) M.M) * * (AC FT) * (KW) * (M,..H) * ($/Mi\H) * SOCIAL *
* GECG. AREA * * CSO,Ml) * (CFS) * CFT) * (KW) * (MriH) * * IMPACT CODE •
*******************************************************************************•***********************•************************** * AKbNPA0392 * CHUILNAK RIVER UPPER * b2 4&,9 * H * 145,0 * 0 * 0 * 4809,2 * YNUUUUU * * I 5 * WADE HA•lPTON ATCHUILNK Rill• lb1 2b,9 * IS • 0 * 2000 * 11000 * 437,20 * "
• SOUTHWEST * UNOE\IELOPED * 1b2 * 193,0• 102,8 * 2000 * 11000 * * UNNUUUUNU *
* * HOLY CROSS 0•5 * * * * * * * *
* * * AK7NPA0310 * THOMAS BAY * I 2 • ~RANGELL PET
* SOUTHEAST * UNDEVELOPED
* SUMOU~ A-2 A•3
* * • AK7NPA0412 * AARON
* * 57 3.3 *
CASCADE CREEK• 132 115,2 *
* 18 *
* * * *
* I 5 * ~QANGELL-PET AARON CREEK
• 5b 22.9 *
* 131 55.0 *
* 911 * * SOU1HEA5T * UNDEVELOPED • * BRADfiELD CANAL C•b,
• * AK7NP~041] * ANAN CHEEK
* I 5 * ftRA~GELL•PET ANAN CREEK * SOUTHEAST • UNDEVELOPED
• * BRADFIELD CANAL A•b.
*
* • *
* • Sb 10.0 *
* 1 31 52. 1 *
* 27 *
* *
*
~ AKbNPA01114 • ANITA * I 2 • ~RANGELL-PET
* 5b 15,5
ZIMOVIA STRAI• 132 2b.S *
~ SOUTHEAST * UNDEVELOPED * 2 • * • PET~RS8URG 8·2. *
* * * * * AK6NPA0415 • BRADFIELD RIVER NDMTH * 5b 19.9 *
* I 5 * ~RANGELL•PET N BRADFIELD •• 131 22.0 *
* SOUTHEAST * UNDEVELOPED * 150 * * • BRADFIELD CANAL 8•5 • •
* AK7NPA0111b
* I 5 * SCuTHE~ST
*
t
* * BURNETT LAKE
* .-RANGELL•PET
• UIWEVELUPED * PEfERSBURb A-2.
•
* * 5b 5.9 *
BURNETT CREEK• 132 27.9 *
* I *
* • * * AK4NPA2b05 • CRITTENDEN CREEK * 56 30.0 •
* I 5 • WRANGELL-PET CRITTENDEN CR• 132 15,1 * * SOUTHEAST • UNDEVELOPED • 10 •
* • PETERSBURG 8•1, * •
• * • AKJNPA0~23 * CRYSTAL LAKE * I 5 * wRANGELL-PET BLIND RIVER
• SOUTHE~ST * CITY OF PEiERSBURG
* * PETERSBURG C-3
* * * Sb 35.9 *
• 132 48.0 *
• 2 •
* *
H
IS
H
* •
* 22b,0•
* *
IS *
1100.0•
* *
H *
IS •
271:.,0•
*
*
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27.0•
•
*
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IS •
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*
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* 80.0•
•
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•
* * • 1&,0•
* 3.0 *
0 *
1443.5 *
* * 100.0 *
7&000 *
117.8 •
* •
169.0 *
164000 *
299.7 *
* * b8,0 *
15500 *
1005.9 *
* * 150.0 *
0 *
156.8 *
* * 35,0 *
0 *
229.7 *
* * 10.0 *
0 *
119.8 *
* * 25.0 *
6860 *
1200.0 •
•
*
0 *
50000 *
50000 *
*
*
0 *
12000 •
12000 *
* •
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7000 *
*
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* *
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* •
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• 0 •
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* 2<1\lO •
1400 •
3800 •
*
•
0 * 217417 *
217417 *
* • 0 •
58000 *
58000 *
* * 0 •
33000 *
33000 •
*
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* * 0 •
131000 *
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* •
0 *
12290 *
12290 *
*
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8128 •
8128 •
* * 9800 *
0 •
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*
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18,473
3386,9
58,396
4b4b,7
140.61
712.64
54,603
8544,5
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92&.8'3
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* *********•************************************************************************************************************************
;:x;.
I
\J1 .......
Project Llsting(continued)
************************************************•················································································· * SITE IO • PROJECT NAME • LA TITIJOE •PROJ.PURI-'.• DAM HT • I:.XIST ,CAP. •EXIST ,tNfiG•ANUL. COST * ENVIRONMENTAl. *
* *PRIMARY CO, •NAME OF STREAM •LONGITUDE • STATUS •TOT, STUN• INC. CAP, •lNC,ENERGYoENEMGY COST• IMPACT CODE *
* OEP ACTV * ONNER * OR,AREA • AVE, ll •PNR. HD, • TOT. CAP, •TOT ,!:.NERGY• * *
* CODE !NV * MAP REFERENCE • (0 M,M) o • (FT) • (K'h} • {M~H) * (1000 $) * *
* • * (D M,M) o o (AC FT) * (l<.N) • (Mt<H) o ($/t~"H) • SOCIAL *
• GC:CG, ARE I. • * (SQ,I'il) • (CFS) * (FT) * (K"') • (M<'~H) • • IMPACT CODE *
****************···~·······························································~·············································· • .I.KH<PA0417 • FALLS LAKf. o 57 1.1 o H o 50,0 o 0 * 0 o 31158,1> * NNUUUUU *
* I 2 • WRANGELL-PET CASCADE CREEK• 132 45.1 * lS • 0 • 4M000 * 190000 • 18.203 *
* SOUTHOST • U~<OEVELOPEO • 20 • 220.0• 906,0 • ~4000 • 19000\1 • * UNNUUUUUU
• SIJ4DU'l A•3. * *
" • A~7NPA0418 • FARRhGUT RIVER
* I b * ftRANGELL•PEf
• SOUTHEAST * UNDfVELOPEO
* o SUMDUM A-3,
*
* 57 28.() •
FARRAGUT RIVE• 132 ~7,9 *
bQ *
* *
H
IS
• •
bb2,0•
•
* * .KbNPA0419 • GOAT
• l b • NAANGELL-PET GUAT CREEK
* Sb 36.0 * H
* 132 0,0 * IS * SOUTHEAST * U~uEVELUPED • 14 • !55.0• * • dRADFIELO CANAl. C•b,
• *
• AK7NPAvl01 • HARUING RIVER
* I 2 • NRANGELL•PET
• SOUTrlEAST • UNDEVELOPED
• Sb 16,1
HARDING RIVER• 131 38,9 *
• Ed *
• 8RAOFIELO CANAL A•S * * • aKb~PA0420 • HOUGHTON
• I b • nRANG[LL·PET
• SOUTHEAST • U~OEVfLOPED
• SU~DU~ 8•3,B•Q,
• * • AK7NPA0~21 • KATETf RIVER
* i 5 * R~ANGELL•PtT
* SOUTHtA5T * U~UEVELOPEO
• 51 23,0 •
NO NAME SE AK• 133 8.9 •
• 39
• • 56 32.9 •
KATETE RIVER • 1~1 Q5,9 •
* 7 3 * * • BRADFIELD CANAl. C•6. * • •
* *
H
IS •
H
IS
725,0•
*
* 511.0•
•
H *
IS
792.0•
• • A~NNPA0424 * KEKU * 51> II 4. 1 * H *
• l 4 * ftRANGELL-PET KEKU CNEEK * SJUTHEAST o KEKU CAN~ING CO.
• PFTEHSUUHG C-h
* AKbtlPA0070 • KUNK LAKE
• I 5 * wqANGELL-PET KUNK CREEK
• SUUTH!:.AC\T • UNOEVELOPFO
• PETENSBURG d•2,
• 133 11!,9 o OP •
8 • '15.0•
•
• Sb 17,1
* 13.::! 23.2 •
* 8 •
*
*
H
IS
74,0•
* * AK6NPA0394 * MARTEN CNEEK * Sb 16.9 * H *
• I b • WRANGELL-PET MARTEN :REE~ * 131 Sl,Q * IS •
* SuUTMEA~T • UNDEVELOPED • 3 • 32,0•
• BRADFIELD CANAL B-6 • * •
•
100.0 •
0 *
492.5 •
* •
1>5.0 •
0 •
1054.9 •
* 190.0 •
0 •
259.7 *
200.0 *
0 •
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* 125.0 •
0 •
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5.0 •
0 •
127.0 •
* •
110.0 •
35150 "
309,b •
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• •
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*
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31000 •
•
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2!000 •
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* 30 •
0 •
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* 0 •
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*
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•
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•
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•
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w*•****•****••*****•****~***•~*****~*********•***********~*******************************************************************•****
:r
\J1
N
Project Listing(contlnued)
**********************•••········································································································· * SITE ID * PROJECT NAME * LATITUDE •PROJ.PURP.• DAM HT * EXlST.CAP. •EXISJ.ENRG•ANUL. COST • ENVIRONMENTAL *
* *PRIMARY CO. •NAME OF STREAM •LONGITUDE * STATUS •TOT. STOR• INC. CAP. •INC.ENERGY•ENE~GY COST• IMPACT CODE *
* OEP ACTV * OwNER * DR.AREA * AVE. U •PWR. HD. * TOT. CAP. •TOT,ENERGY• *
* CODE INV * MAP REFERENCE * (0 M,M) * • (FT) * (Kif.l) * (MrJH) • (1000 S) *
* * * (0 M,M) * * (AC FT) * (Kr;) * (MtiH) ,. (:Ji/MI'IH) *
* GEOG. AREA * * (SU.Ml) * (CFS) * (FT) * (KW) * (MI'IH) • * SOCIAL
IMPACT CODE
* * * ··································································································•*******•*********************** * A~7NPA03qb * MCHENRY LAKE * 56 3.3 * H * 50,0 * 0 * 0 * 1198.3 * NNUUUUU -
* 1 5 • WRANGELL-PET MCHENRY CREEK• 132 20.2 * IS * 0 * 5000 * 21790 * 54,994 *
* SOUTHEAST * UNDEVELOPED * 13 * 160.0• 299.7 * 5000 * 21790 • • UNNUUUUUU *
• * PETERSBURG A•2 * * * * * * * *
* * I.KoNPA03'17
* I 6 * SOUTHEAST
* * AK7NPA03'18
• * MENHEE LAKE
* ~RA'•GELL·PET
• UNDEVELOPED * P£TEwS~U~G A•1 ..
* NAVY LAl<E
* * * 56 3. 9 •
MENEFEE CASCA• 132 12.9 *
* 4 *
*
*
* •
* I 5
• SOUTHEAST
* WRANGELL-PET NAVY CREEK
• Sb 4. 1 • * 13<! 25.3 *
* 7 *
*
*
• UNDEVELOPED
* PETERSBURG A•4
* • 4K7NPA0399 * OLIVE LAKE
* I 5 * WRANG~LL•PET
* SOUTHEAST • U~OEVELOPEO
* * PETERS~URG B-2
* " AK7NPA0400
* I 2 * SOUHlEAST
* • Ali7N>'A0401
* l 2
• SOUTHEAST
•
* * RUTH LAKE
* WRANfiELL•PET
* UNfJEVELUPEO
• PETERSBURG 0•3,
* SCENERY CRtEI<
* WRANGf.LL-PET
* UNOEVELOPEO * SUMDUM A•2,A•3,
* AKbNPA0402 * STIKINE RIVER
* I o * WRANGELL-PET
• SOUTHEAST * UNDEVELOPED
OLIVE CREEK
DELT CREEK
*
*
• •
• So 11 .2 •
* 132 18,9 *
• 4 •
•
*
*
" * so 59, o •
* 13<! 45,0 *
• 6 *
* • *
* * 57 4. 9 *
SCENERY CRtEK• 132 41,9 *
• 21 *
*
"
*
* • 56 42.0 *
STIKINE RlVER* 13~ 11,9 *
• 20000 •
* * PETERSSURr. C•1,D•I BRADFIELD• *
* • A1<7!1PA0403 * SUNRISE LAKE
• I o
* SOUTHEAST
* I'IRANGELL•PET UNNAMED
* UNDEVELOPED
* • PETERSBURG C•2,
* * • 4K7NPA0405 * THOMS LAKE
* l 5 * WRANGELL-PET THOMS CREEK * SOuTHEAST * UNUEVELOPED * * PETERSBURG A•1.
* ..
* 51:1 24.0 * * 132 ('9,0 *
* 1 •
* • *
* • so 111. o •
• 132 15.0 *
• 13 •
* *
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* * * * * * **•***********************************************************************************.***********•**************•*****************
;1:>
I
V1 w
Project Listing(continued)
*******************************•************************************************************************************************** * SITE IO * PkOJECT NA~E *LATITUDE •PROJ,PUkP,• DAM HT * EXIST.CAP, •~XISl .~N~G•ANUL. COST • ENviRONMENTAL * * * PRI~ARY CO, •NA~~ OF STREAM •LUN~ITUUE * STATUS •TOT. STUR• INC. CAP, •INC,EN~RGY•ENENGY COST• IMPACT CUD~ * * OEP ACTV * Ur;NfR • DR,AREA * AVE: Q •PI'fR. HD, • TOT. CAP, •TOT ,E'YtcRGY• • * * CODE !NV • MAP REFE'<ENCE • CD M,M) • • (f T) * (KW) • (M,.;H} • (1000 $} • *
* * • (D M,M} • • (AC FT) • (KW) * (M..,H) • (.'lo/MWH) * SOCUL
* GEOG, •REA • • (S(l,MI} • (CFS) • (FT) • (1\Wl • (Mo'IH) • • IMPACT CODE
•••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••••• * AK7NPA040b * TOM CREEK * 5b 12.4 * H • 50,0 * 0 • 0 • 1801,0 • NNUUUUU *
* I b * r<RANGELL•PET TO"! CREEK * 131 110,3 • IS • 0 * 8500 • 374b7 • 4tl, 70 * *
* SOUTHEAST * UNDEVELOPED * 17 * •148.1• 379.b • t\500 * 37Gb7 • * UNNUUUUUU
* * BRADFIELD CANAL S•b, • * • • * * *
•
• 4~7NPA0407 • TO~ERS CREEK
• I 5 • W~ANGELL-PET
• SOUTHEAST • UNDEVELOPED
• * 51> 51.9 •
TO~ERS CREEK • 133 2b,O *
• 81 * • * PETERSBURG 0•5. • • •
* * • AK7NPA0408 * TYEE cqEE~
* I 2 * ~RA~GELL•PET TYEE CREEK
* 56 12. 0 * * 131 33.0 •
• SOUTHEAST * UNDEVELOPED * 14 * * BRADFitLD CANAL A•S. * • * AK7NPA040q * V!RGI~1A LAKE
* I 5 • ~RA~GELL•PET
* SOUTHEAST • U~DEVELOPEU
* • PETERSBURG B•l.
* * AKbNPA0410 • wHITE RIVER
* •
• Sb 28,4 •
MILL CREEK EA• 132 10.0 •
1 *
* • *
• I b • ~RA~GELL-PtT WHilE RIVER
* 56 1 3. 0 •
* 131 30.0 *
* 43 • * SOUTHEAST * U~DEVELOPEO
* * BRADFIELD CANAL B•S. • • * AK7N?A0411 • ,.;ILKES RANGE
• I 5 • ~RANGELL•PET
* SOUTHEAST • UNDEVELOPED
* • Sb 43.0 •
STIKINE RiVER• 132 ~b,O •
.. 1 •
* • PETERS~URG C-2. * * • l~bNPA0425 • ALATNA RIVER
* I 5 * VU~OII•KOYLIKU
* YUKON • UNDEVELOPED
* • HUGHES C•1.
* * AK7NPA042b • ALATNA RIVER
* I 5 * YU~ON-KOYUKU
• YUKON • UNO~VELOPEO
• SUilVI:.Y PASS
* b6 33.9
ALATNA RIVER * 152 4b,9 •
28b0
* •
UPPEil • b7 15.0
ALATNA RIVER * 153 31,9 *
13Z5 *
•
*
H
IS
H
• •
414,0•
IS •
H
IS
163.0•
*
* * -13.4•
•
H *
lS •
H
IS
H
530,0•
•
*
•
-12.2•
*
IS *
27bO.O•
•
200,0 *
0 •
258.7 *
•
* 100,0 •
105000 *
135o,b •
• • 130,0 •
0 *
149.8 •
* 40.0 •
0 •
31!9.1> * • •
25.0 *
0 •
1398.6 •
•
130.0 *
23'17000 *
10tl,8 *
H o 200.0 *
IS • 3446000 *
!82'l.O• !5?.8 •
*
* 0 •
13000 •
13000 •
•
* 0 •
30000 *
30000 •
• •
0 •
3o·o •
300 •
*
* 0 •
2b000 •
21>000 *
*
*
0 *
2500 •
2500 •
•
0 •
3b000 •
3b000 *
*
*
0 *
25000 *
25000 •
• •
•
0 *
bGOOO *
bliOOO •
0 *
132940 *
1329<1(1
0 *
1338 •
1:ne. •
0 •
116'1<10 •
111><140 *
•
0 *
11371 •
11371 •
0 •
175001) *
175000 *
*
0 •
123000 •
12300J *
• •
5435.2
84,'121>
5678,2
27.bi>8
2854.2
2133.2
*
* * •
*
* • •
• •
*
*
3367.8
2'l, 'IS •
•
5"1\1.20
51,904
21'lb7
125,52
10725
lH • 19b
*
*
* •
*
*
*
*
*
NNUUUUU
UNNUUUUUU
NNUUUUU
UNNUUUUUU
NNUUUUU
UNNUUUUUU
NNUUUUU
UI'1NUUUUUU
NYUUUUU
UNNUUUUUU
NYUUUUU
UNNUUUUYU
vr.uuuuu
UNNUUUNNU
* IKbNP•0427 • BRO..,NE • oa 11,0 • H • 230,0 * 0 • 0 • 27731 * N~UUUUU
*
*
* *
*
* *
* •
* •
*
*
•
* ..
* • •
*
*
*
*
•
* •
*
* I 2 * YU~ON•KOVUKU NENANA RIVER • IG'l 15,0 * IS • U • 200000 * 566000 • 48,995 • *
* YUXON * UN~EVeLOPEO • 2q5Q * 46'l2.0• 20b,7 • 200000 * 5bb000 • • UYYUNNNNN *
* FAIRBANKS A·5, • • • * * * * *
·······················~···-··········································-···········••*•*··~············••***************•**•*******
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Project Listlng(contlnued)
********************************************~····················································*********************************
* SITE !0 * PROJECT NAM~ *LATITUDE •PRUJ,PuRP,• DAM HT * EXIST.CAP, •EXIST.ENRG•A~UL. COST * ENVIWUNMENTAL *
* PRIMARY CO, •NAME OF STREAM •LONGITUDE * STATUS •TOT, STOW• INC, CAP, •INC,ENt~GY•ENEHGY COST• IMPACT CODE *
* OEP
* COOE
ACTV * OwNt:R * OR,A!o~EA * AVE. Q •PwR, HD, * TOT. CAP, •TOT ,f::NERGY• * *
INV * MAP REFERENCE * (0 M,M) * * (FT) * (KW) * (MWH) * (1000 S) * *
* * (0 M,M) * * (AC FT) * (Ki'l) * (MWH) * (S/MwH) * SOCIAL *
* GEOG, AREA * * (SQ,MI) * (CFS) * (FT) * (Ki'l) * (MiiH) * * IMPACT CODE *
**********************************************************************************************************************************
* AKoNPA2o11 • BRUSi'\ANSNA * o3 24,0 * H * 275.0 • 0 * 0 * 7bc!o,l * NNUUUUU *
* 0 5 * YUKON·KOYUKU NErqANA RIVER * 148 30,0 * IS * 0 * 3o000 * 11>0000 * 47 ,oc3 * *
• YUKON * UNDEVELOPED * &50 * 1139,0• 211.1 * 3b000 * 1&0000 * * UYYUNNYYN *
•HEALYI:I•ll, * * * * * * * *
• AKoUPA0428 * CARLO * 0 5 * YUKON•KOYUKU
* YUKON * UNDEVELOPED
* * HEALY C•4,
• * AK6NPA2b12 • OULBI
• *
• &3 40,0 *
NENANA RIVER * 146 48,9 *
* &50 * • * • *
* I 5 * YU~O~·KOYUKU KOYUKUK
• o5 211,0 •
* 1'5b 23,'l •
• 25700 * • YUKON * UNUEVELOPEO
• * K~NTEfL RIVER 8•1, * • *
* • • • AKbNPA042'l • FRY ISLAND
* I 5 * YUKON•KOYUKU
* YUKON * UNDEVELOPED
• * MELOZITNA 0•4•
* * * AKoNPA0430 * HEALY
• D b * YUKON•KOYUKU
* YUKON * UNDEVELOPED
• * HEALY D•4,
* * • AK6NPA2b14 • HUGHES
* 0 5 * YUKON•KOYUKU * YUKON * UNDEVELOPED
* • HUGHES A•3,
• * * AK7NPA2o22 • JACK RIVER
* Y 5 * YUKON•KOYUKU
* rUKON * UNDEVELOPED
* * HEALY 8•4,
* * • AKbNPA2b23 * JACK WHITE
• I o * YUKON•KOYUKU * YUKON * UNDEVELOPED
* * 8ETTLES
* * AKoNPA2b24 * JIM RIVER
* 1 5 * YUKON•KOYUKU
* YUKON * UNDEVELOPED • * SETTLES 0•2.
• 65 113,7 *
KO~UKUK RIVER• 154 5b.3 *
* 19950 *
NENANA RIVER
*
*
*
* * b3 48,'l * * 148 51>,9 •
* 1'100 *
* *
* * * bb o.o *
KOYUKUK RIVER• 154 lb,O *
JACK RIVER
* 18700 *
* * * * &3 1<1.7 *
• 148 43,3 •
* 135 *
*
*
*
* • c& 54,0 •
KOYUKUK RIVER• 152 25.0 *
JIM RIVER
* b 7 00 *
* • * •
* bb llb,ll * * 151 11,2 * * 1170 •
* *
*
H *
IS *
1141,0•
*
*
H *
IS *
21>500,0•
•
*
H *
IS *
t'il320,0•
*
*
H *
IS *
31>95,0•
•
* 205,0 *
0 •
211.7 *
*
* 120,0 *
0 *
o7,9 •
*
* 70,0 *
0 *
53,9 *
•
* 2'lb,O •
0 *
290,7 *
*
* H * 100,0 *
IS * 1140000 *
1&900.0• 118,9 •
* •
H *
IS *
405.0•
* *
H *
IS *
41110,0•
* •
t1 *
IS *
442,0•
*
* * 385,0 •
17'lOOO *
4bb,S *
*
* 150,0 *
0 *
135 ,II * •
* 110.0 *
0 •
11>1,8 *
*
'* 0 •
30000 *
30000 *
*
* 0 •
2114000 •
21l4000 *
• •
0 *
114000 *
1111000 *
*
*
0 *
133000 *
133000 *
*
*
0 *
110000 *
110000 *
* •
0 *
28750 *
28750 •
* * 0 •
bSOOO *
1>5000 * •
* 0 *
'lOOO *
9000 *
"
*
0 *
8110000 *
840000 *
*
*
0 *
1070000 *
1070000 *
•
0 * b22000 •
1>22000 *
* • 0 •
581000 *
581000 •
•
*
0 " 482000 "
1182000 *
*
* 0 *
125000 •
125000 •
•
* 0 •
315000 •
315000 •
•
0 *
43000 •
113000 *
*
51178,5
&,52<!0
*
*
* *
*
* 114218 *
111,3.:!& *
25oSO
111.238
<19113,2
17.114
22524
41>,730
200311
1&0.27
8479,8
2b.<l20
2432,0
51>,559
* *
*
* * * *
* •
*
*
*
*
" •
*
*
*
*
*
* *
*
*
*
*
* *
* *
*
YNUUUUU
UNNUUUUNIJ
Ytwuuuu
UNNUUUUVU
YNUUUUU
UNNUUUUNU
YNUUUUU
UNNUUUUNU
NNYYYUY
UYNUNNNYY
NNUUUUU
UNNUYYYYY
YNUUtJUU
UYYUUUNYY
YNUUUUU
UNNUUUUUU
•
*
* • •
* *
*
* • ..
•
* * *
*
* * * •
*
*
* * " * * * * * •
*
*
*
*
* •
* *
* **********************************************************************************************************************************
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Project Listlng(contlnued)
********************************************************************************************************************************** * SITE 10 • PROJECT NAME • LATITUDE •PROJ.PURP.• DAM HT * EXIST.CAP, •EXIST,ENNG•ANUL, COST * ENVIRONMENTAL
* *PRIMARY CO, •NAME OF STREAM •LONGITUDE • STATUS •TOT, STOR• INC. CAP, •INC,ENERGY•ENERGY COST• IMPACT CODE *
* DEP .t.CT\1 • OwNER * OR,AREA * AVE, Q •Pr<R, 110, * TOT. CAP, •TOT ,ENERGY• * * * t:ODE PIV * MAP REFERENCE • (0 M,M) * • (FT} * (KW) * (MnH) * (1000 :S) * *
• • • (D M,M) * • {AC FT) • (Kw) • (MWH) * (S/Mv.H) * SOt:IAL "
• GEOG, AREA • * (SO,Ml) • (CFS) • (FT) * (KW) * (MWH) • * IMPACT CODE *
********************************************************************************************************************************** * At<;7NPA2b25 * JOHN RIVER * b7 5.9 • H • 365.0 * 0 • 0 • 12413 * NNUUUUU *
• I 5 • YUKON•KOYUKU JOHN RIVER • 151 S7,9 • IS • 0 * 31000 • 149000 * 83,312 * *
* YUKON • UNDEIIELOPEO • 2695 • 2622.0• 799.2 • 31000 • 1119000 * * UNNUYYYNY *
* WISEMAN A • 4 * * * * * * *
• • * A~6NPA2blb • JUNCTION ISLAND * bli 52,8 *
RIVER • 15v !9.9 •
112500 •
* I b * YUKON•KOYUKU TANANA
* YUKON • UNOfVELOPfO
* KANTISHN~ 0•1.
* * AK6NPA2&2b *KALTAG RIVER
• I b * YUKON-KOYUKU
* YUKON • U~DEVELOPED
* * NULATO
• 4KbNPA2~27
• I 5
• YUKON
• KANTISHNA RIVER
• YI!KON•KOYUKU
* U'JO£ VELOI'£0
YUKON RIVER
•
* • b4 13,8
* *
* !58 38,9 *
• 296000 *
• * • * ell 115.6 *
KANTISHNA RIV• 150 30.0 *
• 5440
• KANTISHNA RIVER b•l, *
* * * ~~.bNPA2bl7
• I b
• YUKON
• 1\ANVTI
• YU~Dri·KOYUKU
* U'<OE vELOPE:O
* HUGH~S H•i'.
• AKbNPA2b29 * MCKINLEY RIVER
• I b * YUKON•KOYUKU
• YUKON • UNDEVELOPED
• MT MCKINLEY 8•3
• AKb~PA2b!8 * MELOllTNA
* I 5 • YU~ON•KDYUKU
* YUKON * UNDEVELOPED
* NU~Y D-6.
* • AK6NPA2b30 * MELOZITNA RIVER
* 0 5 • YUMON•KOYUKU
• YUKON • U~OEVELOPED
* MELOZITNA 8•4
•
• bb 27,b •
KOYUKUK RIIIER• !53 4,9 *
18000
* ,.
• 63 51.5 *
MCKINLEY Rill~ 151 33.0 *
• 710 *
• • • • • o4 SO,'l
~lLOZIT~A RIV• 155 3q.'l *
* 26 59 •
•
* b5 15,0 *
MELOZITNA RIV• 151l 45.0 •
2020 •
* •
*
H *
IS •
34000.0•
•
*
150,0 •
0 *
113.8.
•
*
H * 120,0 *
IS •20000000 •
19!800.0• 11&.8 * •
*
H *
IS •
7176,0•
*
•
* 115,0 *
0 ..
94,9 •
•
*
H * 200.0 *
IS •37300000 •
16400.0• 16~.!l •
11
IS
• ,.
• •
1255,0•
• •
H *
IS •
1932,0•
•
*
* 320.0 *
0 •
296,7 •
.sso.o *
0 •
2&9,7 *
•
* H • 135.0 •
IS • 1300000 •
1518.0• 128.8 •
* • •
0 •
~32000 *
532000 *
•
u *
2330000 *
2330000 •
•
*
0 * 0 *
3000000 * 13100000 •
3000000 • !3100000 •
• • 0 •
8C:OQO •
82000 *
• •
0 •
.Sb<IOOO *
368000 •
• •
0 *
112000 *
42000 •
•
0 •
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*
* 0 •
13000 *
13000 •
•
*
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394000 •
394000 *
•
0 *
1612000 •
1bl2000 •
• • 0 •
201000 •
201000 *
* •
0 •
2112000 *
2!l2000 •
* •
0 *
117000 •
117000 •
•
103591l
'14.461
327701
25. 15
36324
n.194
23450
11l.S47
8597,5
42.7711
•
*
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* •
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* 28732 *
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•
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UNNUUUUUU
NNUUUUU
UNNUUUUUU
NNI.JYYUY
UNNUUr<NYY
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UNt.UUUUNU
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UNNNYYYYY
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*
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* ..
* •
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*
* • •
•
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• AKb~PA2b32 • NO~ITNA RIVER * btl 22,8 * H • 200.0 • 0 • 0 • 8295.4 • YNUUUUU *
* I 5 * Yt;K0'<-K0VUKU NOft'ITNA RIVER• 153 37,0 • IS * 2200000 • 58000 * 280000 • 29.&26 * *
• YUKON • tJNOEVE!..OPED * 2570 • 3080.0• 179,8 * 58000 • 280000 * * UNNUUUUYU *
* * RUBY 8•2. * * * * * * * ,.
························~·········································································································
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Project Llstlng(continued)
•••******************************************************************************************************************************* * SITE 10 * PROJECT NAME * LATITliLJE •PRUJ.PURP.• OAM HT * EXIST .CAP. •EXIST .ENfiG*ANUL. COST * ENVIRONMENTAL * * * PRIMARY CO. •NAME OF STREAM •LONGITUDE * STATUS, •TOT. STUR• INC. CAP. •INC.ENtRGY•ENEfiGY CO:>T• IMPACT CODE * * DEP ACTV * O~ii\IER * DR.AREA * AVE. G1 •P.,.R. HD. * TOT. CAP. •TOT .ENERGY• • *
* CODE lNV * MAP REFERENCE * (0 M.M) * * (FT) * (KW) * (M~iH) * (1000 $) * *
* * * (0 M.M) * * (AC F T) * (KW) * (MWH) * (S/MWH) * SOCIAL *
* GEOG. AREA • * (SQ.Ml) • (CFS) • (fT) * (Kw) • (MIIH) • • IMPACT CODE *
***********************************************************************************************************************•**********
• AKbNPA2b20 *RAMPART * b5 19.7 * H * 5b5.U * 0 * 0 * !lll5203 • NYUUUUU * * I b • YIJKON•KOYUIIU YUKON RIVER * 151 1.0 * IS •52000000 * 5040000 * 34200000 • 24.713 * •
• YUKON * UNDEVELOPED * 200000 * 112000.0• 444.5 * 5040000 • 34200000 * • UNNUNUUNU *
• * TANANA B-3. * * • * * * * *
* • * * • * * * * • * AKbNPA2b21 * RU~Y * D b * YU~ON•KDYUKU
* YU~ON * UNDEVELOPED
* * RUBY 0•5,
* * * AK6NPA0431 * TEKLANIKA
• I 5 * YUKON•KOfUKU
• YUKON * UNDEVELOPED
* • HEALY 0•6. .. *
YUKON RIVER
* t>4 llS.o •
.. 1~~ 211,0 ..
* 256000 *
* *
*
* * b3 59.0 *
TEKLANlKA RIV• 11l9 33.0 *
* 520 * * •
* * • AKoNPA0432 * TOTATLANIKA RlVEfi * 64 13.3 *
Ro 146 1111.3 • • I 5 * YUKON•KOYUKU TOTATLANIKA
* YUKON * UNOEVELOPEO * * FAIRdANKS A•4 0
• * * AK6NPA0433 *
• I b "
* YUKON *
* *
* *
VACHON ISLAND
YUKOI'<•KOYUKU
UNDEVELOPED
KANTI~HNA I<IVEii
• AKbi'<PAOil34 * ~ALKER CREEK
* I 5 * YUKON•KOYUKU
* YUKON * UNDEVELOPED
* * FAIRBANKS A•5.
* * AKbNPA01135 * YA~ERT NO 2
* D 5 * YUKON•KDYUKU
* YUKON • UNDEVELOPED
* * HEALY C•ll,
* 250 *
* *
* • * &Q so.o *
TANANA RIVER * 152 119,9 *
o-3.
• 44500 *
*
*
•
* * b3 57.0 *
NENANA RIVER * 149 10.0 *
* 2330 *
* • * * * b3 37,9 *
NENANA RIVER * 148 118,9 *
* 1190 * • •
H *
IS
150000,0•
H
*
*
IS *
H
IS
1>90,0•
*
*
* 1140,0•
• •
H *
IS *
35880.0•
* •
H *
IS •
4554.0•
• •
H *
IS *
2305.0• •
80.0 ..
0 *
71.9 *
* * 470.0 *
27~000 *
45b.~ *
*
* 430.0 *
0 *
419.5 *
*
* 120,0 *
0 * 95,9 *
* * 200,0 *
0 *
11>5,8 *
* * 250,0 •
0 *
231,7 *
*
0 *
1.160000 •
460000 •
* *
0 *
57000 *
57000 *
* •
0 * 211000 .•
24000 *
*
*
0 *
426000 *
ll2b000 *
•
* 0 •
35000 •
35000 •
•
*
0 *
1>2000 *
1>2000 •
•
0 *
b400UOV •
1>1100000 *
*
0 •
272000 *
272000 •
* *
0 * 1111000 •
1111000 •
*
*
0 *
2050000 *
2050(10(1 •
* •
0 *
11>1>000 •
166000 •
*
*
0 *
298000 *
298000 *
*
159612
.2'1.970
lb125
59.285
9702.7
65.112
1>0163
29.348
22970
138.37
17231
57.824
*
*
* •
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*
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*
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*
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Appendix B
PUBLIC REVIEW COMMENTS
Federal
State
Alaska Power Administration • •
U.S. Fish and Wildlife Service
B-1
B-3
Alaska Power Authority • • • • • • • • • • . • • • . • • B-4
(j) .
.
. •
Department Of Energy
Alaska Power Administration
P.O. Box 50
Juneau. Alaska 99802
Mr. Tom White (NPDPL)
North Pacific Division
Corps of Engineers
P.O. Box 2870
Portland, OR 97208
Dear Mr. White:
February 12, 1981
Here are our comments on the National Hydropower Study for Alaska. Many
of our comments have already been incorporated into the draft report
through continuing coordination with the Alaska District Office.
This draft report is much improved over a previous draft we reviewed and
appears to adequately address the marketability aspects of the identified
more desirable projects.
We realize that a study of this type, which is based on criteria developed
at the National level, will in some cases cause discrepancies in results.
This particularly becomes apparent when comparing results from the
National Hydro Study with previously published cost data for some Alaska
projects. The results for the Chakachamna Project, for example, indicate
a much lower cost of energy than the Upper Susitna Project. This is a
serious misrepresentation, not supported by previous studies. We suggest
a "qualifier" be included in your report that would point out these
discrepancies and further caution use of the cost figures unless verified
by other studies.
~'le note that in this draft two projects, Tazimina and Grant, have been
added to the list of 59 potential hydropower sites. These sites were
not included in our marketability study. The inclusion of these two
sites increases the power needs that can be met in the Southwest region
from 39 percent to 100 percent. This also affects table 7-2 on page 72.
A copy of the revised table is enclosed.
We are enclosing a marked up copy of your list of 59 sites with some
changes in project ownership based on local knowledge, revision of
energy and capacity figures for the Snettisham Project, and a suggested
deletion of the Gold Creek and Treadwell Ditch projects (#34 and #35)
along with one of the two plans of development for the Thomas Bay Project.
B-1
We look forward to seeing the final report.
Enclosures
Sincerely,
.~7 ./ ....
,/_ ~ -C1ec ~ .. -
Robert J. Cross
Administrator
cc: Colonel Lee Nunn, Corps of Engineers w/enclosures
B-2
2
United States Department of the Interior
IN REPLY REFER TO:
North Pacific Division
Corps of Engineers
Attn: Tom White
P.O. Box 2870
Portland, Oregon 97208
Dear Mr. White:
FISH AND WILDLIFE SERVICE
1011 E. TUDOR RD.
ANCHORAGE, ALASKA 99503
(907) 276-3800
2 MAR \981
We have reviewed the draft report on the National Hydropower Study for
the Alaska Region and have the following comments:
In 1978, we responded to CH 2M Hill concerning their ''Review of South
Central Alaska Hydropower Potential -Anchorage Area" and recommended
several sites as unacceptable for hydropower development because of
their important fishery resources. Four of these sites (Skwentna,
Yentna, Beluga Upper and Coffee) are·included in this draft report as
potential hydropower projects and identified for detailed study. In
recognition of identified fishery resource values, we question the merit
of continuing to list these areas as sites to be studied for hydropower
development unless it has already been determined that no less environ-
mentally damaging alternative energy sources exist. If so, this should
be indicated in the report.
Our comments to CH 2M Hill were for projects in southcentral Alaska only.
Therefore, we have not previously provided comments on the potential
hydropower sites in southwest or southeast Alaska. In southwest Alaska
the three largest projects presented in your report are: Kisaralik,
Tazimina and Grant Lake. Development of these projects would definitely
impact important fishery resources. In southeast Alaska, Anita (Zjmovia
Strait), Harding River, Ketchikan Creek and Mellen Lake (Reynolds Creek)
are areas which would be very sensitive to hydropower developments. We
would recommend that all of the aforementioned sites be eliminated from
further consideration until all other alternatives have been investigated.
B-3
ALASKA I•OWEII AUTHORITY
: 3 WEST 4th AVENUE· SUITE 31 -ANCHORAGE, ALASKA 99501
Alaska District, Corps of Engineers
ATTN: NPAEN-PL-R (Steve Boardman)
Post Office Box 7002
Anchorage, Alaska 99510
Dear Mr. Boardman:
January 16~ 1981
Phone: (907) 277-7641
(907) 276-2715
This letter is in response to your request for comments on the National
Hydropower Study, Volume XXIV, Alaska Region, dated December 1980.
The list of projects under study or construction on page 30 should be
augmented by the addition of:
Haines and Skagway
Bristol Bay
West Creek
Tazimina River
5 MW
18 MW
Both projects are under study by the Power Authority. Two additional
corrections on this page relate to the cormtun1ties served. The market for
Tyee is Wrattgell and Petersburg" while that for Black Bear Lake will be
Klawock, Craig and Hydaburg. Finally, it appears that the capacity of Port
Lions is misstated.
My primary concern with the study is the degree of consistency in project
cost estimates. You suggest on page 56 that computer-aided cost estimates
were overridden, for certain specific projects, by the results of detailed
studies. This has the potential for creating anomalies that may prove very
misleading. A case in point is the Chackachamna Project. Working back from
your annual cost calculations on the computerized form, we calculate an invest-
ment cost of $267 million for Chackachamna. I surmise that this was a computer
generated.estimate, because 1t is much lower than any detailed study would
show. In fact, following is a quote from the March 1962 Status Report of the
Bureau of Reclamation on the Chakachamna Project:
11 The estimated construction cost of the plan of development selected for
this report is $325,239~000, based on October 1, 1961 price levels ...
(Emphasis added.)
The danger here is that the reader of your report will be led to believe
that the cost per kilowatt-hour for Chackachamna is 12 mills while that for
Watana is 18 mills.
I realize the difficulty you must have faced in having the results of
detailed studies in certain cases and nothing but the computer-a;ded approx-
imate methodology for others. I would request, however, that you take another
look at the Chackachamna cost estimate and resultant cost of energy. Also, I
R-4
A1aska District, Corps of Engineers
ATTN: NPAEN-PL-R (Steve Boardman)
January 16. 1981
Page Two
suggest you put a strongly worded and prominent disclaimer on the estimates of
energy cost, explaining that they are very gross. The approach used may be
appropriate for broad categorization of feasible and non-feasible projects,
but the results should not be indiscriminately used for comparison among
projects on the final list.
I think this matter is very important, and I hope you will be able to
respond to my comment. Thank you for the opportunity to review the report.
Sincerely,
' ---'( "~\ ,_\_,_\
Eric P. Yould '
Executive Director
cc: Robert Cross, Alaska Power Administration
North Pacific Division, COE, ATTN: NPOPL (Tom White)
John Lawrence, Acres, (ATTN: System Generation Planners)
B-5
Appendix C
REFERENCES
REFERENCES
, January 1968, "Summary of Alaska Lower Priced Hydroelectric
Potentials -2500 Kl:.J (Continuous Power) and Larger." Alaska Power 1969.
, 1977, "Potential Hydropower sites Near Angoon, Craig, Hoonah,
Hydaburg, Kake, Kasaan, Klawock, Kukwan, Pelican, and Yakutat." Preliminary
Appraisal Report, Hydroelectric Potential for Angoon, Craig, Hoonah, Hydaburg,
Kakae, Kasaan, Klawock, Kuktvan, Pelican, and Yakutat.
Alaska Department of Commerce and Economic Development, March 1978, Alaska•s
Hydroelectric Resources Inventory, Preliminary Report.
Alaska Division of Energy and Power Development, Department of Commerce and
Alaska Power Administration, U.S. Department of Interior, "Hydropower Sites &
Land Withdrawals in Tongass National Forest (as of June 1974)."
Corps of Engineers, Alaska District, 1954, "Potential Power Projects -
Mainland." Harbors and Rivers in Alaska Survey Report. Interim Report No. 5.
Southwest Alaska.
Alaska Power Adminis ion December 1975, Marketability Analysis, Upper
Susitna River Hydroelectric Studies. Report on Markets for Project Power.
Institute of Social and Economic Research, University of Alaska, Electric Power
in Alaska: 1976-1995.
Alaska Power Administration-1977. "Inventory of Potential
Hydroelectric Sites in Alaska." First published in Alaska's Energy Resources,
Volume II: Inventory of Oil, Gas, Coal, Hydroelectric and Uranium Resources.
State of Alaska. Department of Commerce. Division of Energy and Power
Development. October 1977.
Alaska Power Administration, December 1977, "Reservoirs Under 100 Foot Dam and
or Storage Capacity Under 10,000 Acre Feet." This list developed from list
entitled, "Inventory of Dams in the United States" prepared by the Corps of
Engineers.
Alaska Power Administration, February 1978, Analysis of Impact on Hydroelectric
Potential of the Administration's Recommendations for Alaska D-2 Lands.
Alaska Power Administration, April 1977, Analysis of Impact of H.R. 39 on
Hydroelectric Potential of Alaska.
Alaska Power Administration, March 1979, Upper Susitna River Project Power
Market Analyses.
Alaska Power Adminst • Department of Interior, Compiled 1970. Updated
to 1976, "Powersite Land Withdrawals and Better Hydropower Potentials."
Alaska Power Administration, U.S. Department of Interior, June 1974, "Hydropower
Sites & Land Withdrawals in the Chugach National Forest."
C-1
Alaska Power Survey and the Federal Power Commission, May 1974, "Hydroelectric
Developments Existing and Under construction, Feruary 1973", and "Key
Hydroelectric Resources of Alaska." 1974 Alaska Power Survey, Resources and
Electric Power Generation, A Report of the Tecnical Advisory Committee.
Alaska Technical Advisory Committee, May 1974, Alaska Power Survey Resources
and Electric Power Generation.
Alaska Water Study Committee, June 1976, (List of 76 sites). "Alaska Water
Assessment Map Showing Undeveloped Hydroelectric Resources." Alaska Water
Assessment State-Regional Future Water and Related Land Problems.
CH2M Hill, October 1978, Review of Southcentral Alaska Hydropower Potential
Anchorage Area.
CH2M Hill, October 1978, Review of Southcentral Alaska Hydropower Potential
Fairbanks Area.
CH2M Hill, October 1979, Reconnaissance Study of Hydropower Sites Near Cordova,
Alaska.
CH2M Hill, February 1980, Reconnaissance Assessment of Energy Alternatives,
Chilkat River Basin Region.
City and Borough of Sitka. Sitka, Alaska, September 1977, Application for
License, Green Lake Project.
Federal Power Commission, "Existing Hydroelectric Plants-January 1976." The
1976 Alaska Power Survey, Volume 1.
Federal Power Commission, "Summary of the More Favorable Potential Hydroelectric
Sites in Alaska-February 1976," The 1976 Alaska Power Survey, Volume 1.
Federal Power Commission, January 1956, Hydroelectric Power Resources of the
United States Developed and Undeveloped.
Federal Power Commission, 1960, "Developed Hydroelectric Projects in Alaska,
January 1, 1960." Hydropower of the United States-Developed and Undeveloped.
Federal Power Commission, 1960, Hydroelectric Power Resources of the u.s. -
Developed and Undeveloped.
Federal Power Commission, 1976, Alaska Power Survey.
Federal Power Commission, Division of Licensed Projects, Bureau of Power.
"Projects Presently Under License or Which Have Application for License
Pending." Washington, D.C.
Federal Power Commission and Forest Service, u.s. Department of Agriculture,
1947, Water Powers Southeast Alaska.
Federal Power Commission, San Francisco Regional Office, 1960, Alaska Power
Market Survey.
C-2
Federal Power Commission, u.s. Department of Interior, "Potential Hydropower
Sites in Alaska -Individual Developed and Undeveloped by Hajor Drainages and
River Basins and By Geographic Divisions and States," Hydroelectric Power
Resources of the u.s. -Developed and Undeveloped, January 1, 1968.
Harz a Co., October 1979, Black Bear Lake Project.
Harz a Co., October 1979, Cathedral Falls Project.
Harz a Co. , October 1979' Gartina Creek Project.
Harz a Co. , October 1979' Thayer Creek Project.
Economic Development, State of Alaska, October 1977, Alaska Regional Energy
Resources Planning Project -Phase 1, Volume II, (Similar Report Phase 2, dated
1979).
Joint Federal State Land Use Planning Commission for Alaska, July 1974,
Resources of Alaska, A Regional Summary.
National Electric Reliability Council, July 1979, Summary of Projected Peak
Load, Generating Capability and Fossil Fuel Requirements.
Rutherford Associates, September 1979, Revised Preliminary Appraisal Report Tyee
Lake.
R.W. Beck & Associates, January 1956, Resource Study on Power Supply Development
for the City of Ketchikan, Alaska.
R.W. Beck & Associates, March 1974, Analysis of Electric System Requirements
for Petersburg, Alaska.
R.W. Beck & Associates, April 1974, Analysis of Electric Utility System Sitka,
Alaska. Requirements report for the Sitka City and Borough.
R.W. Beck & Associates, June 1977, Swan Lake, Lake Grace and Mahoney Lake
Hydroelectric Projects. Appraisal Report for the Ketchikan public utilities.
R.W. Beck & Associates, August 1977, Virginia Lake Project, Appraisal Report for
the Thomas Bay Power Commission.
R.W. Beck & Associates, November 1975, Thomas Bay Project, Appraisal Report for
the Thomas Bay Power Commission.
R.W. Rutherford Associates, December 1978, Terror Lake Hydroelectric Project
Kodiak Island. Definite Project Report,
State of Alaska, 1973 and 1978, Alaska's Wildlife and Habitat, Volumes I and II.
State of Alaska, July 1974, Alaska Regional Profiles, Southcentral Region.
State of Alaska, 1978, Alaska's Fisheries Atlas, Volumes I and II.
C-3
State of Alaska, Division of Economic Enterprise, 1977, Alaska Power and
Economic Development Program, Volume I, II, and III.
U.S. Army Corps of Engineers, May, 1975, "Inventory of Dams in the United
States." National Program of Inspection of Dams -Volume III.
Alaska District, u.s. Army Corps of Engineers, January 20, 1950, "Potential
Hydropower Developments-Cook Inlet Area," Harbors and Rivers in Alaska Survey
Report, Cook Inlet and Tributaries. Interim Report No. 2.
Alaska District, u.s. Army Corps of Engineers, October 30, 1950, "Potential
Hydropower Projects-Copper River and Gulf Coast," Harbors and Rivers in
Alaska Survey Report, Copper River and Gulf Coast, Alaska, Interim Report No. 3.
U.S. Army Corps of Engineers, Alaska District, 1957, "Potential Hydropower Sites
-Northwestern Alaska," Harbors and Rivers in Alaska Survey Report. Interim
Report No. 6. Northwestern Alaska.
Alaska District, u.s. Army Corps of Engineers, December 1, 1959, "Potential
Power Projects." Harbors and Rivers in Alaska Survey Report, Yukon and
Kuskokwim River Basins, Interim Report No. 7.
Alaska District, u.s. Army Corps of Engineers, Revised September 1961, Summary
of Potential Hydroelectric Power in Alaska.
U.S. Army Corps of Engineers, Alaska District, 1967, Water Resources Development
u.s. Army Corps of Engineers, Alaska District, December 1975 and as revised June
1976, Southcentral Realbelt Area, Alaska, Upper Susitna River Basin, Interim
Feasibility Report, Hydroelectric Power and Related Purposes.
u. s. Army Corps of Engineers, Alaska District, April 1978, Rivers and Harbors
in Alaska Interim Feasibility Report on Hydroelelctric Power and Related
Purposes for Valdez, Alaska.
u.s. Army Corps of Engineers, Alaska District, April 1978, Southcentral Railbelt
Area, Alaska Stage II Checkpoint Report Hydroelectric Power and Related Purposes
for Valdez, Alaska.
u. s. Army Corps of Engineers, Alaska District, September 1978, Index of Surface
Water Gaging Stations.
u.s. Army Corps of Engineers, Institute of Water Resources, January 1979, National
Hydroelectric Power Study Plan of Study.
North Pacific Division, u.s. Army Corps of Engineers, May 1, 1951, "Potential
Hydropower Projects-Tanana River Basin," Harbors and Rivers in Alaska Survey
Report, Tanana River Basin, Interim Report No. 4.
C-4
u.s. Army Corps of Engineers, North Pacific Division, February 15, 1952,
"Existing Power Developments and Potential Power Projects in Southeastern
Alaska," Harbors and Rivers in Alaska Survey Report, Southeastern Alaska.
Interim Report No. 1.
u.s. Army Corps of Engineers, North Pacific Division, February 15, 1952,
"Southeastern Alaska Water Power Projects-February 15, 1952." Harbors and
Rivers in Alaska Survey Report, Southeastern Alaska. Interim Report No. 1.
u.s. Department of Energy and Alaska Power Administration, December 1979,
Bristol Bay Energy and Electric Power Potential Phase I.
u.s. Department of Energy Alaska Power Administration, December 1979, Small
Hydroelectric Inventory of Villages Served by Alaska Village Electric
Cooperatlve.
U.S. Department of the Interior, June 1967, Alaska Natural Resources and the
Rampart Project.
u.s. Department of Interior, January 1968, Lake Grace Project Alaska.
u.s. Department of Interior, January 1968, Takatz Creek Project Alaska.
u.s. Department of the Interior, 1978, Alternative Administrative Actions Alaska
National Interest Lands. Final EIS.
U.S. Department of the Interior, March 1980, Iliamna National Resource Range
Environmental Supplement.
u.s. Department of the Interior, May 1980, Alaska Peninsula National Wildlife
Refuge. Environmental Impact Statement.
U.S. Department of the Interior, May 1980, A Proposal for Protection of Eleven
Alaskan Rivers. Environmental Impact Statement.
u.s. Department of the Interior Geological Survey, 1940-1979, Water Resources
Data for Alaska.
u.s. Geological Survey, 1967, Dictionary of Alaska Place Names.
C-5
British thermal units
dollars
gigawatt
gigawatt-hours
Btu
$
GW
GWhr
Appendix D
GLOSSARY
Abbreviations
Dl
kilowatt
kilowatt-hours
megawatt
megawatt-hours
kW
kWhr
MW
MWhr
AVERAGE LOAD-the hypothetical constant load over a specified time period that
would produce the s arne energy· as the actual load would produce for the s arne
period.
BENEFIT-COST RATIO (B/C)-the ratio of the present value of the benefit stream
to the present value of the project cost stream computed for comparable
price level assumptions.
BENEFITS (ECONOMIC)-the increase 1n economic value produced by a project,
typically represented as a time stream of value produced by the generation
of hydroele'ctric power.
BRITISH THER~AL UNIT (Btu)-the quantity of heat energy required to raise the
temperature of 1 pound of water degree Fahrenheit, at sea level.
BUS-an electrical conductor which serves as a common connection for two or more
electrical circuits. A bus may be in the form of rigid bars, either
circular or rectangular in cross sections, or in form of stranded-conductor
overhead cables held under tension.
BUSBAR-an electrical conductor in the form of rigid bars, located in switchyard
or powerplants, serving as a common connection for two or more electrical
circuits.
CAPACITY-the maximum power output or load for which a turbine-generator, station,
or system is rated.
CAPACITY VALUE-that part of the market value of electric power which 1s assigned
to dependable capacity.
COSTS (ECONOMIC)-the stream of value required to produce the project output.
In hydro projects this is often limited to the management and construction
cost required to develop the powerplant, and the administration, opera-
tions, maintenance and replacement costs required to continue the powerplant
in service.
CRITICAL STREAMFLOW-the amount of streamflow available for hydroelectric power
generation during the most adverse streamflow period.
DEMAh"D-see LOAD.
DEPENDABLE CAPACITY-the load carrying ability of a hydropower plant under adverse
hydrologic conditions for the time interval and period specified of a
particular system load.
DIVERSION-the removal of streamflow from its normal water source such as
diverting flow from a river for purposes such as power generation or
irrigation.
D2
DRAFT TUBE-that section of the turbine water passage which extends from the
discharge side of the turbine runner to the downstream extremity of the
powerhouse structure.
ENERGY-the capacity for performing work.
used is kilowatt-hours and represents
time period (hours).
The electrical energy term generally
power (kilowatts) operating for some
ENERGY VALUE-that part of the market value of electric power which 1s ass~gped
to energy generated.
FEASIBILITY STUDY-an investigation performed to formulate a hydropower project
and definitively assess its desirability for implementation.
FEDERAL ENERGY REGULATORY COMMISSION (FERC)-an agency in the Department of
Energy which licenses non-Federal hydropower projects and regulates inter-
state transfer of electric energy. Formerly the Federal Power Commission
(FPC).
FIFM ENERGY-the energy generation ability of a hydropower plant urider adverse
hydrologic conditions for the time interval and period specified of a
particular system load.
FORCED OUTAGE-the shutting down of a generating unit for emergency reasons.
FORCED OUTAGE RATE-the percent of scheduled generating time a unit is unable
to generate because of forced outages due to mechanical, electrical or
another failure.
FOREBAY-this generally refers to the reservo1r area located immediately
upstream of a dam or powerhouse.
FOSSIL FUELS-refers to coal, oil, and natural gas.
GENERATOR-a machine which converts mechanical energy into electric energy.
GIGAWATT (GW)-one mill"ion kilowatts.
HEAD, GROSS (H)-the difference in elevation between the headwater surface
above and the tailwater surface below a hydroelectric powerplant, under
specified conditions.
HORSEPOWER-mechanical energy equivalent to 550 ft. lbs. per second of work.
HYDROELECTRIC PLANT OR HYDROPOWER PLANT-an electric power plant in which the
turbine-generators are driven by falling water.
IMPOUNDMENTS-bodies of water created by erecting a barrier to flow such as
darns and diversion structures.
INSTALLED CAPACITY-the total of the capacities shown on the nameplates of the
generating units in a hydropower plant.
D3
INTAKE STRUCTURE-a concrete structure arranged to control the flow of water
from a reservoir to the ultimate point of use. This structure usually
contains either intake gates, or large valves, for regulating the rate
of flow and for shutoff purposes.
KILOWATT (kW)-one thousand watts.
KILOWATT-HOUR (kWh) the amount of electrical energy involved with a one
kilowatt demand over a period of one hour. It is equivalent to 3,413
Btu of hea7 energy.
LOAD-the amount of power needed to be delivered at a given point on an~electric
system.
LOAD CURVE-a curve showing power (kilowatts) supplied, plotted against time
of occurrence, and illustrating the varying magnitude of the load during
the period covered.
LOAD FACTOR-the ratio of the average load during a designated period to the
peak or maximum load occurring in that period.
LOW HEAD HYDROPOWER-hydropower that operates with a head of 20 meters (66 feet)
or less.
MEGAWATT (MW)-one thousand kilowatts.
MEGAWATT-HOURS (MWh)-one thousand kilowatt-hours.
MULTIPURPOSE RIVER BASIN PROGRAM-programs for the development of rivers with
dams and related structures which serve more than one purpose, such as -
hyrlroelectric power, irrigation, water supply, water quality control, and
fish and wildlife enhancement.
NUCLEAR POWER-power released from the heat of nuclear reactions, which 1s
converted t~ electric power by a turbine-generator unit.
OPERATING POLICY (Operating Rule Curves)-the technical operating guide adopted
for water resources projects to assure that authorized output of the project
is achieved. Usually in the form of charts and graphs of reservoir release
rates for various operational situations.
OUTAGE-the period in which a generating unit, transmission line, or other
facility, is out of service.
PEAK LOAD-the maximum load in a stated period of time.
PEAKING CAPACITY-the part of a system's cap~city which 1s operated during
the hours of highest power demand.
PENSTOCK-a large water conduit which 1s subjected to high internal pressure
and is fully self-supporting.
D4
PLANT FACTOR-ratio of the averag~ load to the installed capacity of the plant,
expressed as an annual percentage.
PONDAGE-the amount of ~ater stored behind a hydroelectric dam of relatively
small storage capacity used for daily or weekly regulation of the flow of
a river.
POWER (ELECTRIC)-the rate of generation or use of electric energy, usually
measured in kilowatts.
POWER POOL-two or more electric systems which are interconnected and coordinated
to a greater or lesser degree to supply, in the most economical manner,
electric power for their combined loads.
PUMPED STORAGE-an arrangement whereby electric power is generated during peak
load periods by using water previously pumped into a storage reservoir
during off-peak periods.
REALLOCATION-the concept of changing the existing distribution in use of
reservoir storage space to a new distribution. Reallocation of flood
control storage to power storage would reduce reservoir storage space
reserved for temporary storage of flood water and increase the conservation
storage available for power operation.
RECONNAISSANCE STUDY-a preliminary feasibility study designed to ascertain
whether a feasibility study is warranted.
REVERSIBLE PUMP TURBINE-a Francis type hydraulic turbine which is designed to
operate a pump in one direction of rotation, and as a turbine in the
opposite direction of rotation. Good efficiencies can be achieved ~ith
both modes of operation.
RUNNER BLADES-the propeller like vanes of a hydraulic turbine which convert
the kinetic energy of the water into mechanical power.
SECONDARY ENERGY-all hydroelectric energy other than FIRM ENERGY.
SPINNING RESERVE-generating units operating at no load or at partial load with
excess capacity readily available to support additional load.
STEAM-ELECTRIC PLANT-a plant in which the prime movers (turbines) connected to
the generators are driven by steam.
SURPLUS POWER-generating capacity which 1s not needed on system at the time it
1s available.
SYSTEM, ELECTRIC-the physically connected generation, transmission, distribution,
and other faciltiies operated as an integrai unit under one control, manage-
ment or operating supervision.
TAILWATER LEVEL-the water level measured 1n the tailrace area immediately
downstream from a hydro plant.
D5
THERMAL PLANT-a generating plant which uses heat to produce electricity. Such
plants may burn coal, gas, oil, or use nuclear energy to produce thermal
energy.
TRANSMISSION-the act or process of transporting electric energy in bulk.
TURBINE-the part of a generating unit which is spun by the force of water or
steam to drive an electric generator. The turbine usually consists of a
series of curved vanes or blades on a central spindle.
Impulse Turbines-an impulse turbine is one having one or more free jets
discharging into an aerated space and impinging on the buckets of the
runner, means of controlling the rate of flow, a housing and a discharge
passage. The water supplies energy to the runner in kinetic form.
Reaction Turbine-a reaction turbine is one having a water supply case, a
mechanism for controlling the quantity of water and for distributing it
equally over the entire runner intake, and a draft tube. The water supplies
energy to the runner in kinetic form.
Francis Turbine-a reaction turbine having a runner with a large number of
fixed buckets, usually nine or more, to which the water is supplied in a
whirling radial direction and can be designed for operating heads ranging
from 50 feet to 2,000 feet.
Adjustable-Blade Propeller Turbine (KAPLAN)-a reaction turbine having a
runner with a small number of blades, usually four to eight, to which the
water is supplied ~n a whirling axial direction. The blades are angularly
adjustable in the hub.
Fixed-Blade Propeller Turbine-a reaction turbine having a runner with a
small number of blades, usually four to eight, to which the water is
supplied in a whirling axial direction. The blades are rigidly fastened
to the hub.
UNIT EFFICIENCY-the combined overall efficiency of a hydraulic turbine and its
driven generator.
UPRATING-increasing the generating capacity of a hydropower plant by ~ither
replacing existing equipment with new equipment or making improvements to
the existing equipment.
WATT-the rate of energy transfer equivalent to one ampere under a pressure of
one volt at unity power factor.
WHEELING-transportation of electricity by a utility over its lines for another
utility; also includes the receipt from and delivery to another system of
like amounts but not necessarily the same energy.
D6
U.S. Army Corps of Engineers
National Hydroelectric Power Study
Regional Report: Volume XXIII
Hawaii
September 1981
Prepared by:
u.s. Army Corps of
Engineers,
North Pacific Division
P.O. Box 2870
Portland, OR 97140
u.s. Army Corps of
Engineers,
Pacific Ocean Division
Fort Shafter, HI 96858
Prepared for:
u.s. Army Corps of
Engineers,
Institute for Water Resources
Kingman Building
Fort Belvoir, VA 22060
Table
2-1
2-2
2-3
2-4
3-1
3-2
4-1
4-2
4-3
4-4
List of Tables
Hawaii Petroleum Consumption by Basic Industry, 1976 •.
Hawaii's Civilian Energy Use. • • •••
Electrical Consumption for Four 'Hajor Islands
Summarized on the Basis of KWH Used, 1976 •••
Projected Population, Income and Hajor Sector
Earnings (OBERS) in Constant 1967 Dollars, Hawaii
(BEA Area 173). • • • . . . • . . . • • •
Electric Power Capacity and Energy Generated Hawaii,
19 7 8. • • • • • • • • • • • • • • • • • • • • • •
Existing Hydroelectric Plants, Hawaii. ••••••
State Projected Electric Energy Demand Forecast,
Hawaii, 1980-2005. . . • . . • . . . • • . . • . . .
Public Utilities Projected Peak Load and Generating
Capacities, Hawaii, 1979-98 .••.•..••.
Harza Projected Electric Power Demand Forecast,
Hawaii, 1978-2000. . • • • • . .....•
llistorical Installed Capacity and Peak Load, Hawaii,
1968-19 7 8. • . . • . . . • • • . . . . . . . • .
4-5 Planned Additions to Electric Generating Capacity by
Public Utilities, Hawaii, 1979-98 ••.••..
4-6 Historical Electricity Demand, Hawaii, 1968-78.
7-1 Preliminary Estimates of Potential Hydropower
Projects, Hawaii. • •••••••.••.••••
7-2 Sites Deleted During Stage 3 ..... .
8-1 Hydropower Development Plan for Hawaii. • • • ••
iv
2-5
2-6
2-7
2-9
3-4
3-6
4-2
4-3
4-4
4-5
4-6
4-8
7-3
7-7
8-6
Contents
PREFACE
LIST OF TABLES
LIST OF FIGURES
1. REGIONAL OBJECTIVES
2. EXISTING CONDITIONS
2.1 General Area Description
2.2 Climatology and Hydrology ••
2.3 Economics of Area
2.4 Major Energy Users
2.5 Future Development
3. EXISTING ENERGY SYSTEt-1S
3.1 Existing Energy Systems Excluding Hydropower
3.2 Role of Existing Hydropower Within Existing
Energy System
4. DEMAND SUHMARY •
4.1 Capacity
4.2 Energy ••.•
5. HETHDOLOGY •
5.1 Regional Procedures and Criteria
6. PUBLIC INVOLVE.HENT •
6.1 Role of Public Involvement
6.2 Public Meetings
7. INVENTORY
7.1 Stage l, 2 and 3 Results
7.2 Stage 4 Inventory .
8. EVALUATION •.•.•.
8.1 Regional Development Plan •
8.2 Schedule for Development
8.3 Feasibility of Development Plan .
8 • 4 Summary • • • • • • • . • • • • • •
Page
i
. iv
v
l-1
2-1
2-1
2-3
2-4
2-5
2-8
3-1
3-l
3-5
4-1
4-l
4-7
5-1
5-1
6-1
6-1
6-1
7-1
7-l
7-2
8-l
8-l
8-2
8-2
8-s
APPENDIX Summary Listing of Potential Hydropower Projects A-1
iii
Figure
2-1
7-1
List of Figures
Location Map -State of Hawaii • • • • • • • • • • ••
Locations of Potential Hydroelectric Projects, Hawaii
v
2-2
7-4
Chapter 1
REGIONAL OBJECTIVES
Currently and in the foreseeable future, the Hawaii region will be
almost wholly dependent upon imported petroleum products for generation of
power in the public utility system. The purpose of this regional study is
to document the role of hydroelectric power in the Hawaii region, both
currently and in the foreseeable future. The report will not recommend pro-
jects for authorization of construction by the Corps of Engineers. However,
the report will present information on those potential projects which should
be considered for continued study consistent with the following objectives:
1. Increase the energy self-sufficiency of the region.
2. Assess the physical potential for increasing hydroelectric power
capability and generation.
3. Determine the potential for increasing hydroelectric generating
capacity by development of new sites and by adding generating facilities
to existing water resource projects.
4. Assess the general environmental and socioeconomic impacts of
hydroelectric power development.
5. Provide for maximum feasible utilization of the energy potential
derived from the region's water resources.
1-1
Chapter 2
EXISTING CONDITIONS
2.1 GENERAL AREA DESCRIPTION
For the National Hydroelectric Power Study, the Hawaiian Archipelago
constitutes the Hawaii Region. The Hawaiian Archipelago extends some 1,523
miles over the North Pacific Ocean, between the islands of Midway on the
west and Hawaii on the east. The archipelago consists of a chain of moun-
taintop islands, islets, pinnacles and reefs, all rising thousands of feet
from the ocean floor. A large part of the Pacific Ocean surrounding Hawaii
has depths from 16,000 to 20,000 feet. Except for Midway Island, the archi-
pelago is under the jurisdiction of the State of Hawaii, the 50th State
admitted to the Union, the 47th in geographic area and 40th in population.
Midway has no potential for hydropower development, so the study area
following comprises only the State of Hawaii.
The State's eight principal islands (with their areas in square miles)
are Niihau (73), Kauai (553), Oahu (608), Molokai (261), Lanai (140),
Kahoolawe (45), Maui (729), and Hawaii (4,038). These islands form a
400-mile-long arc at the southeastern end of the archipelago and comprise
more than 99 percent of the region's land area. Of the eight islands,
Kahoolawe is barren, uninhabited and under military control; Niihau is pri-
vately owned and little developed. The other six islands of Kauai, Oahu,
Molokai, Lanai, Maui, and Hawaii, therefore, constitute the principal study
area. The island of Oahu, which is the third largest in land area, is the
social, cultural, economic, and military center of the State. The study
region is shown on Figure 2-1.
The islands and mountains that constitute the Hawaiian Archipelago have
been built almost entirely by volcanic activity. Each island is the top of
an enormous volcanic mountain, modified by stream and wave erosion and minor
amounts of organic growth. The geology is predominantly igneous, with lava
basalts and sporadic occurences of pyroclastics comprising the majority of
the rock types. The decomposition of lava and pyroclastics results in the
residual, lateritic soils found blanketing most of the islands.
Constant erosion has changed the topography of the islands from huge,
gently sloping volcanoes to dissected and incisioned cliffs, valleys and
basins. The topography of many of the drainage areas is characterized by
relatively steep stream courses and steep, rugged basaltic formations. As a
result, the atreams generally do not meander as they traverse alluvial
areas. In areas of the State which are geologically youthful, few if any
perennial streams are found. For example, on the island of Hawaii, 710
intermittent streams reach the sea along three-fourths of the coastline, a
distance of about 225 miles.
2-1
N
I
N
tllO'
Kauai
City and County
of Honolulu (j(,;.'r'~ .. .,.
0 I N
Molokai County of Maui
KAU~ /"'>.._ Maui
HONOLULU
lanai·<":"\
LANAICITYV
Kahoolawe
~J\0
v'' ~~~-----
t58'"
Figure 2-1
LOCATION MAP-STATE OF HAWAII
156.
20.
2.2 CLIMATOLOGY AND HYDROLOGY
In general, the climate of the Hawaiian Islands is characterized by a
two-season year (summer and winter), mild and uniform temperature, stri-
kingly marked geographic differences in rainfall, generally humid con-
dition, and by a general dominance of tradewind flow from the northeast.
During the five-month summer from May through September, tradewinds prevail
80 to 95 percent of the time. During the seven-month winter from October
through April, the prevalence of the tradewinds decreases to 50 to 80 per-
cent. Although the trade-winds produce most of the annual rainfall over the
Hawaiian Islands, it is during the absence of these winds that most of the
flood-producing rainfall occurs. In particular, storms from the south which
are known as "Kona" storms produce the damaging floods in Hawaii. These
storms usually occur during the winter months.
Much of the rainfall in Hawaii results from orographic effects of the
northeast tradewinds, the most prominent feature of air circulation in the
islands. However, major storms are almost always associated with a migra-
tory low pressure area accompanied by widespread heavy rain and southerly
winds. In the open ocean, at the latitude of the Hawaiian Islands, the
average annual rainfall is approximately 25 inches. The actual average at
70 inches indicates about 45 inches of rainfall is orographically extracted
from moisture-bearing air. These effects are evident from the annual rain-
fall maps, which show the tremendous depths of rainfall deposited in moun-
tainous areas and the large variation in rainfall between the mountain and
coastal areas. In many mountainous areas of the State these depths exceed
240 inches. At Mt. Waialeale, on Kauai, the average annual rainfall totals
486 inches.
The average rainfall is often highly variable from one year to another.
Even in areas where the rainfall is very high and the monthly averages are
all above 10 inches, the rainfall of some months may vary by 200 to 300 per-
cent from one year to another and there may be some months with only 1 or 2
inches of rain. With such a high variability of rainfall, it is inevitable
that there are occasional droughts. Drought conditions are prevalent when
the winter rain fails. Although such a deficit of winter storms can affect
any portion of the State, the impact is severest over the normally dry areas
dependent chiefly on these winter rains. In these localities, the small
amount of rainfall that occurs during the usually dry summer season is
insufficient to prevent severe drought.
Steep streams extending from mountainous rainfall belts to the shoreline
are characteristic of the topography and relatively small geographic area of
the Hawaiian Islands. There are no large watershed areas with complex
stream systems comparable to continental areas, but only relatively small
drainage basins, usually consisting of one principal stream with minor tri-
butaries. As most streams have only a few branches generally located in
their upper reaches, the water quickly finds its way to the sea. As a
result, streamflows are generally very flashy in nature. ~tinimum flows may
consist principally of groundwater seepage and spring discharges. Maximum
flows result from heavy rains and reflect the rapid surface runoff typical
of Hawaii's mountainous areas.
2-3
2.3 ECONOHICS OF AREA
Hawaii is a prosperous state with growing population and economy.
Between 1950 and 1978, the total resident population increased by over 79
percent, from 500,000 to 897,000. The gross state product increased tenfold
during this same period, from $900 million to $9 billion. The three largest
contributors to the State's economy are tourism, Federal expenditures, and
agriculture. The bulk of agricultural activity is in the production of
sugar and pineapple. The most rapid growth in the past decade has been in
the tourist industry. Tourist arrivals increased from 243,216 annually in
1959 to 3,670,309 in 1978. Visitor expenditures have grown by an average of
over 17 percent annually since 1959, when they amounted to $109 million.
Estimated 1978 visitor expenditures were over $2 billion. While visitor
expenditures increased by a factor of 20 over this period, defense expen-
ditures only tripled. The trend in tourist industry growth ~Nill probably
continue, although at a slower pace, together with the State's economy in
general.
Hawaii's locational advantages and climate are apparent to the visitor
industry and the military establishment. Its mid-Pacific location also has
important trade and finance implications. The island of Oahu has about 81
percent of the population of the State, and includes the major military
installations. Oahu also has a considerable agricultural and food pro-
cessing industry and the largest regional tourist destination area, Waikiki
beach. The other islands, sometimes referred to as the Neighbor Islands,
do not have as diversified an economic base. In the past their economies
have centered on agriculture and attendant food processing but, employment
in these two sectors has been on the decline. The growth in the tourist
industry, however, has stimulated the Neighbor Islands economies as well as
the State's economy.
The 1970 Census recorded a labor force of 346,859 of which 337,595
(49,785 in the military) were employed. Between 1940 and 1970 the number of
employed persons almost doubled. During this same period, agricultural
employment fell from 55,000 to 13,000. By occupation, one out of every six
workers is classified as either professional or technical. Activities in
the 1970 employment with large number of workers are services (82,000),
government (70,000), retail trade (50,000), and manufacturing (31,000).
Labor union membership was estimated at 82,000 in 1970.
From a cursory viewpoint, it may appear that the Hawaiian Islands
are insulated from other economies in the mid-Pacific area and should exhi-
bit stable employment. On the contrary, growth in the tourist industry and
strategic shifts in military deployment link Hawaii's economy to other
Pacific Basin economies and to the global military situation.
Information from U. s. Census of Population reports indicates that the
number of employed persons in the State grew at over 2 percent a year during
the decade of the 1950's and increased to an annual rate of over 3 percent
during the 1960's. This State growth pattern strongly reflects the average
annual growth rate of about 3-1/3 percent experienced by the City and County
of Honolulu for both decades. The Counties of Hawaii, Maui, and Kauai have
had a somewhat different experience. During the decade of the fifties
these counties experienced a continuing decline of employment in the a~ri-
2-4
cultural sector, which resulted mainly from the impact of mechanization.
Though this decline in agricultural employment still continues, the develop-
ment of a significant tourist industry in these counties has expanded
employment over the past decade.
2.4 MAJOR ENERGY USERS
Hawaii derives 92 percent of its energy from petroleum. Table 2-1 shows
consumption of petroleum in Hawaii by basic industry.
Table 2-1
HAWAII PETROLEUM CONSUMPTION BY BASIC INDUSTRY, 1976
User Category
Air Transportation
Ground Transportation
Water Transportation
Military Transportation
Military (Other)
Industrial/Commercial
Residential
Other
Total
Percent of Total
27.4
15.6
3.5
8.4
9.2
14.9
13.1
7.9
100.0
Source: State Energy Office consultant's unpublished report.
Combined transportation is by far the largest energy consuming industry.
Two of Hawaii's largest industries stand out in this table; tourism, which
is Hawaii's largest industry, accounts for the majority of the 27 percent
consumed by air transportation and a significant portion of the 16 percent
used by ground transportation; the military establishment, which is a major
industry in Hawaii, accounts for almost 18 percent of the total petroleum
consumption. Table 2-2 shows the major civilian energy users in Hawaii.
The two largest users, overseas airlines and residents (home and car), con-
sume more than half of the State's energy. One quarter of the State's
petroleum consumption is for electricity generation.
In 1976, about half of the State's electrical energy was consumed by
residential users. Other major electrical energy users included retail
(7.3%), hotel (6.7%), institutions (5%) and manufacturing (4.8%). The con-
sumption of electricity for the State and four major islands is summarized
in Table 2-3. As displayed in that table, users on the island of Oahu con-
sumed 85.2 percent of the State's total electricity, while users on the
islands of Hawaii, Maui, and Kauai consumed 6.6, 5.5 and 2.7 percent,
respectively. Consumption of electricity on the island of Molokai amounts
to less than one-half of 1 percent of the State's total and is therefore
excluded.
2-5
N
I
0'
Table 2-2
HAWAII'S CIVILIAN ENERGY USE
(B!!I!on BTU'sl
Direct E lectr lea I C I v l I Tan and Gas Mfrs. and Total Percent of
End Users Del lverles ut!lltles PX Service Sta. Distributors Total
-~----·---· ---•··---·-----~~--~---~·~--· ·------··
Overseas alrl'nes 56,128.9 NO 64.0 1/ NO 56,192.9 29.5 -Residents: home & car ND 30,548.7 18,237.0 2,286.0 51 '071 • 7 26.8
Agriculture, Inc I • process 7,673.0 371 .9 160.0 NO 8,204.9 4.3
Overseas waterborne 8,056.4 NO 50.0 NO 8,106.4 4.3
Commercial and Industrial 2,636.0 2, 941 .o o.o 2,343.0 7, 920.0 4.2
Wholesale/retail ND 4, 562.4 1,406.0 NO 5,968.4 3.1
Local air! lnes 5,349.6 ND 31 .o 1/ NO 5,380.6 2.8 -Hotel NO 4,362.7 128.0 NO 4,490.7 2.4
0! I company use 3,861.9 NO NO NO 3, 861 .9 2.0
Construction 2,592.2 ND 1,194.0 NO 3, 786.2 2.0
Institutions NO 3,101 .9 401 .o NO 3,502.9 1 .8
Other (uses 'dentlfled) 6,259.2 15,778.4 3,639.0 78.0 25,754.6 13.5
Unidentified uses of o.o o.o 6,359.0 3! o.o 6,359.0 3.3
gaso I 1ne 2/
-~-----------------
Total 92,557.2 61 '667 .o 31,669.0 4' 707 .o 190,600.2 100.0
-------------~ -----·-~--------~-------------~--~------
Source: "Energy Use ln Hawaii", Department of Planning and Economic Development, State of Hawaii, Nov. 1977.
Notes: ND -Not defined as an end user by fuel or energy distributors.
1/-A1 rllnes allocated between domestic and forelgn and local airlines on same proportion as direct deliveries.
2/-Un'dentlfled uses of service station del lverles amount to 20.0 percent of the total motor gasoline and
'nclude usage by non-taxed federal, state, and county veh'cles, ambulances, and motorcycles.
N
I
""
Table 2-3
ELECTRICAL CONSUMPTION FOR FOUR MAJOR ISLANDS SUMMARIZED ON THE BASIS OF KWH USED,1976_!_/
(Thousands of kWH>
----------
Total
User Category .Amount Percent Oahu Hawaii Maul Kaual
-----------------· -· --------------------~--------
Residential 2, 726,795 48.7 2, 368, 52 5 5 I 158,403 143,145 56,722
Retail 406,338 7.3 346,153 32,695 22,681 4,809
Hotel 374,141 6.7 261,933 49,506 39,129 23,573
Manufacturing 268,623 4.8 259,955 3, 940 3,458 1,270
Institutions 277,728 5.0 246,471 15,788 8,455 7,014
Communications 153,240 2.7 133,845~ 6,457 6,304 6,634
Food processors 99,399 1 .8 76,225 6,161 16,413 600
Street I lghtlng 98,619 1 • 7 74,457 16,088 5,804 2,270
Agriculture 30,288 0.5 10,019 11 '714 3,990 4,565
Military 8,917 0.2 2/ (730, 000)2/ -3/ -3/ 8,917 ~
Other 1 152,561 20.6 992,891 737 59,472 39 ,4_?~-
Total 5,596,649 100.0 4, 770,474 361 ,489 308,851 155,835
Percent 100.0 85.2 6.6 5.5 2.7
----------------~------------
Source: State Energy Office consultant's unpublished report.
Notes:
1/ Molokal not Included above amounted to 17,769 kWh !n 1975, wh!ch would add 0.3 percent to total of alI
Islands.
2/ For Oahu, military accounts are Included In above breakdown.
~ Military on Hawaii and Maul relatively Insignificant.
4/ Kaual military separately reported; not distributed by user category as done for Oahu.
~ Includes military housing and base operations. On Maul and Hawaii mil ltary use Is not a signifi-
cant factor.
6/ On Oahu Includes military bases devoted to communications.
2. FUTURE DEVELOPMENT
Forecasts of regional demographic and economic growth are taken from the
OBERS Series E projection [3]. Series E refers to the latest detailed
regional and national projection of population, employment, and earnings up
to the year 2000. Projections are for the Bureau of Economic Analysis (BEA)
economic area 173, encompassing all of the islands in the State of Hawaii,
and are summarized in Table 2-4.
Although the OBERS population projections are somewhat low, projections
of earning and income are useful to show the relative magnitude of earnings
in various industrial sectors. OBERS forecasts average annual growth in
earnings and total personal income at 3.5 and 3.6 percent, respectively,
between 1970 and 2000. Trade, services, and government sectors are expected
to have the highest industrial sector earnings. Per capita income in Hawaii
was higher than the national average in 1970, and is expected to remain so
throughout the forecast period. The disparity between the national average
and Hawaii per capita incomes is expected to decrease over time. Between
1970 and 2000, per capita income is expected to grow at 2.5 percent
annually.
2-8
Table 2-4
PROJECTED POPULATION, INCOME AND MAJOR SECTOR EARNINGS(OBERS)
Agriculture
Mining
Construction
Manufacturing
Transportation utilities
Trade
Finance
Services
Government
Total Earnings
Total Personal Income
HAWAII (BEA AREA 173)
(Constant 1976 Dollars)
1980
107
0
317
255
329
549
262
712
1, 211
3,741
4,555
Total Population (thousands) 847
Per Capita Income ($)
Per Capita Income
Relative To u.s.
5,375
1.12
YEAR
1985 1990 2000
(Earnings in million $)
110
0
370
295
399
643
324
896
1,443
4,483
5,502
911
6,042
1.11
114
0
432
342
483
752
400
1,127
1, 721
128
0
580
455
697
1,035
598
1, 721
2,431
5,372 7,646
6,645 9,575
979 1,085
6, 791 8,823
1.10 1.08
Source: 1972 OBERS Projections, Regional Economic Activity on the u.s.,
Series E Population, u.s. Department of Commerce, Bureau of Economic
Analysis, 1974.
Note: Sum of sector earnings may not equal the total because of discrepan-
cies in OBERS data.
2-9
References
1. Department of Planning and Economic Development, State of Hawaii, 1977,
Energy Use in Hawaii.
2. u.s. Army Engineer District-Honolulu, 1977, Hydroelectric Power, Plan of
Study, Harbors and Rivers in Hawaii.
3. U.S. Department of Commerce, Bureau of Economic Analysis, 1974, 1972 OBERS
Projections, Regional Economic Activity in the u.s., Series E Population,
USGPO, Washington, DC.
2-10
Chapter 3
EXISTING ENERGY SYSTEMS
3.1 EXISTING ENERGY SYSTEMS EXCLUDING HYDROPOWER
Nuclear
There are no nuclear power plants in the State of Hawaii. The technology
for producing power on a commercial basis from the fission process is well
developed but is economical only in large-scale units. Even the smallest
commercial reactors are too large for integration into the region's electri-
cal systems before the turn of the century.
Oil
Hawaii derives 92 percent of all energy from petroleum. More than half of
it is used for transportation in the form of jet fuel and gasoline. About 25
percent of it is used for the generation of electricity.
There are a total of five utility companies servicing the main populated
islands. All of the companies are investor-owned but are regulated by the
State Public Utility Commission. Each of the islands is served by indepen-
dent power systems. There is no interconnection of power between the
islands. The utility companies are:
Island
Oahu
Hawaii
Kauai
Maui-Lanai
Molokai
Company
Hawaiian Electric Company (HECO)
Hawaii Electric Light Company (HELCO)
Kauai Electric Division of Citizens Utility
Company (KED)
Maui Electric Company (MECO)
Molokai Electric Company (MOECO)
The largest company in the State is Hawaiian Electric Company (HECO).
Two companies on neighbor islands, Maui Electric and Hawaii Electric Light,
are wholly owned subsidiaries of HECO. The island of Lanai is serviced by
Maui Electric but the generating plant and most of the distribution lines are
owned by the privately-owned Dole Company.
These five oil-burning utilities generated 6,541 GWh of electricity in
1978, 90.5 percent of the State's total electric power. The major generating
equipment in Hawaiian Electric Company's system is designed to burn residual
fuel oil. Even with today's critical oil situation, oil remains Hawaii's
most economical source of energy. Alternative energy sources including
biomass (chiefly the sugarcane waste, bagasse), wind, geothermal energy,
refuse, and ocean thermal energy conversion (OTEC) will be developed to
reduce dependence on oil. However, in the foreseeable future, oil is
expected to be the main source of electrical energy.
3-1
Coal
Major economic and environmental problems will be encountered if petro-
leum fuels are to be replaced by coal. Coal is expensive in Hawaii because
it must be imported from overseas. In addition, for large-scale seaborne
transport of coal to power plants in Hawaii, a new ocean bulk handling
system, port facilities, unloading and storage areas, and a surface transpor-
tation system from dockside to generation plant would have to be built at a
large investment cost. The environmental problems would arise from the fact
that, because of the higher impurities content, control of environmentally
unacceptable pollutants such as sulfur dioxide and particulates is more dif-
ficult, and large quantities of ash require disposal.
Material
Hawaii obtains about 7 percent of its energy by burning waste material.
Electrical generation in the State of Hawaii was first begun in the sugar
mills to power the processing of sugar and has evolved along with these
agriculture-based origins. Power is produced by the agricultural processing
power plants by burning a residual product of sugarcane, bagasse. In 1978,
private companies generated 687 GWh of electrical energy, mainly from
bagasse, or 9.5 percent of the total electric energy generated in the State,
which was 7,228 GWh in that year. In 1978, bagasse supplied 38 percent of
the electrical energy of the island of Hawaii and 23 percent of the island of
Kauai. A 12 MW bagasse power plant was completed in 1980, forming an
integral part of the Lihue Sugar Plantation facilities in Kauai. The power
plant, built under a cooperative agreement among Foster-Wheeler Corporation,
AMFAC and Kauai Electric, will annually produce 55.6 GWh of electrical
energy. Refuse is another potential source of energy. The City and County
of Honolulu is considering implementation of a solid refuse treatment plant.
If constructed, the power plant is expected to produce 48 HW of power,
totalling 4 percent of Hawaiian Electric's installed capacity.
Geothermal Energy
Natural heat from the earth shows great long-range potential for Hawaii's
energy future. Economic comparisons generally show that geothermal energy is
competitive with conventional energy sources. High-temperature water can be
used for power generation, while water in the intermediate temperature range
may find application in manufacturing processing, desalting of sea water, and
agriculture. Geothermal environmental problems are relatively minor;
potentially, there could be some impact in the form of noxious gases, noise
from exhaust steam, ground subsidence, and water contamination.
Practically all potential developable geothermal energy is located in the
Island of Hawaii. Although the amount of recoverable geothermal energy is
still unknown, a test well (HGP-A) was drilled 6,450 feet into the eastern
rift of Kilauea volcano on Hawaii Island in 1976 to explore geothermal poten-
tial. Construction of a 3 MW geothermal power plant to utilize the steam
from HGP-A, which is funded by the Department of Energy, began in January of
1980. The Hawaii Electric Light Company has agreed to purchase at least 2
3-2
MW of energy for the first two years the generator operates. The first pro-
duction of electricity from geothermal energy is scheduled for mid-1981. If
huge reservoirs are found yielding greater energy than is needed on the
Island, breakthroughs in undersea transport of energy will be necessary before
power can be transmitted to the other islands. Hawaiian Electric Company is
currently investigating the feasibility of placing undersea power transmission
cables between the islands.
Wind
Enormous amounts of energy are contained in the persistent trade winds
that sweep the Hawaiian Islands. Wind power is a renewable natural energy
resource and has the advantage of generating no noxious substances. It shows
excellent potential for providing a significant percentage of the future
energy requirements of Hawaii. The best wind locations in the Hawaiian
Islands include Kahuku on Oahu, Kahua Ranch on Hawaii Island, West Molokai,
and McGregor Point on Maui. A 200-kW wind machine has been built at Kahuku,
partially funded by the U.S. Department of Energy. The model MOD-OA machine
used here was built and erected by Westinghouse Electric Corporation.
Hawaiian Electric has an agreement with Windfarms Ltd. to purchase 80 MW of
wind generated electricity which is expected to be on line in three to four
years.
Ocean Thermal Energy Conversion (OTEC)
Hawaii has warm surface water and deep cold water near shore the year
round. The technology of OTEC would use this thermal energy differential to
produce electricity. Should OTEC systems become a practical reality, Hawaii
could become energy selfsufficient. A small demonstration plant, Mini-OTEC,
has proved successful and produced 50 kW of electricity. Commercial OTEC's
would range in capacity from 200 MW to 400 MW at an estimated power generation
cost of as low as 4 cents per kWh. However, problems of marine fouling of
equipment and transmission of the electric energy remain to be overcome. In
addition, recent funding limitations of the Federal government will severely
constrain future applied research and development of OTEC.
Summary
In the State of Hawaii electric power is generated on the six developed
islands of Oahu, Hawaii, Kauai, Maui, Lanai and Molokai. Each of the islands
has its own electrical system, and there is no interconnection of power
transmission lines between the islands. Most of the State's power is gener-
ated by the oil-burning utility companies. In 1978, these companies
generated 92.4 percent of the electric power (excludes hydropower). The
remaining 7.6 percent was generated mainly by the sugar companies for their
own consumption.
3-3
All electric power on the island of Molokai is generated by the Molokai
Electric Company. On the island of Oahu, Hawaiian Electric Company
generated 98 percent of electric power in 1978. The remaining 2 percent of
the island's total electricity was produced by three sugar companies; Oahu,
Waialua, and California and Hawaii. On the other major islands private com-
panies generate a much more significant portion of the electric power; in
1978, private companies produced 47.2 percent of the total nonhydropower on
the island of Hawaii, 27.4 percent on the island of Kauai, and 18.4 percent
on the islands of Maui and Lanai. Table 3-1 displays the capacity and energy
generation of the existing electric system.
Table 3-1
ELECTRICAL POWER CAPACITY AND ENERGY GENERATED HAWAII, 1978
-------~-
Entire System l/ NonHydroelectric 2
Percent of Total Percent of Total
Total Utility Private Total Utility Private
-----~·-·
Oahu Island
Installed capacity, !>fW 1,236 98.0 2.0 1,236 98.0 2.0
Energy generated, GWh 5, 723 98.0 2.0 5,723 98.0 2.0
Hawaii Island
Installed capacity MW 163 65.0 35.0 159 64.5 35.5
Energy generated, GWh 558 54.9 45.1 527 52.8 47.2
Kauai Island
Installed capacity MW 106 59.0 41.0 98 63.4 36.6
Energy generated, GWh 299 61.4 38.6 253 72.6 27.4
Maui Lanai Islands
Installed capacity MW 142 59.3 40.7 137 61.5 38.5
Energy generated, GWh 619 67.4 22.6 589 81.6 18.4
Holokai Island
Installed capacity ~fW 7 100.0 7 100.0
Energy generated, GWh 29 100.0 29 100.0
State of Hawaii
Installed capacity j\fW 1,654 88.9 11.1 1,637 89.6 10.4
Energy generated, GWh 7. 228 90.5 9. 5 7,121 92.4 7.6
Notes:
1 "State Energy Plan", Department of Planning and Economic Development,
State of Hawaii, September 1980.
Jj Derived from Table 3-2
3-4
3.2 ROLE OF EXISTING HYDROPOWER WITHIN EXISTING ENERGY SYSTEM
Relationship of Hydropower Within Existing System
Hydropower facilities were originally installed to supplement the needs
of the plantation industry. Only three islands now have developed and
operating hydropower plants. These are Maui, with 7.1 MW installed capacity;
Kauai, with a 7.9 MW capacity; and the island of Hawaii, with 4.2 MW capa-
city. Of the 20 operating and retired hydropower plants on the islands, 18
are owned by sugar plantations for their own industrial use, and two are
owned by a utility company. Only 13 hydropower plants are operating in the
State. Their total installed capacity is 19.2 MW, producing an average
energy of 107.1 GWh per year. Hydropower accounted for 1 percent of the
State's total electric power in 1978. An inventory of hydropower plants in
the islands is shown in Table 3-2.
Hawaii Electric Light Company, Inc. (HELCO), the utility which serves the
island of Hawaii, is a subsidiary of HECO. HELCO is also the only utility
company that operates hydropower plants. The plants are located near Hilo,
the largest area of consumption. The hydropower plants operated by the sugar
plantations are largely part of irrigation systems, and power generation is
dependent to some extent on seasonal rainfall and crop irrigation priorities.
Marketing and Regulations
There is no electric reliability council in the State of Hawaii. The
State is not serviced by a Federal power marketing agency since there is no
Federal power marketed in Hawaii. However, any potential Federal power mar-
keting activities will be performed by the U.S. Department of Energy.
Currently there are no hydropower plants in the State licensed by the Federal
Energy Regulatory Commission (FERC). Licensing is required for nonfederal
development in the following cases: (1) development is on an historically
navigable stream or a stream which could reasonably be improved for
navigation; (2) development is on Federal land; or (3) energy is transmitted
interstate. FERC has enacted a new rule to permit owners of small hydropower
projects (5 MW or less) to apply for exemption of licensing requirements pro-
vided the site is not on Federal land and does not require construction of a
new dam.
Hydropower facilities operated by utility companies are regulated by the
Public Utilities Commission (PUC) of the State of Hawaii under the Department
of Budget and Finance. The PUC does not regulate the hydropower plants owned
by sugar companies if the sole use is industrial. However, when sugar com-
panies sell excess power to utilities for public consumption, the rates must
be approved by the PUC.
Parameters Governing Use of Existing Hydropower
Hydraulic turbines do not perform well when actual flow is substantially
different from the design flow. In Hawaii, since most of the runoff comes
during the winter months (November through March) existing turbines are not
3-5
w
1
0\
Table 3-2
EXISTING HYDROELECTRIC PLANTS
----s-tatIc lnstarre;r--Averag-e· Annual First
Island and Owner head capac! ty Energy year
location Stream Owner class (feet) ( kW) ( Glh) operated -
HawaiI
Walnaku Mi II Mall I 1-CPC p 200 60* ----Pre-WW
Puueo Wa II uku HELCO I 400 2,250 19.0 1918
Waiau Waf I uku HELCO I 322 1' 100 9.2 1921
Papal kou Mi II Honol i i HCPC p 207 150* ----Pre-WW II
Hakalau Mill Haka I au/Ko I ekol e HCPC p 265 75* ----Pre-WW II
Paauhau Lo. Hamakua Ditch PASC p 473 150* ----N.A.
Honokaa Lo. Hamakua Ditch HOSU p 415 800 3.0 N.A.
Union Kohala Ditch KOSC p 565 500* ----1940
Haw! Koha Ia Ditch KOSC p 371 350* ----1923
Maul
Kauaula Kauau Ia PIMC p 535 500 2.0 1918
Paia Wa i I oa Dl tch HACS p 260 800 2.8 1912
Kaheka Wai loa Ditch HACS p 660 5,800 25.0 1924
Kauai
Wainlha Walnlha MBSC p 565 3,600 24.0 1906
Waimea Waimea KESC p 265 1,000 5. 0 1954
Walawa Kahoana KESC p 275 500 1. 9 1907
Hydro Kaumakani Makaweli OLSC p 211 500 3. 1 1920
Alexander Res Wahiawa MBSC p 700 1,000 2. 1 1928
Malumalu Walhohonu MBSC p 150 128* -----1919
Lower Ll hue North Wa I I ua &
II liliula Ditches LIPC p 206 800 5. 0 1941
Upper Ll hue North Wai I ua &
I
-sou-rce:------~··
1. 11 A I tern ate Energy Sources tor Hawa i 111 , Haw a 1 i Natura 1 Energy Institute, UnIversIty of Hawa i i , and Department of
Planning and Economic Development, State of Hawaii, February 1975.
2. Input from owners, 1979-1980.
3. Energy generation estimated by the Pacific Ocean Division, u.s. Army Corps of Engineers.
Abbrevl at ions:
HELCO-Hawaii Electric Light Co., Ltd
PASC -Paauhau Sugar Co.
HOSU -Honakaa Sugar Co.
KOSC -Kohala Sugar Co.
PIMC -Pioneer Mill Co., Ltd.
1-CPC -Hi lo Coast Process! ng Co.
HACS-Hawaiian Commercial & Sugar Co.
MBSC-McBryde Sugar Co., Ltd.
* Denotes inactive sites
KESC-Kekaha Sugar Co., Ltd.
OLSC-Olokele Sugar Co., Ltd.
GRFC -Grove Farm Co., Ltd.
LIPC -Lihue Plantation Co.
N.A. -Not Ava! I able
I -Investor-owned utility
P -Commercial or Industrial Firm
being fully used. Because of relatively small drainage basins having only
one principal stream with minor tributaries, streamflows are low, highly
variable, and largely unregulated. Hydropower plant capacities are small,
usually operated on run-of-river streamflows. Most hydropower plants were
installed by the plantations in their irrigation ditches. In addition, in
contrast to most mainland installations, practically all of the existing
projects are characterized as high head, low discharge facilities and uti-
lize impulse-type (Pelton) turbines.
During the past decade many hydropower plants were deactivated or aban-
doned. In certain instances, sugar plantations owning plants went out of
business; in other cases, turbine/generator equipment no longer performed
effectively. However, some plants could be reactivated and there is poten-
tial for increasing the capacity of currently active plants. The prospect
for reactivation is enchanced by certain recent developments:
a. Sharply rising petroleum prices make hydropower economically
attractive.
b. There is an increasing interest among the plantations to sell energy
as a prime source of revenue.
c. The implementation of the Public Utility Regulatory Policies Act
(PURPA) of 1978 mandating regulatory agencies to establish energy rates
based on avoided petroleum costs assures hydropower producers of receiving a
fair market price. This has spurred plantations to take a second look at
their existing and new alternative energy systems.
d. There is a growing recognition that the combination of wet-season
hydropower and dry-season bagasse could produce year round firm power for
possible sale to a utility.
3-7
References
1. Department of Planning and Economic Development, State of Hawaii, 1977,
Energy Use in Hawaii.
2. Department of Planning and Economic Development, State of Hawaii, 1980,
State Energy Plan.
3. Federal Power Commission, Bureau of Power, 1966, Planning Status Report;
Hawaii River Basins.
4. Hawaii Natural Energy Institute, University of Hawaii, and Department of
Planning and Economic Development, State of Hawaii, 1975, Alternate Energy
Sources for Hawaii.
5. Pacific Analysis Corporation, 1977, An Inventory and Analysis of the
Electrical Energy Industry in the State of Hawaii (prepared for the u.s.
Army Corps of Engineers).
3-8
Chapter 4
DEMAND SUMMARY
Forecasts of electricity demand have been made by the State of Hawaii
(Table 4-1) and Hawaiian Electric Company and Kauai Electric Division (Table
4-2). Another forecast was made in a study by Harza Engineering Company
for the Institute for Water Resources, u.s. Army Corps of Engineers (Table
4-3 [1, 2]. In that study, three projections of electricity demand were
developed for use in assessing the regional market for hydropower.
Projection I was derived from forecasts made by the utilities {5].
Projection II was derived from the forecast made by the Institute for Energy
Analysis (lEA) at the Oak Ridge National Laboratory in May 1977 {3].
Projection III was based on the "Consensus Forecast of u.s. Electricity
Demand" [4]. From these three projections, a "median" forecast was selected
and is considered to be representative of future power and energy demand of
the State. The OBERS population forecasts are adjusted to reflect the
latest census [4].
4.1 Capacity
The peak demand for all the utility companies in the State of Hawaii was
1,120 MW in 1978, up from 726.6 MW in 1969. The total utility-installed
capacity increased from 862 MW in 1968 to 1,470 MW in 1978 which was 88.9
percent of the total installed capacity in the State. Table 4-4 shows the
peak load and installed capacity from 1968 to 1978. The majority of the
peak load occurs on Oahu. However, Oahu's share of the total peak load in
the State decreased from 86.4 percent in 1969 to 81.9 percent in 1978. This
is attributable to the faster growth of the Neighbor Islands during the past
decade. Installed capacity on Oahu constituted 84.2 percent of the State's
total capacity in 1968. This percentage has reduced to 81.3 in 1978.
Hawaii's peak demand now occurs in winter and it is expected to continue
doing so in the future. According to Harza's projection, the peak demand
between 1978 and 1985 is likely to grow at an average annual rate of 4.5
percent from 1,100 MW to 1,500 MW. After 1985, annual growth in peak demand
is likely to be about 4.0 percent until 1990, then 3.6 percent through the
end of the century. The peak demand is expected to be 2,600 MW in 2000.
Utilities projected peak load is somewhat lower. As shown in Table 4-2,
it will only be 2,127 MW in 1998. This projection does not cover Molokai
Electric Company which constituted less than 0.5 percent of the total peak
load for the utility companies in 1978. Also shown in Table 4-2 are the
utilities projected generating capacities. The planned additions are pre-
sented in Table 4-5. The Neighbor Islands are expected to exceed Oahu's
rate of growth in the next two decades. Projected peak load and installed
capacity for Oahu in 1998 are 70.9 and 71.0 percent of the State's total,
respectively. These percentages are considerably lower than 1978. Maui is
projected to have the most significant gain in peak load; from 7.0 percent
in 1978, to 18.1 percent in 1998, and in generating capacity from 5.7 per-
cent in 1978 to 16.8 percent in 1998. Kauai, the island with the most
4-1
Table 4-1
STATE PROJECTED ELECTRICAL ENERGY DEMAND FORECAST, HAWAII, 1980-2005
Lana!,
Year Oahu Hawaii Maul Molokal Kaual State --
Energy Avg. Ann. Energy Avg. Ann. Energy Avg. Ann. Energy Avg. Ann. Energy Avg. Ann.
<GWh) Growth <GWh) Growth <GWh) Growth (GWh) Growth <GWh) Growth
Rate Rate Rate Rate Rate
<%> <%> <%> <%> <%>
1980 5, 057 -435 -509 -187 -6,187
1985 5,350 1.13 522 3. 71 799 9.45 230 4.26 6,900 2.21
1990 6,213 3.04 604 2.98 1,071 6.04 272 3.38 8,159 3.41 .p-
I
N 1995 6, 767 1.72 677 2.31 1,285 3. 72 297 1.81 9,027 2.04
2000 7,466 1.99 720 1 .23 1 '395 1 .65 306 0.58 9,887 1 .84
2005 8,345 2.25 771 1.39 1,497 1 .42 314 0.54 10,926 2.02
Source: "State Energy Plan," Department of Planning and Economic Development, State of Hawall, September 1980.
Table 4-2
PUBLIC UTILITIES PROJECTED PEAK LOAD AND GENERATING CAPACITIES, HAWAII 1979-98
YEAR HECO HELCO f'.ECO KED
Peak Capac tty Peak Capaclfy Peak Capac!ty· Peak Capac Tty
Load( l1rfl l ( I'IW) Load(llrfl) (mw) Load<m.tl Cm.tl load(mw) Cm.tl
1979 906 1209 87 124 87 99 36.5 62.1
1980 994 1350 90 124 95 112 38 62 .1
1981 1022 1350 93 124 103 112 39.6 74.1 *
1982 I 049 1350 97 124 112 125 41 .2 74.1
1983 1077 1350 100 124 121 138 42.8 74.1
1984 I 106 1350 103 127 I 31 151 44.4 74. I
1985 1136 1350 107 141 141 164 46.1 74.1
1986 1163 1420 110 141 152 164 47.7 74.1
1987 1191 1420 114 141 165 190 49.3 74.1
1988 1220 1420 118 141 178 203 50.9 74.1
1989 1249 1489 122 155 192 216 52.6 82.1
1990 1278 1489 127 155 207 229 54.2 82.1
1991 1307 1559 131 155 224 255 55.8 82.1
1992 1336 1559 136 168 242 268 57.4 82 .I
1993 1365 1729 140 168 261 294 59.1 92 .I
1994 1395 1729 145 168 282 307 60.7 92.1
1995 1426 1729 150 182 305 333 62.3 92.1
1996 1453 1729 156 182 329 359 63.9 114.3
1997 1481 1729 161 196 355 398 65.6 114.3
1998 1509 1799 167 196 384 424 67.2 114.3
* Kaual Electric Division wll I have contract purchase power from LThue
Plantation amounting to 12 MW In 1981; thus, planned additions by the
public utility Itself are not projected to occur until 1989.
SOURCE: Official HECO and KED projections, 1979.
AbbrevTatlons:
HECO-Hawaiian Electric Company MECO-Maul Electric Company
HELCO-Hawaii Electric Light Company KED-Kaual Electric D!vTsTon of
Citizens UtTIIty Company
4-3
Table 4-3
HARZA PROJECTED POWER DEMAND FORECAST, HAWAII 1978-2000
7-year 5-year 5-year 5-year 5-year
Growth Growth Growth Growth Growth
1978 Rate_!.! 1985 Rate_!.! 1990 Rate_!.! 1995 Rate 2000 Rate_!.!
% % % % %
Population (Thousands) 897. 1. 7 1007.0 1.4 1080.0 1. 0 1135.0 1. 0 1193.0 1. 3
Projection
Per Capita Consumption (MWh) 7.5 I. 8 8.6 1. 7 9.3 2. 1 10.3 2. 1 11. 5 1. 9
Total Demand (Thousand GWh) 6.8 3.5 8.6 3. 1 10.0 3.2 11. 7 3. 1 13.7 3.2
Peak Demand (GW) 1. 1 3.7 1.4 3.0 1. 7 3.2 1. 9 3. 1 2.3 3.3
Projection II
Per Capita Consumption <MWh) 7.5 2.6 9.0 2.6 10.3 2.6 11.7 2.6 13.3 2.6
Total Demand (Thousand GWh) 6.8 4.3 9. 1 4.0 I 1 • 1 3.6 13.2 3.6 15.8 3.9
Peak Demand (GW) 1. 1 4.5 1. 5 4.0 1.8 3.6 2.2 3. 6 2. 6 4.0
Project I on Ill
Per Capita Consumption (MWh) 7. 5 4.3 10.3 4.0 12.5 3.3 14.7 3.2 17.2 3.8
Total Demand {Thousand GWh) 6.8 6.2 10.3 5. 5 13.5 4.3 16.7 4.2 20.5 5.2
Peak Demand (GW) 1. 1 6.4 1. 7 5.4 2.2 4.3 2.8 4.2 3.4 5.2
Median Projection
Per Capita Consumption {MWh) 7.5 2.6 9.0 2.6 10.3 2.6 11. 7 2.6 13.3 2.6
Total Demand (Thousand GWhl 6.8 4.3 9. 1 4.0 11. 1 3.6 13.2 3.6 15.8 3. 9
Peak Demand (GW) 1. 1 4.5 1. 5 4.0 1. 8 3.6 2.2 3.6 2.6 4.0
Margin (Percent) 25.0 25.0 25.0 25.0
Resources To Serve Demand {GW) 1. 9 2.3 2.7 3.3
Load Factor (Percent) 69.5 68.7 69.0 69.0 69.0
The Growth Rates Are Average Annual Compounded Rates Over The Period.
-----~--
Source: "The Magnitude and Regional Distribution ot Needs for Hydropower, The National Hydropower Study: Phase I I -Future
Electric Power Demand and Supply," Harza Engineering Company, Report Prepared for the u.s. Army Corps of ineers,
980.
~
I
\.11
Table 4-4
HISTORICAL INSTALLED CAPACITY AND PEAK LOAD, HAWAII 1968-1978
-----------
Year HECO HELCO M::CO KED MOECO
~ak Capaclfy
load(MW) <MW>
T'e!ak Capacity
load(MW) (MW)
rea~<:----cap-aCTfY
load(MW) <MW>
Peak Capac l ty· T'e!a-k-capacTfY
loadCMWl. (MW) Load(MW) MWl
Total
~-CapacTty-
Load( MW) CMW)
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
567
628
680
726
780
815
838
854
896
911
725.9
725.9
873
873
963
1,068.4
1,209.4
1, 209.4
,209.4
1, 209.4
1978 --~---'··'·209.4
40
44.8
51
56.8
61 .8
66
69
71
78
80.5
83.3
57.2
57.2
60.8
60.8
71 .8
73.8
102.3
103.6
24.3
124.3
124.3
28
31
34
39
43
48
55
60
67.2
73.1
78.7
50
50
40
42.8
48.3
60.6
60.6
72.9
72.9
79.1
85.2
17.8
19.6
21 .9
24.3
27
29.4
29.4
31 .9
31.7
33.7
35.9
22.3
22.3
22.3
22.3
22.3
39.9
39.9
39.9
39.9
62.1
62.1
3.2
3.7
3.7
3.7
4.1
3.9
4.3
4.5
4.8
5.1
6.6
6.6
6.6
6.6
7.9
7.9
7.9
862
726.6 862
790.6 1 , 002.7
849.8 1,005.5
91 5 • 5 1 , 1 1 3 • 3
962.5 1,250.6
995.3 1,420.1
7.9 1,021.2 1,433.7
7.9 1,077.4 1,454.4
6.9 1,103,.1 1,481.8
6 • 5 _1 , I 20 1 , 48 7. 5
Sources: 1. "An Inventory and Analysis of the electric Energy Industry In the State of Hawa!l," Pacific Analysis
Corporation, Prepared for the u.s. Army Ccrps of Engineers, Paclflc Ocean Dlvlslon, 29 March 1977.
2. State of Hawall Data Book 1977-79.
3. State of Hawaii Publlc Utllltles Commlsslon's Record.
Abbreviations:
HECO-Hawaiian Electric Company
HELCO-Hawall Electric light Company
KED-Kaua! Electric Dlvlslon of
Cltlzens Utl!lty Company
MECO-Maul Electric Company
MOECO-Molokal Electrlc Company
Table 4-5
PLANNED ADDITIONS TO ELECTRIC GENERATING CAPACITY, PUBLIC UTILITIES, HAWAII 1979-98
(Megawatts)
Kahe Waimea
1980 141 13
1981
1982 13
1983 13
1984 3 13
1985 14 13
1986 70
1987 26 (2 units)
1988 l3
1989 69 14 13 8
1990 13
1991 70 26 (2 units)
1992 13 13
1993 170 26 (2 units) 10
1994 13
1995 14 26 (2 units)
1996 26 (2 units) 22.2
1997 14 39 (3 units)
26
Source: Official HECO and KED projections, 1979.
Note: Kauai Electric Division will have contract purchase power from Lihue
Plantation amounting to 12 MW in 1981. Thus, planned additions by the uti-
lity are not projected to occur until 1989.
4-6
hydropower potential, is expected to remain at 3.2 percent in peak load and
grow slightly from 4.2 percent in 1978 to 4.5 percent in 1998 in generating
capacity.
4.2 ENERGY
The electric energy sold by the utilities in the State of Hawaii for
1978 was 6,005 GWh, increased from 3,104 GWh in 1968. This corresponds to
an average annual growth rate of about 6.8 percent. Electricity data for
all utility companies from 1968 to 1978 are presented in Table 4-6.
The "median" electric energy demand in Hawaii as projected by Harza, is
expected to grow from a projected 6,800 GWh in 1978 to 9,100 GWh in 1985, an
average annual growth rate of 4.3 percent. The electric energy demand is
expected to grow to approximately 15,800 GWh by the year 2000, an average
annual growth rate of 3.9 percent between 1978 and 2000. The island of Oahu
currently consumes the largest portion of electrical energy generated. The
island of Maui is expected to have an accelerated growth in demand because
of its expanding tourist industry.
Projections by the State are based on the assumption that conservation
measures, such as improved efficiency in appliances, will be adopted. As a
result, an average annual growth rate of 2.3 percent from 1980 to 2005 is
shown. This projection also reflects the anticipated consumption levels for
electricity regardless of the primary energy source utilized for electric
generation.
In 1978, Hawaii's annual load factor was 69.5 percent. The annual load
factors for the Hawaiian Electric Company and its subsidiaries, Hawaii
Electric Light Company and Maui Electric Company, increased from 57.7 percent
in 1970 to 62.3 percent in 1977. From projected peak and energy demand fore-
casts by the utilities, future load factors are expected to average 69
percent.
4-7
Table 4-6
HISTORICAL ELECTRICITY DEMAND, HAWAII, 1968-78
(GWh)
Utility
Year HECO HELCO KED MECO MOE CO Total
1968 2,728 166 78 119 13 3,104
1969 3,004 186 90 126 14 3,420
1970 3,276 214 103 146 15 3,754
1971 3,601 247 112 186 16 4,162
1972 3,943 279 121 197 17 4,557
1973 4,189 302 132 221 17 4,861
1974 4,393 320 136 243 17 5,109
1975 4,555 333 149 275 18 5,330
1976 4,762 363 156 316 19 5,616
1977 4, 911 377 167 353 23 5,831
1978 5,025 394 179 382 25 6,005
Sources: 1. "An Inventory and Analysis of the Electric Energy Industry in
the State of Hawaii," Pacific Analysis Corporation, Prepared for the U.S.
Army Corps of Engineers, Pacific Ocean Division, 29 March 1977.
2. State of Hawaii Data Book 1977-79.
Abbreviations:
HECO -Hawaiian Electric Company
HELCO -Hawaii Electric Light Company
KED -Kauai Electric Division of
Citizens Utility Company
4-8
MECO -t1aui Electric Company
MOECO -Holokai Electric Company
References
1. Department of Planning and Economic Development, State of Hawaii, 1980,
State Energy Plan.
2. Harza Engineering Company, 1979, The Magnitude and Regional Distribution
of Needs for Hydropower, The National Hydropower Study, Phase 1 -1978
Electric Power Demand and Supply, Report prepared for the Institute for
Water Resources, U.S. Army Corps of Engineers.
3. Harza Engineering Company, 1980, The Magnitude and Regional Distribution
of Needs for Hydropower, The National Hydropower Study, Phase II -Future
Electric Power Demand and Study, prepared for the Institute for Water
Resources, u.s. Army Corps of Engineers.
4. Institute for Energy Analysis, 1977, u.s. Electricity Supply and Demand to
the Year 2000, Oak Ridge National Laboratory.
S. Lane, J, A., 1977, Consensus Forecast of u.s. Electricity Supply and
Demand to the Year 2000, Oak Ridge National Laboratory.
6. Pacific Analysis Corporation, 1977, An Inventory and Analysis of the
Electric Energy Industry in the State of Hawaii, prepared for the u.s.
Army Corps of Engineers, Pacific Ocean Division.
7. Regional Electric Reliability Council, 1979, Reply to Appendix A-2 of
Order No. 383-5, Docket R-362.
8. State of Hawaii, Data Book 1977-1979.
4-9
Chapter 5
METHODOLOGY
5.1 REGIONAL PROCEDURES AND CRITERIA
Regional Screening Criteria
Potential hydropower projects in the region were screened according to
physical, economic, and environmental considerations. Screening was per-
formed in four progressive stages. Only projects that demonstrate an
appropriate level of physical potential, marketability, and environmental or
social acceptability were considered for future development.
Stage 1
An inventory of the existing dams, existing hydropower facilities, and
undeveloped sites having the physical potential to generate hydropower was
made to provide the data base for the screening process. Only sites in one
of the following categories were retained for evaluation in Stage 2:
1. Existing dams exceeding 40 feet of head and 800 acre-feet of storage.
2. Existing hydropower facilities with any potential incremental capa-
city.
3. New undeveloped sites with developable capacity exceeding 100 kW.
Stage 2
A second screening of the sites in the inventory identified those sites
which show some possibility of being marketable. Site-specific data were
coded and analyzed by computer programs which evaluated site hydrology,
project costs and benefits, and identified the scope of project by maxi-
mizing net benefits. Sites which did not show promising marketability were
deleted from further consideration.
Stage 3
In the third stage, sites were screened on the basis of environmental,
social and institutional considerations. Sites with overriding adverse
environmental, social, or institutional impacts were removed from considera-
tion.
Stage 4
For all sites passing the first three stages, economic evaluations were
performed manually using cost curves published in references 7 and 9. Costs
obtained from these curves may not entirely agree with manufacturer and
contractor bid prices. However, since the intent of this study is to make a
comparative analysis of potential projects, absolute accuracy of cost estima-
5-1
tes is not critical. The unit energy cost for each project was estimated by
comparing the project cost with the amount of energy generated. Projects
costs were adjusted to the June 1980 price level based on a construction
cost index. Annual costs include interest and amortization of total
construction costs, based on a project economic life of 50 years and an
interest rate of 7-1/8 percent, and annual maintenance and operation costs.
Data Collection Procedures
All existing dams, existing hydropower facilities, and undeveloped sites
with reasonable hydropower development potential were considered to be
possible sites for new or incremental hydropower development. Data on the
location, ownership, available power head, and potential flow were collected
for each site.
Stage 1
The data base for potential hydropower sites was established principally
from two sources; the National Program of Inspection of Dams [10] and
hydroelectric power resources data published by Federal Power Commission [5].
Other references [1, 2, 3, 4, 6, 8, 11, 12] were also utilized and pertinent
data were adopted to complement the inventory.
Stage 2
Additional site specific data from published and unpublished reports and
topographical maps as required for computer analysis, were collected during
this stage. However, no site visits or field surveys were made. These data
include location and identification, physical and hydrologic characteristics,
and power features that were not in the Stage 1 data base.
Stage 3
Estimates of the capacity and energy generation of potential projects were
determined by computer. Copies of these estimates were distributed to the
concerned public for their information and comments. As a result of this
public-involvement process, more data and information were obtained to
modify the data base.
Stage 4
There were no data collection activities during Stage 4.
Screening Procedures and Evaluation
Stage 1
Data collected from various sources were evaluated and compared with the
Stage 1 criteria. Data for sites exceeding minimum head/storage or minimum
capacity were included in the preliminary inventory data base.
5-2
References
1. Bureau of Power, Federal Power Commission, 1968, Planning Status Report,
Water Resource Appraisals for Hydroelectric Licensing.
2. Department of Land and Natural Resources, State of Hawaii, 1964, Kokee
Water Project, Island of Kauai, Hawaii.
3. Department of Land and Natural Resources, State of Hawaii, 1980, Molokai
Irrigation System Hydroelectric Feasibility Study.
4. Department of Land and Natural Resources, State of Hawaii, 1978, Waialeale
Hydropower Study.
5. Federal Power Commission, 1976, Hydroelectric Power Resources of the
United States -Developed and Undeveloped.
6. Hawaii Natural Energy Institute, University of Hawaii, and Department of
Planning and Economic Development, State of Hawaii, 1975, Alternate Energy
Sources for Hawaii.
7. Hydrologic Engineering Center, and Institute for Water Resources, u.s.
Army Corps of Engineers, 1979, Feasibility Studies for Small Scale
Hydropower Additions.
8. Johnston, W.D., 1974, Report to Hydroelectric Subcommittee of Governor's
Committee on Alaternate Energy Sources for Hawaii.
9. North Pacific Division -Portland District, u.s. Army Corps of Engineers,
1979, Hydropower Cost Estimating Manual.
10. Office of the Chief of Engineers, u.s. Army Corps of Engineers, 1975,
National Program of Inspection of Dams, Vol. II.
11. u.s. Army Engineer District-Honolulu, 1977, Hydrolectric Power, Plan of
Study, Harbors and Rivers in Hawaii.
12. u.s. Army Engineer District -Honolulu, 1978, Hydrolectric Power, Summary
Report, Harbors and Rivers in Hawaii.
5-4
Data for sites identified during Stage 1 were added to the computerized
data base for site specific evaluation. The computer performed (1) analysis
of streamflow data using flow-duration techniques to develop a range of cap-
city and energy potentials, (2) computation of project benefits using FERC
power values; (3) computation of powerhouse and switchyard costs from
generalized cost curves; and (4) identification of the scope of project
which would maximize net benefits. Results of the computer analysis indi
cated that all potential projects had a reasonable likelihood of marketabi-
lity and, therefore, no sites were dropped during this stage.
s 3
A few sites were screened out because of environmental, social or
institutional problems because (1) sites were in significant environmental
pristine areas (2) sites were of questionable safety; (3) sites had incre-
mental capacity potential of 100 kl-l or less; or (4) for existing hydropower
plants there was no expansion potential.
s 4
Marketability of power that would be generated at each site was eva-
luated manually (the results of the computer analysis were not used), and a
ranking of the projects was made according to unit energy costs. Potential
energy generation from these sites falls short of meeting the projected
future demand for the State and for each of the islands. To meet the
regional objective of increasing Hawaii's energy self-sufficiency, all
potentially feasible sites were identified as suitable for further study and
no further screening was performed at this stage.
5-3
Chapter 6
PUBLIC INVOLVEMENT
6.1 ROLE OF PUBLIC INVOLVEMENT
In this study, the purposes of public involvement were to keep the
public informed about the status and findings of the National Hydroelectric
Power Study (NHS); to obtain needed information on existing and potential
hydropower facilities; and, to obtain public comment on potential problems.
6.2 PUBLIC CONTACTS
As mentioned in Chapter 5, information and data collected in the 1977-78
hydropower study conducted by the Corps of Engineers were used as part of
the data base for this report. In that study, workshops were held at each
of the four major islands in the State, namely, Oahu, Hawaii, Maui and
Kauai. A public meeting was also held at Kauai. Major input and basic con-
cerns resulting from these public contacts were:
a. Location of hydropower facilities.
b. Effect on water rights.
c. Effect on local electrical rates.
d. Environmental changes.
e. Alternative energy sources.
f. Past and current State studies.
Public information fact sheets on the National Hydroelectric Power Study
were distributed to selected government agencies, industries and citizens
who have an interest in hydropower development. Attached to the fact sheet
were the National Hydroelectric Power Study brochure published by the
Institute for Water Resources and data sheets on the preliminary inventory
of existing and potential hydropower facilities in Hawaii. Many valuable
comments and information were received from the public regarding additional
potential sites not included in the inventory and the accuracy of some data
in the inventory. The public input was incorporated in the final inventory.
U.s •. Army Corps of Engineers s::aff members also are active participants
of the Committee on Small Hydroelectric Power Systems, sponsored by the
State of Hawaii, Department of Planning and Economic Development.
Representatives from Waialua Sugar Company, Department of Land and Natural
Resources of the State of Hawaii, Kauai Electric Division of the Citizens
Utilities Company, C. Brewer & Company, AmFac Corp., U.S. Army Corps of
Engineers, U.S. Department of Energy, Water Resources Research Center of the
University of Hawaii, Alexander & Baldwin, Theo H. Davies & Company,
Hawaiian Electric Company & Molokai Electric Company serve on the committee.
The several committee meetings held during March to August 1980 served as
forums for discussing the current and future impact of hydropower in the
State. A copy of the draft of this report was distributed to each of the
committee members for review and comment. The draft report was discussed
during the August 1980 committee meeting and additional information and
input were obtained and used to revise the report.
6-1
Chapter 7
INVENTORY
7.1 STAGE 1, 2 AND 3 RESULTS
Size of Inventory
A total of 14 undeveloped sites and existing projects passed the three-
stage screening process. Among these projects, seven are new sites, four
are on existing reservoirs, two are active hydropower plants for which addi-
tional capacity is possible, and one is a deactivated plant which could be
rehabilitated. Collection and analysis of site data were based on available
and readily developed information. Detailed engineering and other technical
studies were not performed specifically for this study. The results of the
study, therefore, are preliminary estimates of developable hydropower within
the foreseeable future.
Capacity and Energy
These 14 identified projects have a total capacity potential of 39.39 MW
and could generate 119.9 GWh of energy. These estimates include the capa-
city of 1.5 MW and energy of 8.1 GWh for two currently active hydropower
plants. The incremental capacity potential for the State is 37.89 MW and
the incrmental energy generation is 111.8 GWh (excluding what is currently
available at the two active hydropower plants).
Plant Factors
Plant factors for the identified projects in the inventory vary from
0.17 to 0.94. However, majority of the sites have plant factors between 0.2
and 0.3. This is attributable to the highly variable runoff in most
Hawaiian streams in relation to the installed capacity.
Primary Locations
Among the 14 projects in the inventory, more than half are located on
Kauai, mainly on the eastern and southwestern parts of the island the
remaining projects are located on the islands of Hawaii (2), Maul (3), Oahu
(1) and Molokai (1).
Potential Development
All potential projects identified in this study are small-scale in capa-
city (less than 25 MW). Only one project has a potential capacity of 10 MW,
and capacity of all others is less than 5 MW.
7-1
Ex is
Development of the seven existing projects would be through expansion of
existing hydropower plants, rehabilitation of abandoned hydropower sites, or
construction of hydropower facilities on existing reservoirs. Total poten-
tial capacity created by this type of development is estimated to be 8.86
MW. The amount of energy which could be generated is estimated to be 27.6
GWh.
New ts
There are seven undeveloped projects in the inventory. These sites have
a total capacity of 29.03 MW and energy potential of 84.2 GWh.
7.2 STAGE 4 INVENTORY
Projects Retained During Stage 4
All 14 projects rema1n1ng in the inventory after the Stage 3 screening
were retained in Stage 4 as suitable for further study. Table 7-l tabulates
some general information and estimated capacity and energy for these pro-
jects. Their locations are shown on Figure 7-1.
Physical Characteristics
Selected projects are classified into five groups:
a. Expansion of active hydropower plants.
b. Rehabilitation of abandoned hydropower sites.
c. Construction of hydropower facilities on existing reservoirs.
d. Construction of new run-of-river hydropower facilities.
e. Construction of new storage reservoir hydropower facilities.
Projects in the first two groups are privately owned existing or aban-
doned hydropower plants. The capacities are small, 1 MW or less. Major
work for these projects would be limited to the installation or rehabilita-
tion of turbines and generators.
Civil engineering features, in addition to electromechanical components,
will be needed for the group "c" projects. The basic features include site
preparation, intake, penstock, powerhouse and switchyard. Existing reser-
voirs included in this group are relatively small, with the largest having
only a maximum storage of 9,000 acre feet. The highest dam is 105 feet high.
Construction works required for group ''d" projects are essentially the
same as those required for group "c" projects with the exception that diver-
sion systems with limited pondage are included in the plans. Although built
on undeveloped sites, carefully designed and constructed run-of-river pro-
jects included in group "d" may result in relatively minor changes to the
natural environment.
7-2
--.1
I w
Table 7-1
PRELIMINARY ESTIMATES OF POTENTIAL HYDROPOWER PROJECTS, HAWAII
------·-----'----------------
I.D. No~ Name of Project
6
9
11
12
14
15
16
22
23
31
25
30
32
26
Notes:
Wai loa
Union Mi II
Wahiawa Res
Hanalei
Kokee
Wa l a I ea I e J!
Puu Lua Res.
Kapa i a Res.
Hydro Kaumakani
Waimea
Wai lua Jl
Waihee
Hamakua Dl tch
1-bopol Chute
Kualapuu Res.
Total
Island
Hawaii
Hawaii
Oahu
Kaual
Kaual
Kaual
Kaua I
Kaua I
Kauai
Kaual
Kauai
Maul
Maul
r4au i
Mo loka i
Owner
Koha Ia Corp
Waialua Sugar Co.
Kekaha Sugar Co., Ltd.
Lihue Plantation Co., Ltd.
Olokele Sugar Co.
Kekaha Sugar Co.
Hawaiian Commercial & Sugar Co.
Hawaiian Commercial & Sugar Co.
State of Haw a i I
Incrementa I
Capacity
MW
2. 9
0.5
2.8
4.5
10.0
7. 8
1. 7
o. 12
o. 75 N
2. 9
8.4
0.73
o. 5
2.0
o.o9ll
37.89
!( Identification numbers are referenced to locations shown on Figure 7-1.
l ncrementa I
~.9.1_
GWh
12.3
4.1
7. 5
16.5
29.2
42.7
3.0
0.2
8.3
3.9
18.7
2.0
2. 5
3.0
0.55
---
111.80
Type of Project
New site (run-of-river)
Rehab! I itation
Existing reservoir
New site (run-of-rl ver)
New site (storage)
t~w site (storage)
Existing reservoir
Existing reservoir
Existing plant
Existing plant
New site (run-of-river)
New site (run-of-river)
New site (run-of-river)
New site (run-of-river)
Existing reservoir
l( Waialeale and Wai lua are alternative development schemes for the same site. Wailua is the preferred development
and is the one included in summaries of potential.
}j This site did not meet the minimum capacity criteria. It was included in the potential project list based on
publ !cation of a favorable feasibl I ity study, Feb 1980, State of Hawaii.
~ New 1.25 MW power plant to be installed. Existing 0.5 ~~~~unit wit I be used as stand-by.
KAUAI
15
• .12
23.
NIIHAU
LANAI
14 31 .. OAHU
.16
MAUl
Figure 7·1
LOCATIONS OF POTENTIAL HYDROELECTRIC PROJECTS, HAWAII
7-4
Projects in group "e" include Kokee Dam, 234 feet high with maximum
storage of 41,000 acre feet, and Waialeale Dam, 185 feet high with maximum
storage of 47,000 acre feet. These two projects require significantly more
extensive civil-works construction than other projects. Items of work are
basically similar to those for group "c" projects, with the addition of
reservoir construction. Construction of reservoirs would drastically alter
the physical appearance and topography of the site. Regulated reservoir
outflows would modify the flow regime of the existing stream.
Economic and Financial Characteristics
Estimated unit energy costs, which are the quotients of total annual
project costs over the annual energy, vary from 10 to 255 mills/kWh. Total
annual project costs were estimated by summing up the annual maintenance
costs and the amortized first costs based on a 50-year project life and the
fiscal year 1980 Federal discount rate of 7-1/8 percent. Projects of high
unit energy costs include those requiring extensive construction such as
large dams or long penstocks, and those with economically unfavorable energy
output. However, more than 50 percent of the potential projects have a unit
energy cost of 40 mills/kWh or less. This is about the price of surplus
energy on the current market.
General Environmental and Social Conditions
All sites with existing hydropower facilities or civil features have no
significant environmental concerns. Some of these facilities may no longer
be in operation. However, all of the affected waterbodies have had a
history of substantial modification to their watersheds. These modifica-
tions include clearing of natural riparian vegetation, monoculture commer-
cial crops (and subsequent exposure to biocides), fords and road crossings,
total or partial channelization, and urbanization. These waterbodies no
longer harbor sustaining populations of endemic or native diadromous fishes,
crustaceans or molluscs. There are no significant recreational areas, or
sites of local or national historic significance located within or imme-
diately adjacent to any of these waterbodies. Although one or more of these
reservoirs and flumes may have been used for potable water supplies in the
past, none are apparently being used for that purpose at present.
The Wailua and Waialeale project site on Kauai possesses one of the most
disturbed aquatic fauna within the State. Continuous introductions of exo-
tic species and modification of watershed vegetation and the streambed have
resulted in the extirpation of virtually all native fauna from this exten-
sive stream system. The lower reaches of the river along the south fork,
however, drain the Wailua River State Park. Wailua Falls, the Fern Grotto,
and the Wailua River boat ride are favorite tourist destination points which
attracted over 4.5 million visitors to the park in 1979. The heavily vege-
tated banks of the estuarine reaches of the river provide habitat for three
endangered Hawaiian waterbirds (Hawaiian coot, Hawaiian gallinule, and
Hawaiian duck).
The Waimea river on Kauai, and its major tributary Makaweli Stream, drain
the impressive Waimea Canyon. The stream itself has a high complement of
indigenous aquatic fauna and is still utilized as a sport fishery. The
7-5
\.Jaihee Stream on Haui has been dewatered by past diversions for water
supply. However, subsurface discharge and spring flow create marginal habi-
tat for a rare native fish (Lentipes concolor). Further consideration of
these streams for hydropower development would require an evaluation of the
potential environmental effects of development on these resources.
The Wailoa River is the principal tributary which drains historic Waipio
Valley in Hamakua, Hawaii. Waipio was once the site of a large Hawaiian
agricultural village; therefore, a substantial number of historic sites and
archaeological resources probably exist along the stream. Wailoa/Waipio is
the source of numerous ancient legends and has tremendous cultural and
spiritual value to Hawaiian people today. The stream itself harbors large
populations of migratory and diadromous native fauna. Lower Waipio Valley
today harbors one of the State's principal centers of commercial taro agri-
culture. This wetland crop depends entirely upon maintenance of adequate
streamflow for irrigation year-round.
Of the 14 potential projects, Hanalei and Kokee possess the most
valuable and significant resources. The lower reaches of the Hanalei River
flow through the Hanalei National Wildlife Refuge, which serves as prime
habitat for four endangered Hawaiian waterbirds and for migratory waterfowl.
Flow from the Hanalei River is needed to irrigate the island's largest com-
mercial taro fields as well as to maintain artificial waterbird ponds. The
river itself serves as the center of the seasonal fishery for native goby
fishes. The estuary provides a resource for recreational boating, and is a
nursery and spawning area for several marine fishes and crustaceans of com-
mercial value. Because the watershed is almost entirely State-owned,
excellent hiking trails extend toward the headwaters of the stream and are
frequented by hunters, hikers and people collecting fishes and shrimp from
the river. The Kokee project occurs within pristine forest reserves and
also within portions of the Kokee State Park. This elevated forest is com-
posed predominantly of native vegetation and native, endangered forest
birds. Several streams within the area are annually stocked by the Hawaii
Division of Fish and Game with rainbow trout to support a very small sport
fishery. Much of the watershed area which may be inundated by an impound-
ment provides habitat for endangered species and is crisscrossed by a net-
work of extremely popular hiking trails.
Sites Deleted Due to Noneconomic Constraints
Seven projects were deleted during Stage 3 because of enviromental,
social and institutional constraints. Three of them are on Oahu, and the
other four are on Kauai. The following table lists these sites and includes
reasons for deletion from further consideration.
7-6
Name of Project
Kaneohe-Kailua
Nuuanu
Ku-Tree
Lumahai
Koloko
Wainiha
Alexander
Waialeale
Table 7-2
SITES DELETED DURING STAGE THREE
Type of Project Location
Existing Reservoir Oahu
Existing Reservoir Oahu
Existing Reservoir Oahu
New Run of River Kauai
Existing Reservoir Kauai
Existing Plant Kauai
Existing Plant Kauai
New Reservoir Kauai
7-7
Reason(s) for Being Deleted
Incremental capacity is only
0.1 MW. Project purposes
(flood control and
recreation) not compatible
with hydropower development.
Incremental capacity is only
0.06 MW. Dam safety is
questionable. Currently
under investigation.
Incremental capacity is only
0.07 MW. Dam has been
declared hazardous.
Reservoir has been drained.
Project site is in signifi-
cant environmentally
pristine area.
Incremental capacity is only
0.07 MW.
There are no plans to expand
the existing capacity of the
plant.
There are no plans to expand
the existing capactiy of the
plant.
Alternative to Wailua which
would be more economically
feasible to develop.
Chapter 8
EVALUATION
8.1 REGIONAL DEVELOPHENT PLAN
A total of 14 projects emerged from the three-stage screening process for
possible inclusion in the regional plan. The total incremental capacity of
these 14 sites is 37.89 MW, much less than the utility projected additional
capacity requirement of 492 MW by 1990. From the preliminary analysis, it
appears that some of these projects may not be feasible at the prevailing
energy price level. However, the feasibility of these projects may be
improved in the future as a result of oil price escalation. To meet the
regional objectives of increasing Hawaii's energy self-sufficiency, all
these projects were included in the regional plan for potential development.
Economically Optimum System Ranking
Unit energy cost for each selected project was determined manually using
published cost curves. These projects were then ranked according to unit
energy costs. This ranking is displayed following.
Project ID No. Project Name
22 Hydro Kaumakani
6 Union Mill
9 Wahiawa Res.
11 Hanalei
1 Wailoa
23 Waimea
30 Hamakua Ditch
31 Wailua
15 Puu Lua Res.
32 Hoopoi Chute
26 Kualapuu Res.
25 Waihee
12 Kokee
16 Kapaia Res.
* June 1980 price level.
Estimated
Energy Cost*
mills/kWh
8-1
10
24
29
29
33
39
40
46
63
64
72
87
119
255
Energy Incremental
Potential
GWh
8.3
4.1
7.5
16.5
12.3
3.9
2.5
18.7
3.0
3.0
0.6
2.0
29.2
0.2
Environmentally Oriented System Ranking
Two of the 14 selected projects have unique ecological values which may
be jeopardized by development of hydropower facilities. An additional four
projects possess significant environmental resources within a portion of
their watersheds. Future detailed studies on the feasibility of these pro-
jects should consider the preservation of certain ecological, recreational,
and historical resources. The remainder of the project sites are in
disturbed areas, or have little or no significant environmental concerns.
The following listing of the 14 projects is in accordance with potential
environmental impacts.
No Significant
Concerns
Union Mill -Hawaii
Wahiawa Res -Oahu
Puu Lua Res -Kauai
Kapaia Res -Kauai
Hydro Kaumakani -Kauai
Kualapuu Res -Haui
Hamakua Ditch -}1aui
Hoopai Chute -Haui
Possess Important
Wailoa -Hawaii
Wailua -Kauai
Waimea -Kauai
Waihee -Haul
Developable System Ranking
Potentially Severe
Hanalei -Kauai
Kokee -Kauai
Projects recommended for further study are listed below on the basis of
combined economic and environmental considerations. Projects with high
marketability (unit energy cost of up to 40 mills/kWh) and no significant
environmental concerns were classified in the high-potential group.
Projects with low marketability (unit energy cost in excess of 100
mills/kWh) and/or potentially severe environmental impacts were classified
in the low potential groups. The remaining projects were included in the
medium potential group.
High Potential
Hydro Kaumakani
Union Mill
Wahiawa Res
Hamakua Ditch
Medium Potential
Puu Lua Res
Hoopoi Chute
Kualapuu Res
Wailoa
Waimea
Wailua
Waihee
8-2
Low Potential
Kapaia Res
Hanalei
Kokee
8.2 SCHEDULE FOR DEVELOPMENT
Short-Term
Short-term projects include Hydro Kaumakani, Union Mill, Wailua, Hamakua
Ditch, Hoopoi Chute and Kualapuu Reservoir. They are considered to have a
reasonable chance of being developed by 1990 or earlier. Among them, Hydro
Kaumakani (Olokele Sugar Company) and Hamakua Ditch and Hoopoi Chute (both
owned by Hawaiian Commercial and Sugar Company) are being planned for
construction. A reconnaissance study of the feasibility of reactivating the
Union Mill hydropower plant was completed by the u.s. Army Corps of
Engineers (COE) in October 1979, under the Rural Energy Initiative Program
managed by the u.s. Department of Energy. The Hawaii Electric Light Company
has subsequently performed further investigations on the site.
Implementation has been deferred pending resolution of water and lease
agreements with the owner. A hydropower feasibility study of Kualapuu
Reservoir was prepared for the State of Hawaii by w. A. Hirai and
Associates, Inc. in February 1980. The design and construction of a 90-kW
hydroelectric plant was recommended and is being considered by the State.
COE is currently undertaking a survey study to determine the feasibility of
constructing run-of-river hydropower facilities in the Wailua River Basin.
The study is scheduled for completion in fiscal year 1982.
Long-Range
Long-range projects include Wahiawa Reservoir, Hanalei, Wailoa, Waimea,
Puu Lua Reservoir, Waihee, Kokee, and Kapaia Reservoir. Although the Kokee
project is currently under study, it is unlikely that any of these projects will
be developed by 1990.
8.3 FEASIBILITY OF DEVELOPMENT PLAN
The development plan is strictly a preliminary conceptual plan for the
Hawaii Region. Detailed site-specific feasibility investigations of these
projects have not been performed. However, some indications of the marketa-
bility and potential environmental impacts of these projects have been
generated from this study and are briefly discussed following.
Short-Term
From the results of preliminary estimates, it appears that the unit
energy costs for most of the short-term projects are either below or com-
parable to the current market value of non-firm surplus energy. The unit
energy costs of two projects exceed 40 mills/kWh: Hoopoi Chute (64
mills/kWh) and Kualapuu (72 mills/kWh). Their cost is considerably higher
than the current market value but they could be marketable in the very near
future. The economic, environmental and composite rankings of these short-
term projects are as follows:
8-3
Ranking Environmental Ranking Composite Ranking
Rank Rank Pro ct Rank t -----
1 Hydro Kaumakani 1 Union Mill 1 Hydro Kaumakani
2 Union Mill 1 Hydro Kaumakani 2 Union Mill
3 Hamakua Ditch 1 Kualapuu Reservoir 3 Hamakua Ditch
4 Wailua 1 Hamakua Ditch 4 Hoopoi Chute
5 Hoopoi Chute 1 Hoopoi Chute 5 Kualapuu Reservoir
6 Kualapuu Reservoir 2 \~ailua 6 Hailua
Long-R~nge
Among the long-range sites, only four of the eight appear to yield a unit
energy cost compatible with current market energy values. All the long-term
projects are considered for development after 1990. It is possible that
energy values will be substantially higher at that time. The marketability of
the majority of the long-term projects does not seem to be encouraging at this
time but may improve wi.thin the decade. The economic, environmental and com-
posi.te rankings of these long-term projects are as follows:
Economic Ranking Ranking Composite Ranking
Rank Rank Rank _____ _!'_!'o jec t ___ _
1 Wahiawa Reservoir 1 Hahiawa Reservoir 1 Wahiawa Reservoir
2 Hanalei 1 Puu Lua Reservoir 2 Puu Lua Reservoir
3 Wailoa 1 Kapaia Reservoir 3 Wailoa
4 Haimea 2 Wailoa 4 Haimea
5 Puu Lua Reservoir 2 Waimea 5 Waihee
6 Waihee 2 Haihee 6 Kapaia Reservoir
7 Kokee 3 Hanalei 7 Hanalei
8 Kapaia Reservoir 3 Kokee 8 Kokee
on of Hydropower 1 with Demand
As discussed i.n Chapters 3 and 4, the total capacity of the State's
electric system installed by utilities was 1,463 MW in 1978 (excluding
MOECO), and the utility projected generating capacity is 1,955 MW in 19~0
and 2,533 HW in 1998. Thus, the State needs 492 MW additional capacity by
1990 and 1070 MW by 2000 to meet the capacity requirements for the utilities
alone. The additional capacity requirements by 1990 are 278 HW for HECO, 49 NW
for HELCO, 145 MW for MECO and 20 HW for KED. By 1998, additional r.apacity of
588 MW, 90 MW, 340 MW and 52 MW will be needed for HECO, HELCO, MECO and KED,
respectively. The total identified hydropower sites without overriding environ-
mental and/or institutional problems, however, only have a total incremental
capacity of 37.87 MW. Since potential power generation from all of these sites
is needed, they were all included in the development plan.
8-4
8. 4 SUMHARY
From the standpoint of marketability, most of the projects included in the
regional plan have a unit energy cost less than or equal to the current market
value of surplus energy. Energy from other projects could be marketable in
the near future. From the standpoint of environmental impact, eight projects
with existing hydropower facilities or civil features have no significant
environmental concerns. Construction of Wailoa, Wailua, Waimea, and Waihee
projects may disturb important natural resources. Hanalei and Kokee sites
possess very valuable and significant resources and construction activities
could cause severe environmental impacts. Key characteristics of the develop-
ment plan for Hawaii are summarized in Table 8-1. The development of the
hydropower sites will not satisfy the additional capacity or energy require-
ments of the State. The contribution of new and incremental hydropower deve-
lopment is expected to satisfy about 4 percent of the additional capacity
demand by 1998. However, the important consideration is that development of
any additional hydropower will relieve the State of the equivalent amount of
petroleum. Based upon an assumed development of new hydropower plants pro-
ducing 111.8 GWh of additional energy by the year 2000, the annual savings in
oil used to generate electricity would total 186,000 barrels.
8-5
Table 8-1
HYDROPOWER DEVELOPMENT PLAN FOR HAWAII
Name of Project Island Owner Rank Incremental Incrementa I
Composite Economic En vi ron menta I Capacity Energy Type of Project
(MW) CGWh l
Short-Term
Hydro Kaumakani Kaual Olokele Sugar Co. 1 I I 0.75 8.3 Expansion of Existing
pI ant by owner.
Union Hawaii Kohala Corp. 2 2 1 0.5 4. I Rehab! litation of
existing plant by
owner and Hawaii
Hamakua Ditch Maul Hawaiian Commercial Electric Light Co.
and Sugar Co. 3 4 1 o. 5 2. 5 Construction of new
run-of-river plant
Hoopoi Chute Maul Hawaiian Commercial by owner
and Sugar Co. 4 5 1 2.0 3.0 Construction of new
run-of-river plant
by owner
Kualapuu Reservoir Molokai State of Haw a i I 5 6 1 0.09 0.6 Construction of new
plant on existing
Q;) reservoir by the State
I Wailua* Kauai -----6 3 2 8.4 18.7 Feas i bl I i ty study of a (J'I new run-of-river plant
by Corps of Engineers
Long-Range
Wahiawa Reservoir Oahu Waialua Sugar Co. I 1 I 2.8 7.5 Existing reservoir
Puulua Reservoir Kauai Kekaha Sugar Co. 2 5 I I. 7 3.0 Existing reservoir
Waf loa Hawaii -----3 3 2 2. 9 12.3 New site (run-of-
river)
Waimea Kaual Kekaha Sugar Co. 4 4 2 2. 9 3. 9 Existing plant
Waihee Maul -----5 6 2 o. 73 2.0 New site (run-of-
river)
Kapaia Reservoir Kauai Lihue Plantation
Co. Ltd. 6 8 1 o. 12 0.2 Existing reservoir
Hanalei Kauai -----7 2 3 4.5 16.5 New site (run-of-
river)
Kokee Kauai -----8 7 3 10.0 29.2 New site (storage)
New feasibi I ity study
pend~.
*The selected development in drainage area between Walaleale and Wai lua projects.
APPENDIX
SUMMARY LISTING OF POTENTIAL HYDROPOWER PROJECTS
A-1
Introduction
A primary objective of the NHS was to inventory and evaluate potential
hydropower projects. Projects inventoried included existing dams and other
water projects and previously studied undeveloped sites. Project data were com-
piled from existing information sources supplemented by data from USGS
topographic maps, where necessary. No site visits or other field investigations
were made. Although to the extent possible, all existing and undeveloped pro-
jects were inventoried, only those projects with existing power generating faci-
lities or projects with a reasonable potential for development for hydropower
were retained in the NHS inventory. This inventory is permanently maintained in
a computer data base which includes descriptive information and the results of a
computer analysis of power potential and development costs for each project. In
all, the inventory for Hawaii includes 28 projects.
Tabulated Data
The purpose of this appendix is to provide a summary listing of selected
data on the 28 existing and potential hydropower projects which were included in
the NHS inventory (computer data base) for Hawaii. In the following table, pro-
jects are listed in alphabetical order by county. A description of the data
included in the table precedes the tabulated information. However, a few items
warrant clarification:
(1) Up to four lines of information are presented for each project.
(2) Projects are separated by a space.
(3) As noted in the description of tabulated data. The third character of
the project indentification number describes the type and status of the project.
A description of each of the possible project status/types is shown in the
following matrix:
* STATUS * TYPE OF OPERATION *
* OF ******************************************************************
* WATERWAY *RUN OF* * * RES. WITH * IRRIGATION * *
* STRUCTURE *RIVER * DIVERSION * RESERVOIR * DIVERSION * CANAL * STORAGE*
********************************************************************************
* * * * * * * *
* EXISTING * A * B * c * D * E * F *
* * * * * * * * * EXISTING * * * * * * * * WITH POWER * G * H * I * J * K * L * * * * * * * * *
* EXISTING * * * * * * *
* WITH RETIRED* M * N * 0 * p * Q * R * * POWER PLANT * * * * * * * * * * * * * * * * BREACHED * s * T * u * v * w * X * * * * * * * * * * BREACHED * * * * * * * * WITH RETIRED* y * z * 0 * 1 * 2 * 3 * * POWER PLANT * * * * * * * * * * * * * * * * UNDEVELOPED * 4 * 5 * 6 * 7 * 8 * 9 *
* * * * * * * *
********************************************************************************
A-2
(4) Project costs shown were derived from computer application of genera-
lized cost estimating procedures and should not be construed to be represen-
tative of actual costs. Further, it should be noted that as stated in Chapter 5
of this reportt final economic screening of potential projects was based on
manually computed cost estimates; not on the computer estimates shown in the
summary table. The estimated energy costs used in the economic screening and
ranking of projects recommended for further study are shown in Chapter 8 of this
report (page 8-1).
(5) With a few exceptions, environmental and social impact assessments and
codes were completed only for those projects which are recommended for further
study (ACTV INV status of "2").
(6) Projects with stars appearing in seventh column (energy) are projects
for which insufficient data were available to make a complete computer analysis.
A-3
> I .p..
COLUMN LINE
NO. NO.
2A
FORM 2
ITEM NO.
b'i
COLUMN
HEADING
Summary Listing of Existing and Potential Hydropower Projects, Hawaii
Description of Tabulated Data
DESCRIPTION
SITE ID NUM!lEf< U~IUUl 10-CHANACTlk IUt~llFIER FUN tACH Silt.
OEP C QUE
~XAMPLf: HICPOH0003
CHANACT~~s:
1-i'
VALUE:
HI = ST.TE COOt (POSTAL AH!lNtVIATIUNJ
5
4•h
7-10
C = TYPE ANU STATUS CUUt l~tftk Tu FO~M 2 ITEM UESCNIPTION
POH
0003
OUCUMtNIAIIUN FUN ITEM Ha). CODES. lHHU R !NUlCATt
EXISTING PNUJtCTS, S IHRU 3 lNDILATf 8RE.CHED PNUJtC15
AND 4 Tt;HII 9 lNU!CATF UNDEVELOPED t'tiOJECT5 f'UH VAHIUUS
TYPI:S Uf UPti<A T 101;,
: U,S. ARM~ CO~PS Of tNGJr<tt!<!> DISTRICT CUll£ (Ntrt!< Tu
FUNM 2 ITtM OtSCHIPIJUN UOCUMtNTAT!UN FGN ITEM J3J
: UNlwtJt SfLWtNTIAL NUMBER wJIHIN EAC!-1 LJI::.TNICT
IDENTIFICATION OF IINDEVELUPtD PNUJECTS AS AN ALTtNNATiVt TO SOME UTHtN PNUJtCT
Oij AS A PANT OF SUM£ SYST~M, THIS lTtM ALSO !NulCAI£5 AH!CH UN~ UF fHt PUSbl~Lt
ALTtkNATIVf PNUJELTS SH~ULU 8t INCLUDtO IN ~ST!MAftb UF TOTAL NAIIJNAL
POTENTIAL.
THl OEPENDENT/INOEPENOENT CUUl IS UEflNEU AS FuLLO~&:
: lND~PENUtNT SITE.
E : OEPENUENT, ALIENNAT!VE SITE, ~XCLUOEO F~UM
SUMMANltS.
S: OtPtNOENT, PAHT Of A aYST~M. THIS ~liE SHOULU
~E I~CluUtO l~ SUMMARY TAdLLS,
0: UtPtNUENI, ALTE~NATIVE aiiEb ~HICH ANt CHOSEN
HY UISlkiCT fuN INCLUSION IN SU~MAN~ TAbLtS.
r
Vl
COLUMN
NO.
~
~
2
2
2
3
3
3
LINE
NO.
~B
3
2A
26
3
q
2
3
FORM 2
ITEM NO.
3
53
~
40
31
bO
lbO
5b
37
l2b
COLUMN
HEADING
ACTV INV
PO..,ER AREA
PROJt:::CT NAME
PRIMARY COUNTY
NAME OF STREAM
UI'INER
MAP REFEI<ENCE
LATITUDE
LONGITUDE
DR. AREA
Description of Tabulated Data(continued)
DESCRIPTION
ACTIVE IN INVENTORY CODE FO~ lDENflfYlN& ~ITES bASED UN CAPACITY ANO o/~ RATIUS.
(SEE FORM 2 ITEM DESCRIPTION UOCUMENTATION FOR UETAI(tO EXPLANATluN Uf COUEbl.
SOME OF THE MORE COMMON ACTIVE IN INVENTORY COOtS ARE Ab FOLLUWS:
: SITES CONSIDERED INACTIVE FON STUDY THAT HAVE A TOTAL
POTENTIAL CAPACITY 8£h1Et.N 50 1<\W A1~0 1000 1'."1 ANO A tl/C RAflO
GREATER THAN 1.0.
2 : SITE~ CONSIDERED ACTIVE FUN bTUOY IHAT HAVE A TOTAL POTENTIAL
l.APACTTY GNf.ATt.R IriAN iJR El.IUAL TO 10\JO Kr. ANli 1:!/C !<AT 10
GREATER THAN OR ~YUAL TO 1.0 (NOTE: OlHtl< SITtS CHOSEN bY
THE DISTRICTS CAN ALSO HAVE A CUUE : 2 TO lNOICAit ACTIVE
STATUS).
q: SirES CONSIDERED INACTlvt FOR STUDY "'HENE THt IOTAL POTENTIAL
CAPACITY IS L~SS THA~ 50 R~ 0R THE RIC RATIO IS LESS THAN
1. 0.
~ : SITE CONSIDERED INACTIVE FUN STUUY H~CAU~E AOVANCtu ANALYSIS
SHOftED O~VELUPMENT OF THE S!Tt T0 of ECONOMICALLY u~
ENGINEERIN~LY INfEASl~LE.
b : SITE~ CONSlOER~O INACTI~t FUN STUDY ~ECAUSc TH~Y FAILtU THt
SCNEENI~b UN ADVtHSE E~VlNUNMENTAL, ~OCIALo A~~/UR
INSTITUTIONAL lMPACrS.
ELECTRIC NELIAHILITY COUNCIL SUd-NEbTUN l~EUG~APHIC A~EA FON ALASKA).
IUENTIF!CAT!ON NAME OF EXISTING DAM 0~ POTENTIAL "'ATEN MANAbEM~NT PwOJECT
(NOTEI ONLY TH~ ~INST iq CHA~ACTENS UF A PUSbltiLt 40 CHA~ACT~~S A~t PNINIEU).
PRIMANY COUNTY NAME IN ~H!CH THE PNUJtCI IS LOCATED.
NAME OF STREAM ~HERE THE PNUJECT IS LUCAltO,
IDENTIFICATION Of PHOJECT OWNER.
NOTE: DAEN XXX N~PR~SENTS U.S, A~MY CORPS OF tNbiNEE~S
ftHERE XXX INDICATES THE DISTRICT C00E (REFER TU fUN~ 2 ITEM
OESCNIPTION DOCUMENTATION FON A LIST Of JISTNICT CODES AND
FEDERAL AGENCIES).
IOENTIFICATIUN OF USGS MAP SHOftiNG LOCATION OF SITtS ANU UTHEN MAPS AS NEEDED
FOR IDENTIFICATION,
IDENTIFICATION OF P~OJECT LOCATION HY LATITUDE
(DEGREES, MINUTES ANO TENTHS UF MINUTES).
IDENTIFICATION OF PROJECT LUCATIUN ~y LONGITUDE
(DEGREES, MINUTES ANu TfNTHS Uf MlNUTtSJ.
DRAINAGE AREA (IN SYUARE MILE~) OF THE PRUJtCT.
COI.UMN I.IN£
NO. NO.
4
II ~
(I 3
~ 5 1 I
0'\
5 ~
5 3
b 1
b 2
b .s
7 2
3
8 1
B 2
FORM l
ITEM NO.
b2
b3
128
tll
88
1 1
300
310
290
301
3 1 1
2'l1
318
.3181311
COI.UMN
HEADING
PRUJ. PURP,
~TATUS
AVE • f.l
DAM HI
TOT. STOR
PwR. HD,
txiST. CAP,
iNC, CAP,
TOT, CAP,
txiST. t t~Rli.
INC, ENERGY
TOT, ENE~GY
ANUL. COST
ENERGY COST
Description of Tabulated Data(continued)
DESCRIPTION
IDENTIFICATION OF AUTHORIZED PROJECT PURPOSES AS FULLU~S:
I ::: IRRIGATiON R ::: RECRI:.ATION
H : HYO~OELECTRlC 0 : UE8RlS CONTROL
C ::: FLOOD CONTROL P : FAtlM PONU
N : NAVIGATION 0 : UTHEfl
S : WATE:.fl SUPPLY
INDICATION UF PROJECT STATUS AS FULLO~s:
IS = IOENTIFlEU SITE
SP : STUDY PROPOSED
SA = AuTHORIZED FOR STUDY
FP = FEASIBILITY STUDY IN PfiOGflt.SS
Sl : STUDY INACTIIII:
AVI:.HAGE ANNUAL INFI.OW liN CFSI,
PA : PfiUJtCT AUTHURllEU
OM : GDM lN PfiOGRtSS
UC : UNQEfl CONSTRuCTION
OP : PROJtCT lN UPEfiATIUN
NOTE: NEGATIVE vALUES INDICAlt MACHINE DETERMINED VALUtS HASEU UN A
URAINAGE AREA NATIO OF TH~ PNOJECT 10 THE fiEPNtStNIATIVt GAGE.
PHYSltAL HEIGHT (IN FEET) 0~ DAM ABOVt THE ~TNEAM~~U.
CUMULATIVE STORAGE (IN ACNF•FtETJ AI TOP UF FLOUU CUNTAUL POUL. lF ITtM btl ~AS
NUT SUPPLltO, THEN THt STORAGE VALUE WAS lRANSFtRRtU ~RU~ IltM 104, MAXIMUM
STORAGE liN ACRt-~ttT).
WEIGHTED NET POWER HEAO IF UETENMINtu ~y PNO&RAM:
liTEM 111 IF CUMPUTEu 6Y FLO~-UUfiATIUN PHOCEUU~E Ofl TNANSFERNEO ~RuM
NORMAL NET POWtN HtAO liTEM 1051.
AMOUNT UF EXISTING CAPACITY (IN K~) FUfl THE PROJECT.
AMOUNT OF INCREMENTAl. CAPACITY (INK~) THAT IS tST!MAI~U ~ON THt PROJECT.
AMOUNT OF TOTAl. CAPACITY liN K~) THAT IS ESTIMATED ~ON TH~ PRuJtCT (tMI~TlNG
PLUS INCREM~NTAL).
A~OUNl OF EXISTING ENERGY (IN MwHJ FON THE PNUJtCT.
AMOUNT UF INCREMENTAl. AVENAGE ANNUAL ENERGY [IN MwH) THAT I~ ~STIMAlfu FOR !Ht
P~OJECT,
AMOUNT OF TOTAL ENERGY liN MWH) THAI IS ESTlMATtO FUR THE PROJECT (EXISTING PLUS
INCREMENTAL).
TOTAL ANNUAL COST (iN tOOU ~~ OF PRODUCING IHt iNCREMENTAL POTENTIAL AVENAGt
ANNUAL ENERGY THAT IS !:~liMATEt.l F..JR THE P"OJECT.
COST (IN $/MWH) IIF PRODUCING THE INCREMENTAL POTENTIAL ENERGY THAI IS ESTiMATED
FOR THE P~OJECT.
COLUMN LINE FORM a
NO. NO. ITEM NO.
6o8
T"
-....!
8 6o'l
Description of Tabulated Data(contlnued)
~XPLANATION OF ENVIRONMENTAL ANO SOCIAL IMPACT COU~s: (COLUMNS 7 • 8)
ALPHABETICAL CODES y, N, AND U ARt OEFINEU AS FOLLOWS:
Y : YES
N : 1110
U : UNKNOwN
NUMERICAL CODES 1 THROUGH 5 AWE DEFINED AS FOLLUws:
COLUMN
HEADING
ENVRNMNTL IMPACT CODE
SOCIAL IMPACT CODE
1 : MAJOR ADVERSE
2 = MINOR ADVERSE
3: INSlGIIIl~ICANT
4 : MINUH FAVORAMLE
5 = MAJOR FAVORABLE
DESCRIPTION
SEVEN CHARACTER ENVIRONMENTAL IMPACT CODE IS DEFINED A5 FOLLOwS:
CrlARAClEN
PO&IflON OESCRIPTlUN
1ST I\IAllUNALISTATE PANKS ANU WlLUER~ESS
2ND WILU AND SCtNIC RIVER
3RO kESIOENT FISH
4TH ANAUROMOUS ~ISH
5TH WlLDLIFt HA~ITAT
&TH ENDANbENfD SPECIES
7TH wETLANDS
NINE CHANACTtN SOCIAL IMPACT CODE IS Ot~INEo AS FOLLUWS:
CHARACTER
~OSITION DESCRIPTION
1ST COLIUNAL AND HISTUNICAL NtSUUNCES
iND COMMUNITIES RELOCATtO
3NO TNANSPORTAT!ON RELOCATED
4TH FARMLAND
5TH LOCAL GROUP COMMENT
6TH ENViRONMENTAL GROUP CUMM~NT
7TH OTHER G~OUP COMMENT
8TH UTILITY INTEREST
9TH STATE COMMENT
> I
00
Summary Listing of Existing and Potential
Hydropower Projects, Hawaii
Project listing
*******************************************************·~··············~·························································· * SITE IO • PROJECT NA~~ • LATITUUE •PRUJ.PURP.• UAM HT • ~XIST.CAP. •~XIST.~NMG•ANUL. CUSI • ENVlNUNMtNTAL *
* *PRIMARY CO. -NAM£ OF STRtAM •LONldTlJUE • STATUS •TOT. SlUR• INC. LAP. •INC.tNtf<GV•ENEt<GY COST• IMPACT CUD!:. *
* DEP ACTV * Oi"'N~R • O>I.ANEA • AV~. IJ •P"R• HD. • hiT • CAP. •TOT .t!llt:.RGV• *
* CODE !NV * MAP ilEFf.lH:NCF • lD M.M) • • l~ T) • (KW) • (Mi"'H) • l I UOO :b) * *
* * * (0 M.M) • * (AC 1-T) * (1\W) * (M,..H) • (:1>/M,..H) * SOCIAL
* POi"'ER ARF.A * • (Slj.MJJ • tCFS) • (tTl * (1\W) • li-1M;J • • IMPACT CUUt
********************************************************************************************************************************** * HlHPOH0004 * HONOKAA • 20 ').~; * HI * U • 0 • <I • 0 * *
'> * NA ... A! I LOi"'ER HAMAKUA• 1 ')5 2t!.? • uP * 0 • U * U • 0
* * Htli;UKAA SUGAI-i CO • • O• 4l:,.u • iJ ********** • *
* • • * HINPOHOOO~ • PAPAIKOU MILL
* ~ * rlAWA!l HONULll
• HILU CUA&T PAOCESSlNb CO
• HIHPOH0002 * PliUfO
* 5 • HAWAII WAILUKU
• HA~AII ELECT~IC LIGHT LO
• • •
• • •
• l'l 46.'1 •
• l ~5 '}. ll •
• • • * l'l 45.R *
• 1"1~ 5.~ •
• •
* HIQPOHOOOb • UNION MILl * 20 12.0
* I 2 • HA~All KIIHALA UITCH • 155 4t!.O •
* * K{)HALA SUGAR CO • 2 *
* HIHPOH000j * WAIAU
~ * HAwAll WAILUKU
• HAwAII ELECTWIC LlbHT CO
• •
• H15POH0001 • ~AILOA
2 * HAwAII
•
I"'A!LOA
* KUKUIHAELE, KAMUELA QUAOS
* HICPOHOOO'l * i"'AHIAI"'A WESENVOIR
2 * HONOLULU KAUKONAHUA
* * "'U ALUA !JUGAl< CO
* * HALtlWA UUAO
•
l'l 4.~.4
• •
• I')~ 7 • 3 •
• •
• 20 <.I.K
• 155 ~7.3 •
1 4
• 21 3U.li
• •
ST• l"'t! 3.U •
• 1 7 *
• HIJPOH0018 * ALEXANDER >~ESER\IlllW • 21 57 .b
* :, * KAtJAl WAH!AI"'A SHH:A• !59 31.') *
• MCdRYD~ SUGAR C(J L TO • 3
* I<OLOA (JUAO
• • * HISPOHDOII • HANALEI
2 * 1\AUAl
• 22 7.8
HANALEI NIVER* IS'l 28.0 *
* lU • * HANALEI !JLIAD •
H
OP
H
dP
Hl
H
OP
H
IS
I~
OP
• • •
O•
O•
• • •
<~t.u•
•
0•
7 I • D •
•
-212.u•
• •
IH:; *
OP
H
IS
-6.5•
•
IU<~.U•
•
• •
0 •
() .
201.0 •
(J •
(J •
<IPU.O *
u •
(J *
':lh<l.4 •
u •
\) .
522.v •
• •
I U. o •
u •
2'>2. 7 •
• •
'll!.tJ •
\J ..
""·" .
•
ll'l.u •
0 •
694.5 •
•
I 0. v *
* 2bC:. 7 •
•
•
0 •
0 •
•
\J •
l) •
0 ********** * •
(l •
0 •
\! •
\) .
0 •••••••••••
•
0 •
5()0 •
5u (l •
• • u •
() .
•
0 •
4100 •
~lou •
\) .
v •
0 ********** *
•
I) •
2'10{1 •
~'100 •
• •
(J •
<'~<Ov •
2oll0 •
IOUO *
0 •
1000 •
0 •
450() •
4':>tJ0 •
•
u •
I<'~Ov •
12)0U *
\J •
7':10\J •
I'> 0 v *
2111\J •
\) .
2!(1 u •
v •
lb'>VV *
lb'>Ov •
u
0
0
0
Y4.btl7
c' -~. 'I <I
u
(J
II 'loll
'-17 r!.. I 4
'l04.b'l
~.~.9o6
0
l<'ll~v
12o.~~
•
*
*
*
•
*
•
NNNNNNN
UNNNUUliNU
NNNYN11.111
UNNNUliUIIiU
NNV n Ny
YNNYUYUUU
v N y NI•NI•
i•f•N V V Y UUU
t<NVVYVY
YNNn VUUY
•
•
•
•
•
**********************************•••······~······················································································
~
\.0
Project Listing(continued)
********************************************************************************************************************************** * SITE ID * PROJECT NAME * LATITUDE •PROJ.PURP.• DAM HT * EKIST.CAP. •EKI5T.ENNG•ANUL. COST * ENVIRONMEhTAL * * * PRIMARY CO. -NAMt OF STREAM •LONGllUOE * 5TATUS •TOT. STOR• INC. CAP. •INC.ENERGY•ENENGY CU5T• IMPACT COOt *
* OEP ACTV * O~NER * DR.AREA * AVE. Q •PwN. HD. * TOI. CAP. •TOT.ENENGY• * *
* CODE INV * MAP REFERENCE * (0 M.Ml * * HTJ * (K~l * (M.-.H) • (1000 Sl * *
* * * (0 "'.M) * * (AC FT) * (Kill) * (M~H) * (.)/MWH) * ::iOClAL *
* POWER "REA * * (SU.IH l * (CFS) * (fT l * (KV<) * (Mo'IH) * * IMPACT COOt *
********************************************************************************************************************************** * HIHPOH0022 * HYDRO KAUMAKANI * 22 0.1 * HI * 10.0 * 500 * 3100 * 247.b1 * NNUUNNN *
* 2 * KAUAI MAKAWELI * 159 3&.8 * UP * 0 * 7SO * 8300 * 29.833 * *
* * OLOKELE SUG"R CO * ~ * -10.1• 21Uol * 1250 * 11400 * * UNNNUUUNU *
* * WAIMEA CANYON QUAD * * * • • * * *
* * * • * HICPOHOOib * KAPAIA RESERVOIR * 22 1.1 *
* ~ * KAuAI HANAM"ULU STR• 159 23.9 *
* * LIHUE PLANTATION CO LTD * 2 *
* *
* *
* * *
* * Hl7POH001c * KOKEE WATER PROJECT * 22 7.9 *
* 2 * KAtlAl KAWAIKOI STRE• 159 37 .II *
* * STATE * 1 *
* * HAENA, KEKAHA, MAKAHA POINT,•
* *
*
*
*
I *
OP *
.q.q.
*
* HlNO *
51 * -B.••
* • * HICPOH0017 * KOLOKO ~ESERVOIR • 22 1 u. 7 * I * * ~ * KAUAI OFFSTNEAM • 159 22.9 * OP * -<;.5• * * MA~Y N LUCAS ESTATE
* • * •
* 1 *
*
*
*
*
*
* * HIKPOH0021 *LONER LIHUE * 22 1.2 * Hl *
* I <; * KAUAI N ~AILUA-ILIC• 159 2b.B * OP *
* * L[11UE PLANTATION Cu • * '111.0•
*
*
*
* • HICPOHOOI5 * PUU LUA RESERVOIR
* 2 * KAUA[ TK•HAELEELE
* * KEKAHA SUGAR CO LTD
* • MAKAHA POINT QUAv
* *
*
*
*
* * 22 5.':> *
S• 159 40.8 *
• 1 *
* *
*
* * HIKPOH0020 * uPPER LIHUE * 22 1.4 *
* 5 * KAUAI N ~AILUA-ILIC• 15~ ~7.9 *
* * LI11UE PLA~lATIO~ CO * *
*
* * HI7POH0014
* E 2
* •
*
*
* * U!ALE.ALE
* KAUAI
* $TATE * iiiAlALEALE.,KAPAA
* * HlHPOH0024 * WAlAWA
*
*
*
* 22 1. q *
SOUTH FORK iliA* 159 22.8 *
lJUAOS
* 18 *
*
*
* •
* 5 * KAUAI KAHOANA
* 21 59.1! • * 159 43.5 *
* * KEK"HA SUGAR CO
* • * * * *
I
UP
..
*
*
* -f:>3.'h
*
*
HI *
uP •
HlN
FP
Hl
OP
2<'.0•
* *
*
* -57 .1•
*
* • •
O•
*
•
u *
II •
-37.1 *
*
* 24u.u •
0 •
'IS'l.u •
* u •
u *
3~.9 *
*
II *
II *
2118.0 * •
* 11o.o •
II *
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NHS MAPS
Two maps are inserted into the adjacent pocket. One is an index map
and one is a site location map. The primary purpose of the index map is
to show the National Electric Reliability Council (NERC) regions, the
Corps of Engineers division and district boundaries, and Corps office
locations. A separate regional report and accompanying site location map
has been prepared for each of the NERC regions depicted on the index map.
The second map shows existing and potential hydroelectric site locations
for the subject region and is intended to provide general information to
the reader about the sites. The size of a project is depicted by the
diameter of the circle and the type of project by color. Each site symbol
on the map is labeled with a four digit number which corresponds to a ten
character National Hydroelectric Power Resources Study site identification
code. Each part of the 10 character ID code helps to narrow down the
source of information for that site. For example, a typical site identi-
fication code is shown below:
0 R A
State_j J
Type of Project
N P P 9 9 9 9 L Lsite ID Number
Corps Division and District
Consequently, for more information about a site, one needs to determine
from the map a site's state and county, the Corps division and district,
and the four digit number. With the site ID number, the site can then
be located in the list of sites in the regional report or in Volume XII
of the ~TfiS final report. If more detailed information is desired, the
appropriate Corps division and/or district office may be contacted.