HomeMy WebLinkAboutAPPENDIX 2 - Adak Hydropower Feasibility and Conceptual design - appendices 2
Hatch Feb. 2013 report
TDX Power
615 E. 82nd Avenue, Suite 200 Anchorage AK 99518
Reconnaissance Study - Final Report
For
TDX Power - Adak Reconnaissance Study
H343115-0000-00-236-0001
Rev. 1
02/06/2013
TDX Power - Adak Reconnaissance Study
Final Report
Prepared by Hatch, 2/16/2013
H343115-0000-00-236-0001, Rev. 1
Page 1
Project Report
02/06/2013
TDX Power
Adak Reconnaissance Study
Distribution
Martin Miller, TDX Power
Final Report
Table of Contents
Terms, Acronyms, and Abbreviations ...................................................................................................... 3
1. Introduction ........................................................................................................................................... 4
1.1 Community Overview .................................................................................................................... 4
1.1.1 Location: .............................................................................................................................. 4
1.1.2 History ................................................................................................................................. 4
1.1.3 Military Uses of Adak .......................................................................................................... 5
1.1.4 Climate: ............................................................................................................................... 6
1.1.5 Land Ownership: ................................................................................................................. 6
1.1.6 Facilities: ............................................................................................................................. 7
1.2 Previous Hydroelectric Studies ..................................................................................................... 7
2. Geography ............................................................................................................................................. 8
3. Geology ................................................................................................................................................. 9
4. Site Control ........................................................................................................................................... 9
5. Environmental and Aquatic Resources ........................................................................................... 10
6. Existing Infrastructure ....................................................................................................................... 11
6.1 Existing Generation and Demand ............................................................................................... 11
6.2 Water System ............................................................................................................................. 12
7. Water Use ............................................................................................................................................ 12
8. Hydrology ............................................................................................................................................ 14
9. Project Options and Initial Evaluation .............................................................................................. 18
10. Lake Bonnie Rose to Mitt Lake Project Analysis ............................................................................ 20
10.1 Description .................................................................................................................................. 20
10.2 Analysis ....................................................................................................................................... 21
10.3 Cost Estimate .............................................................................................................................. 23
10.4 Economic Value .......................................................................................................................... 24
11. Existing PRV Project .......................................................................................................................... 26
12. Recommendations ............................................................................................................................. 28
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13. References .......................................................................................................................................... 29
Table 1 - Lake Summary ............................................................................................................................... 8
Table 2 - Existing Applied, Permitted, or Certificated Water Rights, Lake Bonnie Rose and De Marie ..... 12
Table 3 - USGS Stream Gauge Summary .................................................................................................. 14
Table 4 - Rainfall Data ................................................................................................................................ 14
Table 5 - Project Stream Flow Derivation ................................................................................................... 17
Table 6 - Derived Monthly Average Stream Flows (cfs) for Each Project Location .................................... 17
Table 7 - Project Options and Analysis Matrix ............................................................................................ 18
Table 8 - Mitt Lake Project Cost Estimate ................................................................................................... 24
Table 9 - Mitt Lake Project Performance Summary (Town load only) ........................................................ 25
Table 10 - Mitt Lake Project Performance Summary (Town and Processor load) ..................................... 25
Table 11 - Existing PRV Cost Estimate ...................................................................................................... 26
Table 12 - Existing PRV Project Performance Summary (Town load only) ................................................ 27
Figure 1 - Adak Location ............................................................................................................................... 6
Figure 2 - Adak Demand Profile .................................................................................................................. 11
Figure 3 - USGS Monthly Average Stream Flow Chart .............................................................................. 16
Figure 4 - Lake Bonnie Rose Hydrograph .................................................................................................. 20
Figure 5 - Lake Bonnie Rose Flow Duration Curve .................................................................................... 21
Figure 6 - Mitt Lake Project Operation Chart without Environmental Flow Restrictions ............................. 22
Figure 7 - Mitt Lake Project Operation Chart with Environmental Flow Restrictions .................................. 22
Attachments
Plate 1 - Location Map
Plate 2 - Site Map
Plate 3 - Project Map
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Terms, Acronyms, and Abbreviations
TERM MEANING
ADNR Alaska Department of Natural Resources
AEA Alaska Energy Authority
Avg Average
BTU British Thermal Unit
cfs Cubic feet per second
cyd Cubic yards
Dia Diameter
DIP Ductile Iron Pipe
ea Each
FERC Federal Energy Regulatory Commission
gal Gallon
gpd Gallons per day
gpm Gallons per minute
HDPE High density polyethylene
ID Inside diameter
kVA Kilo Volt-Amps
kW Kilo Watt (1000 Watts)
kWh Kilo Watt-hours
lb Pound
mgd Million gallons per day
mi Mile
mmBTU 1 million BTU's
mo Month
O&M Operation and Maintenance
OD Outside Diameter
SDR Sidewall Diameter Ratio
sq ft Square feet
sq mi Square miles
sq yd Square yard
TDX Tanadgusix Corporation
TDX Power Subsidiary of TDX, owner and operator of regulated utilities in Sand Point, Manley,
Adak, and Prudhoe Bay.
USGS United States Geological Survey
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1. Introduction
TDX Power is evaluating renewable energy options for the city of Adak, Alaska and has
tasked Hatch with an update to the July, 2011 Adak Reconnaissance Study, Final Report.
The general purpose of this report update is to include recently collected demand information
in the comparative analysis between the different potential hydroelectric developments,
perform an initial cost estimate for the recommended project(s), and incorporate improved
mapping that was used to identify the different alternatives into the report.
It has been found that there are numerous hydroelectric generation possibilities on the island
of Adak. This report identifies the different potential projects and performs a high level
comparison of the options. While this report includes a brief analysis of the most likely option,
most of the options should be vetted further with site visits and additional data collection and
analysis before making a recommendation for future development.
1.1 Community Overview
Current Population: 326 (2010 U.S. Census Population)
Pronunciation/Other Names: (A-dack); formerly Adak Station
Incorporation Type: 2nd Class City
Borough Located In: Unorganized
School District: Aleutian Region Schools
Regional Native Corporation: Aleut Corporation
The community incorporated as a second-class city in April 2001.
1.1.1 Location:
Adak is the southern-most community in Alaska, on the latitude of Vancouver Island in
Canada. The former Navy Air Facility Adak is located off the Alaskan mainland near the
center of the Aleutian chain, approximately 1,200 miles west-southwest of Anchorage,
Alaska. Flight time to Anchorage is three hours. Adak Island’s coordinates are latitude
51°53’0" N, at longitude 176° 38’46" W. The Bering Sea surrounds the island to the north
and the Pacific Ocean to the south. Adak is located in the Aleutian Islands Recording District.
The area encompasses 122.4 sq. miles of land and 4.9 sq. miles of water.
1.1.2 History
The first inhabitants of Adak Island were the Aleuts. Archaeological evidence reflects
occupation as early as 9,000 years ago. The Aleuts hunted whales, seals, otters and sea
lions, as well as island birds, and fished Adak’s freshwater streams and the surrounding seas.
They lived in large, communal, subterranean structures of grass and earth built over driftwood
or whalebone frames. The Aleuts developed technologies such as sophisticated kayaks and
waterproof clothing to deal with the cool marine environment. Aleut settlements were often
located in coves along freshwater streams. Remnants of prehistoric Aleut settlements remain
on Adak today.
Russians first visited the Aleutian Islands in the early 1740s and were trading with the Aleuts
by the 1750s. As recently as 1827, Adak was a busy trading settlement with a population of
193 Aleuts. By 1830, Russian settlers had occupied Adak and relocated the Aleuts to
Russian settlements in Kodiak, the Pribilof Islands, and Sitka. Adak Island became part of
the Alaska Territory, which was subsequently purchased from Russia by the United States in
1867. Even after the permanent Aleut villages were abandoned, seasonal and subsistence
use of the island continued. By 1910, over hunting by outsiders had nearly depleted the once-
abundant sea otter and fur seal populations. In 1913, Adak Island was included in the 2.9-
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million-acre Aleutian Islands National Wildlife Refuge (renamed the Alaska Maritime National
Wildlife Refuge in 1980) established by the President. This refuge was set aside as a
preserve and breeding ground for native birds and fur-bearing animals and as an important
fisheries habitat. Seasonal and subsistence use of the island by the Aleuts continued up until
the time of World War II, when Aleuts in the island chain were evacuated to internment
camps.
1.1.3 Military Uses of Adak
Since the early 1940s, the northern half of Adak Island has been used for military operations.
During World War II, Adak Island became the site of a military base operated by the Army Air
Corps for defensive action against Japanese forces occupying Attu and Kiska Islands in the
Aleutian chain. In the spring of 1944, Adak’s population included at least 32,000 military
personnel. In preparation for a major offensive on the Japanese-occupied islands of Kiska
and Attu, as many of 90,000 troops on ship or shore were mobilized to the Aleutian arena.
Since the war, the military presence on Adak has fluctuated, depending on United States
defense policy and federal appropriations, and has generally not exceeded 6,000 persons.
After the war, the base was transferred to the U.S. Air Force (renamed Davis Air Force Base)
and, according to Army Corps of Engineers records, encompassed all of Adak Island. The
U.S. Air Force withdrew from Adak in 1950, and the Navy assumed all facilities on Adak
Island. In 1953, only 15 officers and fewer than 200 enlisted men were assigned to the base.
In 1959, Public Land Order No. 1949 withdrew land described as representing approximately
61,000 acres (the resurveyed land mass is 79,200 acres) of Adak Island (approximately the
northern half) for use by the Navy.
By 1966, military and civilian personnel totalled almost 1,000, a number that stayed fairly
steady through the 1970s. By 1981, the population had doubled by 2,000. In 1984, the Adak
Naval Station was renamed Naval Air Station (NAS) Adak. By 1990, over 5,000 people were
at the base, almost 3,000 of whom were military, the remainder composed of military
dependents and civilian employees. In 1994, NAS Adak was designated as Naval Air Facility
(NAF) Adak. As of February 1996, following military draw down and closure of Naval Security
Guard Activity (NSGA), approximately 500 military and 50 civilian personnel were stationed
on Adak. Subsequent to its listing under Base Realignment and Closure in July 1995, the
military mission at Adak was ended on March 31, 1997. The Aleut Corporation purchased
Adak's facilities under a land transfer agreement with the Department of the Interior and the
U.S. Navy/Department of Defense. This agreement was finalized in March, 2004.
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Figure 1 - Adak Location
1.1.4 Climate:
The maritime climate on Adak is characterized by persistently overcast skies, high winds, and
frequent, often violent, cyclonic storms originating in the northern Pacific Ocean and Bering
Sea. Weather can be localized, with fog, low ceilings, precipitation, and clear weather all
occurring within a distance of a few miles. Storms can occur during any season, although the
most frequent and severe storms occur during the winter.
Mean annual precipitation for Adak Island is about 66 inches, most of which falls as rain.
Average monthly precipitation varies from a low of 3 inches in June and July to a high of 7 to
8 inches in November and December. Snowfall averages over 100 inches per year. Because
of the relatively warm temperatures, snow rarely exceeds 1 to 2 feet in depth and is
concentrated in the mountains.
Mean monthly temperatures vary from a low of 32.9° F in February to a high of 51.3° in
August. The highest temperature recorded on Adak is 75° F (August 1956), and the lowest
temperature is 3 degrees F, recorded in January 1963 and February 1964.
1.1.5 Land Ownership:
A land exchange between Aleut Corp., the U.S. Navy, and the Department of the Interior has
transferred most of the naval facilities to the Aleut Corporation. A portion of the island
remains within the national Maritime National Wildlife Refuge, managed by the U.S. Fish &
Wildlife Service.
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1.1.6 Facilities:
After World War II, the U.S. Navy developed facilities and recreation opportunities at Adak. A
movie theater, roller skating rink, swimming pools, ski lodge, bowling alleys, skeet range, auto
hobby shop, photo lab, and racquetball and tennis courts were developed. An $18-million
hospital was built in 1990. As of 2009, all of these facilities are closed.
Substantially all of the infrastructure and facilities on Adak are owned by Aleut Corporation,
who is currently developing Adak as a commercial center via their subsidiary companies. The
former base has two areas with extensive development. The first is the "downtown" area of
Adak, where NAF was located and which includes the airfield, port facilities, landfills, sewage
treatment facilities, light industrial, administration, commercial, recreational, and residential
areas. The second main developed area, formerly used by NSGA, includes the northern part
of the island and areas around Clam Lagoon. The NSGA area is no longer used.
Water is derived from Lake Bonnie Rose, Lake De Marie, and Nurses Creek, stored in any of
the seven water tanks throughout the community, and piped to facilities and housing units.
The wastewater treatment system discharges through a marine outfall line to Kuluk Bay.
Husky Road landfill is a class III permitted landfill.
Adak provides a fueling port and crew transfer facility for fishing fleets, and an airport, docks,
housing facilities, restaurant, grocery store, and ship supply store are available. The seafood
processing facility can process about 500,000 pounds of fish per day. In 2010, two residents
held commercial fishing permits.
Adak Airport is a State of Alaska owned & maintained certificated airport. It has two asphalt
paved runways; one measures 7,790' long by 200' wide, and the other runway measures
7,605' by 200' wide. Alaska Airlines operates passenger and cargo jet service. There are
three deep water docks and fueling facilities. In 2009, the city was in the process of
expanding the Sweeper Cove small boat harbor to include new breakwaters, a 315' dock, and
new moorage floats. Adak has approximately 16 miles of paved roads, as well as gravel and
dirt roads.
1.2 Previous Hydroelectric Studies
A previous study by Ebasco Services Inc. (Ebasco, 1980) looked at four sites:
Sites 1 and 2 - run of river sites located on the west side of Mt. Moffett (not included in
this report).
Site 3 - Lake Bonnie Rose to Lake De Marie.
Site 4 - Lake Betty to tidewater.
The reported states "Sites does not have economic hydropower development potential." It
also noted that there were environmental concerns with salmon migration in streams with
hydropower potential.
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Information provided for sites 3 and 4 include the following:
Site 3 4
Intake Location Lake Bonnie Rose Lake Betty
Powerhouse Location Lake De Marie Tidewater
Average Annual Streamflow (cfs) 14.8 12.8
Total Head (feet) 200 200
Net Head (feet) 180 180
Installed Capacity (kW) 192 166
No other studies investigating hydroelectric potential in Adak have been found.
2. Geography
Adak Island was formed by extreme geologic events, including the tectonic collision of large
sections (plates) of the earth’s crust and resulting volcanic eruptions. Advancing and receding
glaciers, frequent rainfall, and high winds have shaped Adak Island into a dramatic landscape
of hills, valleys, cliffs, and floodplains. Very few areas of the island are flat, and grading to
create flat areas could not be done easily.
The highest point on Adak Island is Mt. Moffett (elevation approximately 3,875 feet). Some
coastal cliffs on the island rise 2,500 feet above sea level.
Topographic data was obtained from CAD drawing files provided by TDX. The files were
developed by PND Engineers and contained 20' interval contours for areas located within the
naval base boundary. For areas outside the PND mapping area topographic data from the
Shuttle Radar Topography Mission and USGS was used along with 1:50,000 scale U.S.
Defense Mapping Agency maps of Adak (updated in 1974) containing 20 meter interval
contour data. Plate 1 at the end of this document shows the USGS map for the island.
The upland topography of Adak is typical of the Aleutian Islands with rolling, steep terrain,
volcanic features, and shallow, but often sharp crested, stream valleys. The vegetation
primarily consists of grass with no trees or shrubs. Some exposed bedrock and areas of
eroding volcanic soils can be found.
Several large lakes are formed in what are likely glacial carved depressions. These are
primary candidates for hydropower development. The table below summarizes the lakes in
the vicinity of the developed area of Adak.
Table 1 - Lake Summary
Sources Elevation, ft Basin Area (at outlet), sq mi Surface Area, acres
Lake Bonnie Rose 739 1.55 139.2
Lake De Marie 234 3.59 86.7
Heart Lake 153 4.18 36.4
Lake Betty 159 4.43 136.6
Lake Leone 113 0.88 78.3
Mitt Lake 45 0.78 12.4
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3. Geology
Adak Island was created during the last 60 million years by a complex set of geologic
processes resulting from the collision of the North American and Pacific crustal plates. The
resulting rock sequences consist primarily of volcanic rocks with some sedimentary rock. A
relatively thin layer of unconsolidated material (generally less than 10 feet think) covers the
entire island. Only the downtown area is known to have a thick sequence of unconsolidated
material (greater than 100 feet). The northern region of Adak is dominated by the remnants of
three volcanoes.
Throughout most of the project area, a 2 to 3 meter thick mantle of tephra blankets other
surficial deposits and bedrock. A 1995 geologic map for the area indicates bedrock and
tephra deposits in the area around Lake Bonnie Rose and Mitt Lake. The following is reported
about the surficial deposits and bedrock in Adak (Waythomas, 1995):
Tephra deposits are usually 1.5 to 3.0 m thick and consist of thin beds of fine grained
(mostly silt and clay size particles) ash and 3 to 5 beds of lapilli-sized (2-64 rnm) tephra.
Locally interbedded with peat. Many of the ash layers are weathered to clay. Somewhat
porous, but permeability is limited by fine particle size. Lapilli beds are more porous and
permeable than the fine grained tephra layers. Locally water bearing, especially in low-
lying areas.
Areas of bedrock may include minor amounts of talus and colluviurn. In areas away from
Mount Moffett and Mount Adagdak, most of the bedrock consists of Finger Bay Volcanics
(Coats, 1956). These rocks are extensively fractured and faulted, and locally exhibit
some weathering. Zones of bedrock where fracture density is high may be porous and
permeable and may be water bearing.
The hydroelectric projects envisioned in this report will require roads or trails to the
powerhouse and intake locations. Pipelines can be located outside road access and laid on
supports or directly on the ground or buried. Construction equipment use may be limited
where pipelines are located off road in Tephra deposits without a solid base to support the
equipment. Some difficulties may also be encountered burying pipelines within road footprints
due to existing infrastructure. The cost estimate assumes no difference in cost for pipelines
located off road versus pipelines buried within the roadway.
4. Site Control
Land ownership and use has not been investigated as part of this study. All of the projects
considered in this report are located outside the US Fish and Wildlife Refuge boundary and
are presumably entirely owned by the Aleut Corporation or the City of Adak, both with an
interest in lowering the cost of electricity generation in order to improve economic
development and sustainability for Adak.
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5. Environmental and Aquatic Resources
This report does not address in any detail the potential environmental impacts of the projects
considered. A review of the ADF&G's catalog of anadromous habitat indicates that all of the
project options are located on streams that have anadromous fish in their lower reaches.
Approximate habitat locations based off the catalog are as follows. It is possible that the
catalog is not entirely accurate with some reaches shorter or longer than stated.
Lake Bonnie Rose - Lake De Marie - Heart Lake drainage: The upper limit of anadromous
habitat is estimated at about elevation 100', reach about 1000' long.
Lake Leone: The upper limit of anadromous habitat is estimated at elevation 60', reach about
630' long.
Lake Betty: The upper limit of anadromous habitat is estimated at elevation 30', reach about
2200' long.
Mt Reed Creek: The upper limit of anadromous habitat is estimated at elevation 250', reach
about 1300' long (note: average gradient ~20%).
Mt Moffett Creek: The upper limit of anadromous habitat is estimated at elevation 20', reach
about 1500' long.
Additionally, many of the streams and lakes support resident fresh water species such as
Dolly Varden and trout (HDR 2011). The protections for these non-anadromous aquatic
resources are evident in the water use reservations for fish passage purposes identified later
in this report.
The presence of fresh water species found in the lake system, and likely in other streams as
well, is the most significant concern for hydroelectric development. All of the potential hydro
schemes are run of river projects that bypass natural stream reaches. Additional habitat and
instream flow investigations, focused on hydro related impacts, must be undertaken for
permitting any of the proposed projects.
A potential concern with excavation for installation of pipelines and foundation structures is
the presence of contaminated sites and unexploded ordinance. Extensive information
regarding site assessment and cleanup activities is available at the environmental cleanup
and closure of the former Naval Air Facility, Adak, Alaska website
(http://www.adakupdate.com/).
Water quality may be a concern in the design of pipe works and intake equipment. A report
on the water system (Bristol, 2010) indicates that the water from Lake Bonnie Rose is
"aggressive" with a low pH and a high amount of dissolved oxygen. Cathodic protection was
strongly recommended for the water system.
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6. Existing Infrastructure
6.1 Existing Generation and Demand
An updated demand profile consisting of hourly data, for a 12 month period, was provided by
TDX for a time span between 2011 and 2012. This profile is based on metering of an
operational fish processing plant and, because separate metering was not available for the
town, a synthesized town load was developed by TDX. The synthesized profile was created
using totalized sales data that was converted to hourly demand using daily load variations
measured at the TDX power plant in St. Paul and scaled to Adak’s energy profile. This data
is shown in the following figure.
Figure 2 - Adak Demand Profile
The existing generation equipment consists of oversized, for the current load, caterpillar 3516
diesel generators. TDX Power reports that one new high efficiency unit is being installed that
will be sized for the current and expected future demand.
Hydroelectric project benefits are evaluated using an operational model. The modeling of the
existing diesel generation system ignores efficiency and is simplified to a single performance
parameter of 14 kWh/gal. The model also includes a minimum diesel loading of 40 kW but
does not include minimum run time, maintenance, and capital replacement costs. Both load
cases (Town only, and Town with Processor) are considered in the analysis and presented in
this report.
0
100
200
300
400
500
600
700
800
1/1 1/29 2/26 3/25 4/22 5/20 6/17 7/15 8/12 9/9 10/7 11/4 12/2 12/30Demand (kW)Date
Adak Daily Average Demand Profile
Average Town + Icicle Average Town Only
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6.2 Water System
Lake Bonnie Rose and Lake De Marie have existing dams at their outlets for collection of
water. As indicated in the Design Analysis Report for the water system (Bristol, 2010), the
current source of raw water is from Lake Bonnie Rose.
The Lake Bonnie Rose dam has a crest elevation of 739' and is a concrete cantilever wall
type structure. The outlet works of the existing Lake Bonnie Rose dam consists of a screened
inlet in the reservoir connected to a 12" pipe penetration with an invert elevation of 731.25'.
Water is conveyed through an existing 10" ductile iron pipeline, circa 1990's (Bristol 2010 and
WHPacific, 2012), from Lake Bonnie Rose to a PRV located at elevation 306' and set to 70
psi (PRV-1). There are numerous tanks and PRV's that serve various distribution areas.
Water tank capacity on Adak is 3.7 million gals with 1.9 million gallons in use ("A" and "B"
tanks). The Adak system operator has reported that the overflow elevation of tanks A and B is
235.8' and 231.9' respectively.
7. Water Use
The Alaska Department of Natural Resources (ADNR) Water Resources division manages
water rights in Alaska and reports the following existing uses.
Table 2 - Existing Applied, Permitted, or Certificated Water Rights, Lake Bonnie Rose and De
Marie
Month Potable Export -
Bonnie Rose
Export - Lake
De Marie
Environmental(a) -
Lake Bonnie Rose(b)
Environmental(a) -
Lake De Marie(c)
Jan 1.4 0.8 0.8 5 10
Feb 1.4 0.8 0.8 5 10
Mar 1.4 0.8 0.8 5 9
Apr 1.4 0.8 0.8 5 9
May 1.4 0.8 0.8 4 8
Jun 1.4 0.8 0.8 4 8
Jul 1.4 0.8 0.8 4 8
Aug 1.4 0.8 0.8 4 9
Sep 1.4 0.8 0.8 5 10
Oct 1.4 0.8 0.8 5 11
Nov 1.4 0.8 0.8 5 12
Dec 1.4 0.8 0.8 5 10
Notes:
(a) Environmental flows from Lake Bonnie Rose and Lake De Marie exclude flows from Heart Lake.
(b) Minimum of 2" over Lake Bonnie Rose spillway also established equal to 3.3 cfs1.
(c) Minimum of 2" over Lake De Marie spillway established equal to 14 cfs2.
Water rights for potable use by the City of Adak includes both Lake Bonnie Rose and Lake
De Marie but the Lake De Marie water collection system is currently not operable. TDX Power
reports, based on a discussion with the City of Adak Public Works Director, that water flow at
1 Lake Bonnie Rose Dam Safety Inspection Report indicating spillway width of 14.5' and a coefficient of
3.33.
2 Lake De Marie Dam Safety Inspection Report indicating spillway width of 51.5' and a coefficient of 4.
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PRV-1 is about 215 gpm (0.5 cfs). This includes continuous, unmetered overflow at the A-
tanks. Actual potable water needs are unknown. Domestic water use is presumed to be 215
gpm in the analysis. Future modifications to the water system suggests construction of a new
water treatment plant with design flows of 35 to 70 gpm (Bristol, 2010).
Water use with the fish plant online is estimated, by the public works director, to be up to 800
gpm (1.8 cfs). The water system report (Bristol, 2010) indicates there are plans to convert the
fish processing service to raw water supply. No information on the timing or future supply
source of this use has been obtained and it is not included in the hydropower analysis.
The water rights for export aren't fully representative of actual plans for export operations.
TDX reports that the export plan is to tap into the existing raw water pipeline above PVR-1
and route approximately 1/2 mile of new 12” HDPE to discharge directly into an ocean vessel.
Each vessel can hold 5 million gallons. Estimated fill time is 8 hours (23 cfs). It is noted that
the export operation would station one person at the dam during each vessel filling operation
to monitor lake level to ensure compliance with the water rights permit. The export operation
expects to load one vessel (5 million gal) every 10 days.
The export operation includes Lake Betty, with the largest average annual flow, as a potential
source for water export. Unused water tank capacity could be used to store water for the
export operation as well to reduce instantaneous demand from Lake Bonnie Rose when a
vessel is in for filling. The assumed quantity of water used in this analysis for export is the
amount of 0.5 mgd as described in the water rights application.
In addition to the monthly environmental flows, the water rights include a minimum of 2" of
water over the spillway of Lake De Marie, equivalent to 14 cfs, which also effectively
establishes environmental flows at the outlet of Lake Bonnie Rose of 6.4 cfs based on the
relative basin areas. The analysis of the selected project disregards this criteria and uses the
less stringent monthly environmental flows established at Lake Bonnie Rose instead.
Environmental flows have the most significant impact on hydroelectric operations. The
minimum bypass flows established at the dams, particularly the minimums for overflow at
Lake De Marie, significantly curtail the potential water available for hydropower. Additionally,
the environmental flows practically eliminate the potential of using the existing dams as
storage reservoirs. Environmental flows are excluded from the initial identification of projects
and preliminary analysis. However, environmental flows are included in the detailed analysis
for the selected project. Additional investigation of flows for fish passage requirements, which
can result in changes in the existing environmental flows, will require significant data
collection, analysis, and consultation with ADF&G and ADNR.
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8. Hydrology
Short, steep-gradient streams draining radially from Mt. Moffett, Mt. Adagdak, and other
upland areas characterize the surface water hydrology of the northern portion of Adak Island.
Perennial flow is maintained by snowmelt in the mountains and seepage from the shallow
surficial soils. Numerous lakes and sediment deposits occur along stream courses.
The USGS has measured stream flows at two locations on Adak Island in addition to
numerous sites on Amchitka, two on Shemya, and one at Cold Bay. The following table
summarizes the data for these sites.
Table 3 - USGS Stream Gauge Summary
No. of Records Basin Area Unit Flow (cfs/mi^2)
Station ID Station Name Begin Date End Date Days Years Sq Mi Avg Med
15297610 RUSSELL C NR COLD BAY AK(a) 10/1/1981 6/23/2011 7663 21.0 30.9 8.2 6.7
15297617 SWEEPER C AT ADAK IS AK 10/1/1992 4/22/1996 1300 3.6 1.0 4.1 2.7
15297625 MOFFETT C AT ADAK IS AK 10/1/1993 4/22/1996 935 2.6 4.5 6.0 4.9
15297640 LIMPET C ON AMCHITKA IS AK 11/1/1967 9/30/1972 1796 4.9 1.7 3.1 2.1
15297650 FALLS C ON AMCHITKA IS AK 4/1/1968 2/19/1972 1420 3.9 1.0 2.1 1.6
15297655 CLEVENGER C ON AMCHITKA IS AK 4/1/1968 5/23/1974 2244 6.1 0.3 3.8 2.7
15297680 BRIDGE C ON AMCHITKA IS AK 11/1/1967 8/28/1974 2493 6.8 3.0 1.5 0.8
15297690 WHITE ALICE C ON AMCHITKA IS AK 4/1/1968 8/27/1974 2340 6.4 0.8 2.8 2.0
15297767 LK C AT SHEMYA AFB AK 11/21/1970 11/30/1972 741 2.0 1.0 1.8 1.4
15297773 GALLERY C AT SHEMYA AFB AK 11/22/1970 11/30/1972 740 2.0 1.0 0.9 0.8
Notes:
(a) Gauging at Russell Creek was discontinued on 12/31/1986 and restarted on 10/1/1995.
The short data records for the Adak streams, only 3.6 years and 2.6 years for Sweeper Creek
and Moffett Creek respectively, present a general concern that an average water year may
not be represented. The Russell Creek drainage has data that spans 30 years but is missing
9 years from the period 1987 to 1996. There is about a 7 month overlap between the Russell
Creek data and the Adak gauges. However, comparison of the two data sets over this short
time does not reveal any meaningful comparison regarding year to year variability.
An additional means of identifying adverse water years is through comparing rainfall data with
streamflow measurements. The rainfall data for Adak is shown below.
Table 4 - Rainfall Data
ADAK, ALASKA-500026, Monthly Total Precipitation (inches)
File last updated on Oct 22, 2010
*** Note *** Provisional Data *** After Year/Month 199603
a = 1 day missing, b = 2 days missing, c = 3 days, ..etc..,
z = 26 or more days missing, A = Accumulations present
Long-term means based on columns; thus, the monthly row may not
sum (or average) to the long-term annual value.
MAXIMUM ALLOWABLE NUMBER OF MISSING DAYS : 5
Individual Months not used for annual or monthly statistics if more than 5 days are missing.
Individual Years not used for annual statistics if any month in that year has more than 5 days missing.
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YEAR(S) JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC ANN
1949 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 6.45 7.30 7.93 12.96 34.64
1950 3.95 2.63 3.39 2.54 3.23 1.35a 2.44 6.42 10.04 5.58 2.54 7.65 51.76
1951 7.57 9.23c 4.65c 6.76g 4.20c 2.15b 3.42 3.22 4.22 10.62 8.65 11.63 69.56
1952 5.00a 5.86b 7.43a 2.48a 5.89a 9.38a 3.43 1.89 4.69 9.82 10.51a 2.54 68.92
1953 9.86 7.22 11.08 7.12 6.47 4.48 0.43a 5.78 5.49 6.41 12.92 4.37 81.63
1954 6.01 6.96 7.97a 2.44 16.10 5.62 4.79 4.59 7.75 6.79 6.12 13.78 88.92
1955 17.34 5.88 4.13 4.75 5.45a 3.20 5.11 2.33 4.80a 12.52a 11.66 13.47 90.64
1956 3.92 6.95 11.99 5.01a 6.82a 4.34 4.38 9.52 10.70 3.38a 5.51 9.46 81.98
1957 12.92 4.40 7.02 9.95 6.05 6.79 1.03b 2.71 5.21 7.10 4.68 8.78 76.64
1958 6.71 2.77 8.31 5.24 5.69 3.74 3.07 1.57 7.47 11.22 11.19 9.61 76.59
1959 3.13 7.15 7.38 3.88 5.25 3.80 2.50 4.44 7.44 7.15 7.23 4.62 63.97
1960 4.35 2.79 2.55 2.31 3.29 1.43 3.04 2.98 2.49 5.31 2.94 3.87 37.35
1961 5.74 2.81 2.33 2.26 2.82 2.97 4.86 2.41 4.74 6.85 7.85 4.90 50.54
1962 5.35 6.44 9.63 1.42 1.68 4.07 2.28 3.95 2.71 8.09 6.14 5.34 57.10
1963 5.30 1.97 8.67 3.79 5.98 3.52 2.17 0.00z 4.50 6.10 6.78 10.16 58.94
1964 4.30 6.10 7.10 6.87 1.12 2.50 2.15 3.68 11.30 5.87 7.12 8.65 66.76
1965 4.80 5.67 5.86 10.17 3.05 3.16 3.88 2.39 5.37 6.66 8.18 6.96 66.15
1966 5.71 8.21 2.57 4.43 5.76 1.36 2.16 6.72 3.76 3.02 11.65 6.72 62.07
1967 7.69 5.05 5.65 4.75 0.64 1.61 6.10 5.28 6.01 7.81 9.59 9.64 69.82
1968 8.89 3.75 3.67 4.99 1.34 1.91 2.37 2.49 3.10 4.95 6.65 8.09 52.20
1969 10.28 5.26 4.28 4.19 3.29 2.04 1.22 4.53 6.77 4.20 7.40 4.17 57.63
1970 6.10 3.76 3.39 6.25 1.55 1.92 2.81 4.75 0.00z 7.83 4.81 0.00z 43.17
1971 3.67 2.07 6.92 3.80 2.54 0.00z 3.41 2.25 6.72 5.47 10.62 0.00z 47.47
1972 6.20 2.93 3.43 2.57 3.01 3.02 2.33 3.78 0.00z 8.71 9.12 0.00z 45.10
1973 2.71 0.00z 6.06 0.00z 2.77 2.95 2.74 5.31 7.83 4.60 8.67 8.01 51.65
1974 5.58 3.78 3.76 5.89 5.37 1.63 4.66 7.34 4.57 3.02 9.89 6.71 62.20
1975 4.03 3.84 5.58 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 7.28 6.48 27.21
1976 3.92o 1.07q 3.89 3.34 2.60 1.55 3.56 3.81 4.56 7.49 3.16o 0.00z 30.80
1977 3.56 3.81 4.85 2.91 3.81 2.68 1.98 4.50 0.00z 6.07 4.98 5.87 45.02
1978 0.00z 4.44 3.99 3.93 3.37 3.17 1.84 2.99 0.00z 6.23 0.00z 8.19 38.15
1979 6.75 4.72 5.53 6.64 0.00z 3.04 2.86 0.00z 4.26 10.01 6.06 6.53 56.40
1980 0.00z 0.00z 6.44 4.36 3.53 3.46 1.68 5.34 4.55 5.66 9.21 5.90 50.13
1981 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00
1982 0.00z 0.00z 0.00z 0.00z 0.00z 3.74 4.92 4.53 6.21 4.08 8.34 4.21 36.03
1983 3.65 4.72 3.03 2.23 1.76 1.70a 2.35 3.60 4.74 7.66 7.34 6.59 49.37
1984 4.97 4.27 0.00z 4.55 2.74 1.67 1.76 0.00z 5.35 4.05 0.00z 6.79 36.15
1985 3.43 2.96a 4.77 3.65 3.71 3.37 1.34 0.00z 4.66 0.00z 0.00z 0.00z 27.89
1986 3.38 3.04 4.17 6.00 3.60 2.22 0.71 0.00z 4.74 0.00z 7.74 0.00z 35.60
1987 0.00z 3.96 0.00z 0.00z 1.92 4.88 0.00z 3.31 0.00z 7.47 0.00z 0.00z 21.54
1988 0.00z 2.80 4.66 2.92 4.43 0.00z 3.57 0.00z 0.00z 6.64 6.22 0.00z 31.24
1989 6.22 2.79 2.96 0.00z 2.76 0.00z 1.28 0.00z 7.34 3.30 0.00z 4.30 30.95
1990 6.60 3.62a 6.11 1.97 4.36 0.90 2.47 6.20 5.01 2.58 3.10 0.00z 42.92
1991 11.39 1.75 6.94 3.79 3.55 3.48 2.76 2.93 7.12 4.64 0.00z 5.74 54.09
1992 0.00z 4.91 5.63 1.61 1.58 5.37 0.00z 3.42 6.35 6.92 6.14 7.54 49.47
1993 9.35 5.35 4.91 3.61 2.30 3.17 3.89 7.62 4.84 9.81 7.02 4.46 66.33
1994 5.66 6.31 3.84 1.43 2.69 2.87 2.48k 4.89f 3.76h 5.40k 3.38f 4.81k 22.80
1995 1.41k 4.10i 1.38d 3.54a 1.73i 0.67d 1.71c 3.45a 7.38f 6.32e 2.69 7.00g 19.76
1996 3.57f 3.51f 4.98g 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00z 0.00
1997 to 2010 No Data
MEAN 6.27 4.57 5.43 4.19 3.86 3.09 2.82 4.22 5.78 6.56 7.43 7.28 65.65
S.D. 3.05 1.81 2.34 2.05 2.53 1.66 1.30 1.79 2.01 2.30 2.55 2.80 13.77
SKEW 1.69 0.55 0.81 1.14 2.81 1.52 0.47 0.93 0.99 0.46 0.00 0.71 0.05
MAX 17.34 9.23 11.99 10.17 16.10 9.38 6.10 9.52 11.30 12.52 12.92 13.78 90.64
MIN 2.71 1.75 1.38 1.42 0.64 0.67 0.43 1.57 2.49 2.58 2.54 2.54 37.35
NO YRS 37 40 42 39 41 41 41 36 37 42 38 35 21
The lack of significant overlap between the rainfall data and Russell Creek, Sweeper Creek,
and Moffett Creek prevents using the rainfall record for an evaluation of year to year
variability in the stream flow records. However, a limited comparison can be made on a
monthly basis. There appears to be a low deviation in the observed rainfall and runoff
measurements compared with the long term mean rainfall. Based on this limited comparison
and due to the general lack of data, it is concluded that the measured runoff at Sweeper
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Creek and Moffett Creek are generally representative of long term average runoff quantities
and patterns for the purpose of this analysis.
The two Adak sites, despite being only 4 miles apart, exhibit significantly different runoff
characteristics. The typical annual runoff profile from Moffett Creek has peaks and valleys
inverted from that of Sweeper Creek. During the summer months Moffett Creek has higher
unit runoff than during the winter months. Sweeper Creek is the opposite with higher runoff
rates in the winter than in the summer. Moffett Creek also exhibits a higher amount of unit
runoff overall on an annual basis.
A review of the other USGS gauged drainages along the Aleutian Islands and Alaska
Peninsula exhibit a similar trend with Russell Creek having a significantly higher unit runoff
and all of the remaining sites exhibiting runoff similar to Sweeper Creek. This dichotomy is
illustrated in the following chart.
Figure 3 - USGS Monthly Average Stream Flow Chart
A review of the locations of the drainages indicates that Moffet Creek and Russell Creek have
catchment areas located in relatively high elevations with ridges and valleys whereas the
other drainages are located in relatively flat and open areas. Notwithstanding other factors in
the data sets, it is possible that the higher elevations, ridges, and valleys allow for snow
drifting and accumulation that becomes a significant contributor to runoff in those drainages
during the summer months. And during the winter months it is likely that the high altitude
results in winter precipitation falling as snow and, with lower temperatures, results in reduced
runoff.
The drainages for Mt. Reed Creek and Lake Bonnie Rose both have catchments with ridges
and valleys at higher elevations and therefore the runoff in these basins is expected to be
0.0
2.0
4.0
6.0
8.0
10.0
12.0
123456789101112Average Unit Runoff, cfs/sq miMonth
LIMPET C ON AMCHITKA IS AK
FALLS C ON AMCHITKA IS AK
CLEVENGER C ON AMCHITKA IS AK
BRIDGE C ON AMCHITKA IS AK
WHITE ALICE C ON AMCHITKA IS AK
LK C AT SHEMYA AFB AK
GALLERY C AT SHEMYA AFB AK
RUSSELL C NR COLD BAY AK
MOFFETT C AT ADAK IS AK
SWEEPER C AT ADAK IS AK
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similar to the Moffet Creek drainage. The lower drainage areas of Heart Lake and Lake
Leone are presumed to have runoff rates similar to the Sweeper Creek. And the mid altitude
drainages of Lake De Marie and Lake Betty are expected to exhibit runoff rates that equal the
average of the other two.
The procedure for determining runoff rates for drainages in this analysis was to calculate the
daily average3 unit flow from all years of the record for each of the Adak data sets. This
resulted in two data sets, one for Moffett Creek and one for Sweeper Creek, containing an
average year of daily unit runoff flows. Then, based on the general altitude for the basin, the
unit runoff for each project option was calculated by combining the Moffett Creek and
Sweeper Creek data sets appropriately and scaling by the appropriate basin area. The values
to derive daily flows for each of the projects options are shown below.
Table 5 - Project Stream Flow Derivation
Source Daily Unit Flow Basin Area (sq
mi)
Tributary Flow
Lake Bonnie Rose 25%*Sweeper Creek Average +
75%*Moffett Creek Average 1.55
Lake De Marie 50%*Sweeper Creek Average +
50%*Moffett Creek Average 2.04 (3.59 - 1.55) Lake Bonnie Rose
Heart Lake 100%*Sweeper Creek Average +
0%*Moffett Creek Average 0.59 (4.18 - 3.59) Lake De Marie
Lake Betty 50%*Sweeper Creek Average +
50%*Moffett Creek Average 4.43
Mt Reed 25%*Sweeper Creek Median +
75%*Moffett Creek Median 2.39
Moffett 0%*Sweeper Creek Median +
100%*Moffett Creek Median 2.78
The following table is the resulting monthly average flow for each of the project intake
locations.
Table 6 - Derived Monthly Average Stream Flows (cfs) for Each Project Location
Month Lake Bonnie
Rose
Lake De
Marie
Heart Lake Lake Betty Mt Reed Moffet
1 6.7 15.9 18.7 20.0 8.8 10.3
2 7.5 18.3 21.9 23.4 10.3 11.2
3 5.8 13.5 15.8 16.8 7.8 9.3
4 5.7 13.2 15.4 16.4 8.2 10.0
5 6.8 14.1 15.3 15.9 10.4 14.5
6 12.6 24.7 25.6 26.3 19.3 28.7
7 14.0 28.1 29.6 30.5 21.3 31.2
8 9.4 19.8 21.7 22.7 13.8 19.4
9 10.4 22.2 24.6 25.8 15.4 21.0
10 10.8 24.0 27.3 28.8 14.8 18.9
11 9.2 20.8 23.8 25.1 13.4 16.7
12 7.3 16.9 19.6 20.7 10.3 12.4
Average 8.8 19.3 21.6 22.7 12.8 17.0
3 The average unit flow is appropriate if storage is utilized whereas for the run-of-river projects on Moffett
Creek and Mt Reed Creek the median flow is used.
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9. Project Options and Initial Evaluation
Initial analysis found about 13 individual hydroelectric project configurations near Adak. A
simple approach to comparing these individual options was adopted to identify the options
with the best potential for development. The following discussion presents this approach. Not
included in this analysis is the multitude of options possible when the individual projects are
combined. Current loads appear to have dropped enough from historic levels such that a
single hydroelectric development should meet the majority of demand. The table below
summarizes the results of the initial project identification and assessment.
Table 7 - Project Options and Analysis Matrix
No Source Elev Powerhouse
Location Elev Design
Flow
Penstock
Length Dia Net
Head Power Electric
Length
Cost
Score
Energy
Score
Environ
Score
Avg
Score
ft ft cfs ft in ft kW ft 1 to 5 1 to 5 1 to 5 1 to 5
1 Lake Bonnie Rose 739 Lake DeMarie 249 10.6 5,270 16 445 320 2,500 2.3 3.2 3.5 3.0
2 Lake Bonnie Rose 739 Ocean 25 10.6 9,765 16 632 450 0 1.6 4.9 2.8 3.1
3 Lake Bonnie Rose 739 Ocean 25 10.6 15,032 18 644 460 7,500 0.0 5.0 2.0 2.3
4 Lake Bonnie Rose 739 Heart Lake 168 10.6 13,862 18 506 360 5,000 0.5 3.7 2.5 2.2
5 Lake DeMarie 234 Heart Lake 168 23.1 2,408 24 54 80 5,500 2.8 0.0 3.5 2.1
6 Lake DeMarie 234 Ocean 25 23.1 7,519 26 183 280 7,500 0.5 2.6 2.0 1.7
7 Lake Betty 159 Lake Betty PH 30 27.2 1,335 22 114 210 17,500 2.2 1.7 3.8 2.6
8 Lake Bonnie Rose 739 Exist PRV 315 3.5 0 10.6 364 90 0 5.0 0.9 4.5 3.5
9 Lake Bonnie Rose 739 Exist PRV 315 10.6 8,196 18 385 270 0 1.9 2.5 4.0 2.8
10 Lake Bonnie Rose 739 Mitt Lake 60 10.6 7,263 16 618 440 850 1.9 4.7 3.5 3.4
11 Heart Lake 153 Ocean 25 25.9 3,650 26 112 190 7,500 1.9 1.4 2.0 1.8
12 Mt Reed 400 Ocean 25 15.4 2,543 18 350 360 12,000 2.1 3.7 1.3 2.4
13 Moffet 400 Ocean 25 20.4 10,017 24 334 450 0 0.2 4.9 4.0 3.0
Scores shown in the table are ranked using a low number to representative a negative or
detrimental aspect (such as high cost) and a high number to represent a positive aspect
(such as high energy output or low environmental impact).
Some of the projects utilize the same source and destination elevation but have different
pipeline routes and powerhouse locations. It is expected that many of the above options
would prove feasibly impractical. Due to the desktop level of analysis and the number and
complexity of issues, particularly the uncertainty related to environmental flows and aquatic
resources, other water uses, and electrical demand, all of the options that are possible have
been retained in this report for reference purposes in future feasibility efforts.
The initial analysis presented above does not include storage or useable energy (demand
constrained) considerations. The design flow for each configuration, except option 8 using the
existing pipeline, is selected as the average annual flow, as calculated previously for each
basin, times 120%. The total annual energy production is based on the design flow times a
capacity factor. The estimated capacity factor for option 8 is 100% while the other options use
a 60% capacity determined from energy analysis using the estimated daily hydrology data.
Actual useful capacity factors will be dictated by system load, local hydrology, water system
demands, bulk water sales (if any), environmental bypass flows, and storage capability.
Transmission lengths were determined by the shortest distance from the powerhouse location
to the nearest building group.
At this stage in the analysis the results are considered relatively accurate and should only be
used for comparison among projects in this study and as a basis for future planning and
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analysis efforts. A project scoring system was developed for assessing and ranking each
project based on cost, energy produced, and environmental attributes. The environmental
factors assigned are based on estimated impacts to aquatic issues and the physical footprint
of the project.
Scoring of cost is derived by calculating a cost factor that is based on the pipeline diameter,
length, and transmission length. The project with the lowest cost factor has the highest score
whereas the highest cost project has the lowest score. Similar to the cost scoring, the ranking
of energy is derived by scoring the project with the highest energy output a 5 and the project
with the lowest output a 0. Environmental scores are based on a qualitative evaluation of the
amount of bypassed reach, the percentage of bypassed flows (excludes consideration of
existing water use flows), and the amount of new trail required for the pipeline and
transmission lengths combined.
The results show that two developments rank the highest:
Option 10, 440 kW Mitt Lake Project - Constructing a storage project utilizing the existing
dam at Lake Bonnie Rose for the intake and locating a powerhouse on Mitt Lake.
Option 8, 85 kW Exist PRV Project - Utilizing the existing 10" DIP water system pipeline
and installing a turbine near the water treatment plant.
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10. Lake Bonnie Rose to Mitt Lake Project Analysis
10.1 Description
Option 10 (Mitt Lake Project), the configuration with an intake at Lake Bonnie Rose and a
powerhouse at Mitt Lake, with more capacity and higher energy output, appears to be the
most feasible option for meeting a majority of energy generation needs economically at this
stage of analysis. Option 10 could also be configured as a storage project and is analyzed in
more detail in this section.
The Mitt Lake Project would utilize a combination of HDPE and steel or ductile iron pipe with
a total length nearly the same as that for the existing PRV-1 location. The project is modeled
with the following parameters:
Peak Flow 10.6 cfs Operating Head 613 ft
Head water elevation 739 ft Lake area 139 acre-ft
turbine centerline elevation 60 ft Active Storage 3 ft
static head 679 ft Storage 418 acre-ft
Penstock Length 7,300 ft Eff 0.8
Penstock Diameter 16 in Power 440
kW
Annual Energy Potential 3,209,499 kWh
The hydrograph and flow duration curve for Lake Bonnie Rose with the power potential of
Option 10 (excluding other water uses) is shown in the figures below.
Figure 4 - Lake Bonnie Rose Hydrograph
0
200
400
600
800
1000
1200
0
5
10
15
20
25
30
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Power Potential (kW)Stream Flow (cfs)Date
Lake Bonnie Rose Hydrograph and Power Potential
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Figure 5 - Lake Bonnie Rose Flow Duration Curve
10.2 Analysis
The detailed analysis includes consideration of storage and the ability to meet the energy
needs of the synthesized hourly demand. The estimated useable storage for the lake is the
surface area times a depth of 3 feet. Also included in the analysis are options for supplying
the 0.5 cfs of potable water, 0.8 cfs for export, and the monthly environmental flows. Storage
in the reservoir is not included when considering environmental flows.
The analysis of the performance using the hourly demand data and storage is an
approximation that does not include varying efficiency, headloss, minimum diesel run time, or
ice and snow effects on storage. For this level of study, the results are generally adequate to
test the viability of the concept and assist future feasibility efforts. The charts below shows the
results of the Mitt Lake Project operational model with the combined town and processor load
and with and without existing environmental water uses.
0
200
400
600
800
1000
1200
0
5
10
15
20
25
30
0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100%Option 10 Potential Power (kW)Lake Bonnie Rose Inflow (cfs)% Time Exceeded
Lake Bonnie Rose Flow Duration Chart
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Figure 6 - Mitt Lake Project Operation Chart without Environmental Flow Restrictions
Figure 7 - Mitt Lake Project Operation Chart with Environmental Flow Restrictions
735
735
736
736
737
737
738
738
739
739
740
0
100
200
300
400
500
600
700
800
1/1 2/1 3/1 4/1 5/1 6/1 7/1 8/1 9/1 10/1 11/1 12/1 Reservoir Elevation (ft)Power (kW)Date
Mitt Lake Project Operation
Avg Diesel Generation
Avg Hydro Generation
Resvoir Level
0
100
200
300
400
500
600
700
800
0
100
200
300
400
500
600
700
800
1/1 2/1 3/1 4/1 5/1 6/1 7/1 8/1 9/1 10/1 11/1 12/1 Reservoir Elevation (ft)Power (kW)Date
Mitt Lake Project Operation
Avg Diesel Generation
Avg Hydro Generation
Resvoir Level
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10.3 Cost Estimate
The opinion of construction cost (cost estimate) was prepared using cost estimates for other
projects and general cost knowledge. This first stage of analysis lacks conceptual designs, a
schedule, site visit, surveys, and other investigations that can significantly impact cost.
The estimated construction effort spans a period of about 8 months with 5.5 months on
location in Adak. The construction support includes housing and per diem at a unit cost $150
per day (the low cost is based on excess housing availability in Adak). Also included are
costs for air travel every other week (13 trips) at a rate of $15,000 per trip. Mobilization is
based on a presumed rate of $350,000 per trip for a vessel making two round trips from
Seattle.
The cost estimate for the modifications to the existing dam includes 50 cubic yards of
concrete, valves, screens, controls, and a power and communications line from the
powerhouse that would follow the pipeline alignment. The pipeline cost estimate includes
4,600 feet of HDPE and 2,650 of steel or ductile iron pipe. Miscellaneous fittings and anchor
blocks are included as well. Access trails are included in the cost estimate based on a
presumed length of 5,000' and a shot rock material volume of 1 cyd per foot of trail at a cost
of $50/cyd.
The turbine and generator costs include $500k for the turbine and generator and another
$250k for controls, switchgear, and transformer.
Equipment budgeted for the project includes a fusion machine, concrete mix truck, two
excavators, an end dump, loader, generators, 2 light trucks, and a track drill with compressor
all rented for 8 months. Also included is 20,000 gallons of fuel at an estimated retail cost of $7
per gallon (included under materials category of equipment).
Due to the preliminary status of the project analysis and cost estimate a 25% contingency is
added to the construction cost. A summary of the preliminary opinion of the development cost
for the Mitt Lake Project is provided in the table below.
TDX Power - Adak Reconnaissance Study
Final Report
Prepared by Hatch, 2/16/2013
H343115-0000-00-236-0001, Rev. 1
Page 24
Table 8 - Mitt Lake Project Cost Estimate
Item Labor Labor Cost Equip Cost Material
Cost
Ship Cost Total Cost
Construction Support 3,390 $ 322,000 $ 344,000 $ 670,000
Mobilization $ 700,000 $ 700,000
Powerhouse 1,620 $ 132,000 $ 350,000 $ 480,000
Intake 1,800 $ 142,000 $ 82,000 $ 220,000
Pipeline 2,400 $ 190,000 $ 334,000 $ 520,000
Access Trails 1,320 $ 101,000 $ 275,000 $ 380,000
Turbine And Generator 540 $ 51,000 $ 750,000 $ 800,000
Transmission 360 $ 29,000 $ 20,000 $ 50,000
Equipment $ 513,000 $ 140,000 $ 650,000
SUBTOTAL, Direct Costs 11,400 $ 968,000 $ 513,000 $ 1,950,000 $ 1,044,000 $ 4,470,000
Weather delay (% of Labor and Equip) 10% $ 150,000
Contingency 25% $ 1,120,000
Contractor profit 15% $ 670,000
SUBTOTAL, Construction $ 6,410,000
SUBTOTAL, Construction $ 6,410,000
Construction interest $ 140,000
Engineering 12% $ 800,000
Inspection and testing 4% $ 250,000
Owner admin 6% $ 400,000
TOTAL PROJECT $ 8,010,000
10.4 Economic Value
The results indicate that storage has some value. The most significant consideration however
is the amount of water available for hydropower. The instream flow requirements significantly
affect the economics of the Mitt Lake Project and all of the diversion projects using water from
the lake system.
The tables below show the energy distribution with the hydroelectric project as part of the
generation system and the estimated annual fuel savings with the various water use options.
Table 9 is for the "town only" demand while Table 10 is for the combined "town and
processor" demand. The estimated cost of diesel fuel in Adak is $5.00 per gallon.
TDX Power - Adak Reconnaissance Study
Final Report
Prepared by Hatch, 2/16/2013
H343115-0000-00-236-0001, Rev. 1
Page 25
Table 9 - Mitt Lake Project Performance Summary (Town load only)
Town Load Only
Parameter No Competing
Water Use
Potable Water
Use Added
Water Export
Added
Environmental
Flows Added
Units
Annual Energy Demand 2,000,000 2,000,000 2,000,000 2,000,000 kWh
Demand Met by Hydro 2,000,000 2,000,000 2,000,000 780,000 kWh
Demand Met by Diesel 0 0 0 1,230,000 kWh
Current Diesel Use 142,857 142,857 142,857 142,857 gal
Diesel Use with Hydro 0 0 0 87,900 gal
Annual Fuel Savings (gal) 142,857 142,857 142,857 54,957 gal
Annual Fuel Savings ($) $714,286 $714,286 $714,286 $274,786
Net Present Value $14,000,000 $14,000,000 $14,000,000 $5,400,000
Benefit / Cost Ratio (B/C) 1.7 1.7 1.7 0.7
Table 10 - Mitt Lake Project Performance Summary (Town and Processor load)
Town and Processor Load
Parameter No Competing
Water Use
Potable Water
Use Added
Water Export
Added
Environmental
Flows Added
Units
Annual Energy Demand 3,310,000 3,310,000 3,310,000 3,310,000 kWh
Demand Met by Hydro 2,880,000 2,700,000 2,520,000 910,000 kWh
Demand Met by Diesel 440,000 630,000 810,000 2,400,000 kWh
Current Diesel Use 236,429 236,429 236,429 236,429 gal
Diesel Use with Hydro 31,400 45,000 57,900 171,400 gal
Annual Fuel Savings (gal) 205,029 191,429 178,529 65,029 gal
Annual Fuel Savings ($) $1,025,143 $957,143 $892,643 $325,143
Net Present Value $20,100,000 $18,800,000 $17,500,000 $6,400,000
Benefit / Cost Ratio (B/C) 2.5 2.3 2.2 0.8
From the tables it can be seen that, with the processor load added, the water export
operation has some impact on the economics. However, with proper timing, use of additional
sources and storage, the overall impact could be negligible. The environmental flow
requirements are significant enough that it appears the export operation may be curtailed at
times. The environmental flow restrictions reduce the value of the hydro by about $600,000
annually with the processor load considered. This equates to a net a present cost of
preserving resident fish at about $11.7 million over 30 years.
TDX Power - Adak Reconnaissance Study
Final Report
Prepared by Hatch, 2/16/2013
H343115-0000-00-236-0001, Rev. 1
Page 26
11. Existing PRV Project
The Existing PRV project utilizes the existing raw water transmission pipeline from Lake
Bonnie Rose to the water treatment plant. The pipeline is reported to be a 10" DIP. A
standard wall thickness is assumed resulting in an internal diameter of 10.6". A hydraulic
capacity of 3.5 cfs is selected for this option which results in a relatively high frictional loss but
the turbine is not expected to operate over a wide range flows. The water available for power
is reduced to 3 cfs when including the potable water needs of 0.5 cfs.
This project is limited in the amount of power output due to the existing pipeline. It is sized to
the practical maximum which varies from about 75 kW to 90 depending on the domestic
water needs. This consideration must be taken into account when comparing with the Mitt
Lake project size which is fairly flexible. It can be expected that the Mitt Lake project size, and
economics, will be optimized with further feasibility analysis.
The output of this project is lower than the towns demand and would require continuous
diesel operation throughout the year. Since the operational model for this report did not
include diesel engine maintenance, overhauls, and replacement costs the economical
comparison to the Mitt Lake project is not entirely accurate. The Mitt Lake project will result in
additional cost savings that is not accounted for in this analysis.
A preliminary estimate of construction cost was prepared for the Existing PRV project using
the cost estimate from the Mitt Lake project and is shown in the table below. The pipeline cost
is zero in the estimate but a more appropriate comparison with the Mitt Lake project would
consider the age of the existing pipeline and the remaining service life and replacement cost.
Table 11 - Existing PRV Cost Estimate
Item Labor Labor Cost Equip Materials t Shipping Total Cost
Construction Support 450 $ 43,000 $ 135,000 $ 180,000
Mobilization $ 300,000 $ 300,000
Powerhouse 1,080 $ 88,000 $ 250,000 $ 340,000
Intake 600 $ 47,000 $ 59,000 $ 110,000
Pipeline
Access Trails 660 $ 51,000 $ 100,000 $ 150,000
Turbine And Generator 540 $ 51,000 $ 345,000 $ 430,000
Transmission
Equipment $ 66,000 $ 18,000 $ 80,000
SUBTOTAL, Direct Costs 3,300 $ 280,000 $ 66,000 $ 804,000 $ 435,000 $ 1,590,000
Weather delay (% of Labor and Equip) 10% $ 30,000
Contingency 25% $ 400,000
Contractor profit 15% $ 240,000
SUBTOTAL, Construction $ 2,250,000
SUBTOTAL, Construction $ 2,250,000
Construction interest $ 50,000
Engineering 13% $ 300,000
Inspection and testing 2% $ 50,000
Owner admin 4% $ 100,000
TOTAL PROJECT $ 2,750,000
The potential energy and economic benefit of the Existing PRV project has also been
analyzed using the same model developed for the Mitt Lake project. As with the Mitt Lake
TDX Power - Adak Reconnaissance Study
Final Report
Prepared by Hatch, 2/16/2013
H343115-0000-00-236-0001, Rev. 1
Page 27
project, reservoir storage is assumed to be zero when including environmental flows. The
results are shown in the table below for the town load only.
Table 12 - Existing PRV Project Performance Summary (Town load only)
Town Load Only
Parameter No Competing
Water Use
Potable Water
Use Added
Water Export
Added
Environmental
Flows Added
Units
Annual Energy Demand 2,000,000 2,000,000 2,000,000 2,000,000 kWh
Demand Met by Hydro 760,000 650,000 650,000 330,000 kWh
Demand Met by Diesel 1,240,000 1,350,000 1,350,000 1,660,000 kWh
Current Diesel Use 142,857 142,857 142,857 142,857 gal
Diesel Use with Hydro 88,600 96,400 96,400 118,600 gal
Annual Fuel Savings (gal) 54,257 46,457 46,457 24,257 gal
Annual Fuel Savings ($) $271,286 $232,286 $232,286 $121,286
Net Present Value $5,300,000 $4,600,000 $4,600,000 $2,400,000
Benefit / Cost Ratio (B/C) 2.1 1.9 1.9 1.0
The resulting benefit to cost ratios are somewhat similar to the Mitt Lake project. However,
the overall value of the Exist PRV project is much lower with a Net Present Value (NPV) of
$4.6 million compared with the NPV of $14 to $18.8 million for the Mitt Lake project. Even
when including environmental flows, the NPV of the larger Mitt Lake is more than double that
of the Existing PRV project.
It is premature to recommend a proposed develop until further feasibility efforts are
undertaken to optimize project sizing and efforts are made to reduce the environmental flows.
However, considering that the life of a hydropower project is much longer than the economic
term adopted in this report the most favourable development would be an appropriately sized
Mitt Lake project even when considering environmental flow restrictions which are subject to
change.
TDX Power - Adak Reconnaissance Study
Final Report
Prepared by Hatch, 2/16/2013
H343115-0000-00-236-0001, Rev. 1
Page 28
12. Recommendations
The preliminary analysis indicates that a hydroelectric project in Adak is economically viable
without the environmental flow restrictions. The environmental flow restrictions significantly
impact the hydro potential but it is worth pursuing development efforts and to try to reduce or
eliminate the restrictions given the low value of the resident fresh water species and the high
value of the use of water for power production.
Additional consideration of many issues and more thorough feasibility analysis is necessary
to determine the best development scenario. Additional feasibility study is warranted to collect
site specific data, initiate permitting actions, and refine the analysis to determine
recommended project(s), storage potential, conceptual designs, and costs.
Recommendations include:
Obtain current satellite image and perform a satellite photogrammetric or LIDAR survey
over the entire project area (from Moffet drainage south to the Aleutian Wilderness
boundary).
Monitor and log 15 minute demand data to determine daily load fluctuations. Also log
hourly or daily demand with peaks over a longer period.
Coordinate conceptual designs and development efforts with the water system and bulk
sales.
Install and maintain stream gauges in Adak for a minimum of one to three years. At a
minimum one should be placed at the outlet of Lake Bonnie Rose.
Initiate the additional permitting and mitigation for the removal of instream flow
restrictions and allow for the diversion of water.
Perform feasibility level studies to further evaluate issues related to aquatic habitat,
incorporate stream gauge work into the hydrology analysis, and develop more detailed
project cost estimates, size, and storage recommendations, and conceptual designs.
Investigate future load growth (or decline), fish processor loads, and further evaluate
demand requirements.
TDX Power - Adak Reconnaissance Study
Final Report
Prepared by Hatch, 2/16/2013
H343115-0000-00-236-0001, Rev. 1
Page 29
13. References
Alaska Department of Commerce, Community, and Economic Development, Division of
Community & Regional Affairs. Alaska Community Database Community Information
Summaries (CIS). http://www.commerce.state.ak.us/dca/commdb/CF_CIS.htm.
Alaska Journal of Commerce. Wesley Loy. Aleut Corp wants to export Adak Water.
http://www.alaskajournal.com/stories/082010/loc_adw.shtml.
Bristol Environmental & Engineering Services Corporation. Adak Water and Sewer
Improvements. Prepared for City of Adak. July, 2010.
HDR Inc. Adak Island Lakes Draft Fisheries Field Report, August 2011.
Peratrovich, Nottingham & Drage, Inc. Adak Lake Surveys. December 2010.
URS Corp and US Navy, 2009. Environmental cleanup and closure of the former Naval Air
Facility, Adak, Alaska. Website: http://www.adakupdate.com/
Waythomas, Christopher F., 1995. Surficial Geologic Map of Northern Adak Island, Alaska.
U.S. Geological Survey Open-File Report 95-1 28.
http://www.dggs.dnr.state.ak.us/pubs/quad/adak.
WHPacific. Safety Inspection Report, Lake Bonnie Rose Dam, Adak, Alaska, NID ID No. AK
00108. Prepared for City of Adak. April 03, 2012.
WHPacific. Safety Inspection Report, Lake De Marie Dam, Adak, Alaska, NID ID No. AK
00123. Prepared for City of Adak. April 03, 2012.
1225 East International Airport Rd., Suite 110
Anchorage, AK, USA 99518
Tel (907) 561 2800 Fax (907) 561 2802
McMillen Sept. 2013 report
2022 Adak Petroleum invoice
Canyon Hydro Quote
November 28, 2022
Loren A. Jalbert
TDX Power Services, LLC
208-375-5323
ljalbert@tdxpowerservices.com
Dear Mr. Jalbert,
Thank you for contacting Canyon Hydro regarding the site evaluation requirements at Adak. As always,
we welcome the opportunity to offer our expert assistance as listed below.
• (1) Travel to the Adak site (Tuesday/Wednesday)
• (1) Review site and note potential hydro options (Thursday/Friday)
• (1) Travel from the Adak site (Saturday/Sunday)
• (1) Airfare to and from Adak
• (2) Hotel nights in Anchorage
• (1) Lot meals and ground travel
• We understand lodging and transportation will be provided in Adak
Estimated price for the field services listed above……………………………………..................$15,650.00
Our normal terms are 50% payment prior to departure and 50% due upon return from the visit. We will
waive this requirement if the City of Adak provides a purchase order to Canyon. If a PO is not an
option, we will send an invoice for $7,825.00. Balance to be determined by actual time spent and travel
costs.
Our proposed engineer is Mike Maloney. Please find attached Mike’s resume. He is our electrical
engineer and has a great deal of experience with evaluating hydroelectric sites. Mike’s experience will
be used to prepare a report based on the findings noted during his visit.
I welcome questions you may have regarding our proposed services.
Sincerely,
Eric Melander
Vice President of Sales
General Provisions for Field Service
Effective January 1, 2022
Field Service Rates
Technician $1,400 per day (based on 8 hour work day)
Overtime/weekends $200 per hour
Engineer or Executive $2,000 per day (based on 8 hour work day)
Overtime/weekends $285 per hour
Transportation
Personal or Corporate automobile mileage charged at $0.625/mile.
Air, rail, rental car, etc. will be charged at cost plus 15% processing charge.
Lodging & Meals
Charged at cost plus 15% processing charge.
Travel
Travel time will be billed at the straight time hourly rate Mondays through Fridays
and at the weekend rate for Saturdays, Sundays, and Holidays.
General Provisions
Standby Time
Any waiting time when the Representative is available to work, up to a maximum
of eight (8) hours on any one working day, shall be regarded as time actually
worked, even though the services are not actually utilized. The rate may not be
prorated for partial days.
Delays
Canyon Industries, Inc. shall not be liable for delay in performance when such
delay is occasioned by causes beyond its reasonable control, including but not
limited to acts of God, acts of the customer, material shortages, transportation
difficulties, flood, strikes, epidemics, war (declared or undeclared), riot, etc.
Emergency Work
The minimum time off for a representative during any 24 hour period must be
eight (8) consecutive hours.
Terms of Payment
A deposit equal to 50% of anticipated charges due upon request for a field
representative. Payment for services and material will be due upon presentation
of invoices.
Rates subject to change without notice.
B/C Ratio file - 440 kW Hydroelectric Turbine
*see attached Excel file
B/C Ratio file - 100 kW Hydroelectric Turbine
*see attached Excel file