HomeMy WebLinkAboutAPA569s
TK
1425
.58
A23
no.569
Existing Generating Facilities
And Planned Additions for the
Railbelt Region of Alaska
Volume VI
September 1982
Prepared for the Office of the Governor
State of Alaska
Division of Policy Development and Planning
and the Governor's Policy Review Committee
under Contract 2311204417
()Battelle
Pacific Northwest Laboratories
LEGAL .NOTICE
This report was· prepared by Battelle as an account of sponsored
research activities. Neither Sponsor 110r Battelle nor any person acting
on behalf of either:
MAKES ANY WARRANTY OR REPRESENTATION, EXPRESS OR
IMPLIED, with respect to the accuracy, completeness, or usefulness of
the information contained in this report, or that the use of any informa-
tion, apparatus, process, or composition disclosed in this report may not
infringe privately owned rights; or
Assumes any liabilities with respect to the use of, or for damages result-
ing from the use of, any information, apparatus, process, or, composition
disclosed in this report.
JAN 1 4 1M1
ALASKA RESOURCES LIBR-ARY
U.S. DEPT. OF INTERIOR
EXISTING GENERATING FACILITIES
AND PLANNED ADDITIONS FOR
THE RAILBELT REGION OF ALASKA
Volume VI
September 1982
Prepared for the Office of the Governor
State of Alaska
Division of Policy Development and Planning
and the Governor's Policy Review Committee
·under Contract 2311204417
BATIELLE
Pacific Northwest Laboratories
Rich 1 a.nd, Washington 99352
PREFACE
The State of Alaska commissioned Battelle to investigate potential
strategies for future electric power development in Alaska's Railbelt region.
The results of the study will be used by the Office of the Governor to
formulate recommendations for electric power development in the Railbelt.
The primary objective of the study is to develop and analyze several
alternative long-range plans for electric energy development in the Railbelt
region. Each plan is based on a general energy development strategy
representing one or more policies that Alaska may wish to pursue. The
analyses of the plans will produce forecasts of electric energy demand,
schedules for developing generation and conservation alternatives, estimates
of the cost of power, and discussions of the environmental and socioeconomic
characteristics for each plan.
This report (Volume VI of a series of seventeen volumes, listed below)
describes electric generating facilities currently existing and scheduled to
be added in the Railbelt region. Several sources were used to develop the
lists of current generating facilities presented in this report. In most
cases, the utilities themselves furnished the data on the number of units and
their nameplate capacities. Other information, such as the retirement date,
forced ou~age rate, and maximum capacity factor, was assumed on the basis of
national operating statistics.
,; Volume I
RAILBELT ELECTRIC POWER ALTERNATIVES STUDY
-Railbelt Electric Power Alternatives Study: Evaluation of
Railbelt Electric Energy Plans
Volume II -Selection of Electric Energy-Generation Alternatives for
Consideration in Railbelt Electric Energy Plans
Volume III -Executive Summary -Candidate Electric Energy Technologies for
Future Application in the Railbelt Region of Alaska
Volume IV -Candidate Electric Energy Technologies for Future Application
in the Railbelt Region of Alaska
J Volume V -Preliminary Railbelt Electric Energy Plans
iii
Volume VI
~ Volume·VII
-Existing Generating Facilities and Planned Additions for the
Railbelt Region of Alaska
-Fossil Fuel Availability and Price Forecasts for the Railbelt
Region of Alaska
J Volume VIII -Railbelt Electricity Demand (RED) Model Specifications
Volume IX -Alaska Economic Projections for Estimating Electricity
Requirements for the Railbelt
Volume X -Community Meeting Public Input for the Railbelt Electric Power
Alternatives Study
Volume XI -Over/Under (AREEP Version) Model User's Manual
Volume XII -Coal-Fired Steam-Electric Power Plant Alternatives for the
Railbelt Region of Alaska
Volume XIII -Natural Gas-Fired Combined-Cycle Power Plant Alternative for
the Railbelt Region of Alaska
Volume XIV -Chakachamna Hydroelectric Alternative for the Railbelt Region
of Alaska
Volume XV -Browne Hydroelectric Alternative for the Railbelt Region of
Alaska
Volume XVI -Wind Energy Alternative for the Railbelt Region of Alaska
Volume XVII -Coal-Gasification Combined-Cycle Power Plant Alternative for
the Railbelt Region of Alaska
iv
SUMMARY
The total nameplate generating capacity for each of the Railbelt
utilities by type of generating capacity is presented in Table S.1. As shown
in this table, the Anchorage-Cook Inlet area had a total of 621.5 MW of
capacity, and the Glennallen-Valdez area had 303.65 MW of capacity in 1980.
Of the total 944.05 MW capacity,_the majority is simple-cycle combustion
turbine (520.45 MW or 55%). The relative mix of technologies is shown in
Figure S.l. The total nameplate generating capacity for the military
installations is surnnarized in Table S.2.
v
TABLE S .1. Total Nameplate Generating Capacity-Railbelt Utilities (1980) -MW
CCCT(a) Diesel Hydro RCCT SCCT ST Total
Anchorage -Cook Inlet Area
' Alaska Power Administration 0 0 30 0 0 0 30
Anchorage Municipal Light and Power 139 0 0 0 74.5 0 213.50
Chugac~ Electric Association 0 0 16 111 244 0 371.50
Homer Electric Association 0 1.5 0 0 0 0 1.5
Matanuska Electric Association 0 0 0 0 0 0 0
Seward Electric System 0 5.5 0 0 0 0 5.5
Subtota 1 139 7 .o 46 111 318.5 0 621.5
Fairbanks -Tenana Valley Area
Fairbanks Municipal Utilities System 0 8.25 0 0 28.35 29.0 65.6
Golden Valley Electric Association 0 23.75 0 0 170.80 25.0 219.55
University of Alaska -Fairbanks 0 5.50 0 0 0 13.0 18.50
< Subtotal 0 37.50 0 0 199.15 67.0 303.65 .....
Glenna 11 en -Valdez Area
Copper Valley Electric Association 0 16.10 0 0 2.8 0 18.9 ---
TOTAL 139 60.6 46 111 520.45 67.0 . 944.05
(a) CCCT -Combined-Cycle Combustion Turbine
Diesel -Diesel Cycle
Hydro -Hydraulic Turbine
RCCT -Regenerative Cycle Combustion Turbine
SCCT -Simple Cycle Combustion Turbine
ST -Steam Turbine
HYDRO
146MW-5%l
SIMPLE CYCLE
COMBUST! ON TURBINE
I520MW -55%)
FIGURE S.l. Relative Mix of Electrical Generating Technology -
Railbelt Utilities -1980
vii
< ..... ..... .....
TABLE S.2. Total Nameplate Generating Capacity -Railbelt Military Installations
CCCT (a) Diesel
Anchorage -Cook Inlet Area
Elmendorf AFB 0 2.1
Fort Richardson 0 7.2
Subtotal 0 9.3
Fairbanks -Tenana Valley Area
Ei e 1 son AFB 0 0
Fort Greeley 0 5.5
Fort Wainwright 0 0
Subtotal 0 5.5 --
TOTAL 0 14.8
(a) CCCT -Combined-Cycle Combustion Turbine
Diesel -Diesel Cycle
Hydro -Hydraulic Turbine
RCCT -Regenerative Cycle Combu~tion Turbine
SCCT -Simple Cycle Combustion Turbine
ST -Steam Turbine
Hydro RCCT SCCT ST
0 0 0 31.5
0 0 0 18.0
0 0 0 49.5
0 0 0 8.75
0 0 0 0
0 0 0 22.0
0 0 0 30.75 --
0 0 0 80.25
(1980) -MW
Total
33.6
25.2
58.8
8.74
5.5
22.0
36.25
95.05
1.0 INTRODUCTION
The Railbelt area currently consists of three noninterconnected load
centers; the Anchorage-Cook Inlet area, the Fairbanks-Tenana Valley area, and
the Glennallen-Valdez area.(a) In the Anchorage-Cook Inlet and Fairbanks-
Tenana Valley areas several utilities and military installations are
interconnected. The Glennallen-Valdez area has only a single utility, the
Copper River Electric Association, Inc. The utilities and military
installations for which data are included in this report are shown below:
Anchorage-Cook Inlet Area
Utilities
Alaska Power Administration
Anchorage Municipal Light and Power
Chugach Electric Association, Inc.
Homer Electric Association, Inc.
Matanuska Electric Association, Inc.
Military Installations
Elmendorf AFB
Fort Richardson
Fairbanks-Tenana Valley Area
Utilities
Fairbanks Municipal Utilities System
Golden Valley Electric Association, Inc.
University of Alaska-Fairbanks
Military Installations(b)
Eielson AFB
Fort Greeley
Fort Wainwright
(a) Glennallen and Valdez were scheduled to be interconnected in 1981 and are
considered as a single load center for the purpose of this analysis.
(b) Clear Air Force Station generates its own power but is not connected to
the other systems. Due to the mission of this station, future connection
is not anticipated.
1.1
Glennallen-Valdez Area
Utility
Copper Valley Electric Association, Inc.
Industries having their own generating facilities were not considered in
this analysis since they typically do not market power.
1.2
2.0 EXISTING GENERATING FACILITIES AND PLANNED ADDITIONS FOR THE RAILBELT AREA
As mentioned earlier, the Railbelt area has three noninterconnected load
centers: the Anchorage-Cook Inlet Area, the Fairbanks-Tenana Valley area; and
the Glennallen-Valdez area. In the following section, the existing generating
facilities and planned additions for each of these areas are presented and
briefly discussed.
2.1 ANCHORAGE-COOK INLET AREA
The Anchorage-Cook Inlet area has three rural electric cooperative
associations (REAs), two municipal utilities, a Federal Power Administration,
and two military installations. They are listed below:
Alaska Power Administration (APA) -U.S. Department of Energy
Anchorage Municipal Light and Power (AML&P) -Municipal Utility
Chugach Electric Association (CEA), Inc. -REA
Homer Electric Association (HEA), Inc. -REA
Matanuska Electric Association (MEA), Inc. -REA
Seward Electric System (SES) -Municipal Utility
Elmendorf AFB -Military
Fort Richardson -Military
All of these organizations, with the exception of MEA, have electrical
generating facilities. MEA buys its power from the Chugach Electric
Association. HEA and SES have relatively small generating facilities that are
used for standby operation only. They also purchase their power during normal
operations from the Chugach Electric Association. Total nameplate generating
capacity for these utilities is presented in Table 2.1. Total nameplate
generating capacity for the two military installations in the Anchorage-Cook
Inlet area, Elmendorf AFB and Fort Richardson, are presented in Table 2.2.
Further information about specific generating plants and units for each
of the utilities and military installations discussed in this report is
contained in Appendix A.
2.1
N .
N
TABLE 2.1. Tota 1 Nameplate Generating
CCCT(a) Diesel
Alaska Power Administration 0
Anchorage Municipal Light and Power 138.9
Chugach Electric Association 0
Fairbanks Municipal Utility System 0
Golden Valley Electric Association 0
Homer Electric Association 0
Seward Electric System 0
TOTAL 138.9
(a) CCCT -Combined-Cycle Combustion Turbine
Diesel -Diesel Cycle
Hydro -Hydraulic Turbine
RCCT -Regenerative Cycle Combustine Turbine
SCCT -Simple Cycle Combustion Turbine
ST -Steam Turbine
0
2.2
0
8.25
17.95
2.095
5.5
35.995
Capacity -Railbelt Utilities (1980) -MW
Hydro RCCT SCCT ST Total
30.0 0 0 0 30.0
0 0 89.5 0 230.6
16.5 120.10 287.31 19.0 442.91
0 0 28.35 28.5 65.10
0 0 163.4 25.0 206.35
0 0 0 0 2.095
0 0 0 ·0 5.5
46.5 120.10 568.56 72.5 982.555
TABLE 2.2. Total Nameplate Generating Capacity Anchorage-Cook Inlet
Area Military Installations (1980)
CCCT(a) Oiese 1 Hi:dro
Elmendorf AFB 0 2.1 0
Fort Richardson 0 7.2 0
TOTAL 0 9.3 0
(a) CCCT -Combined-Cycle Combustion Turbine
0 i e se 1 -0 i e se 1 C yc 1 e
Hydro -Hydraulic Turbine
RCCT -Regenerative Cycle Combustion Turbine
SCCT -Simple Cycle Combustion Turbine
ST -Steam Turbine
RCCT SCCT ST Total
0 0 31.5 33.6
0 0 18.0 25.2
0 0 49.5 58.8
Presently, three additional generating facilities are planned for the
Anchorage-Cook Inlet area. The Bradley Lake hydroelectric facility will have
a rated capacity of 90 MW with an expected average annual energy production of
347,000,000 kWh. It is presently anticipated to come on-line in 1988. Under
current plans, it is to be a Federal project built by the Corps of Engineers
and operated by the Alaska Power Administration.
AML&P is planning to add a 73.6-MW combustion turbine unit at Station 2
in 1982. CEA is planning to add a waste heat recovery steam turbine at the
Beluga plant in 1982. This unit will have a generating capacity of
approximately 54 MW.
2.2 FAIRBANKS-TENANA VALLEY AREA
The Fairbanks-Tenana Valley area has one REA cooperative, one municipal
utility, a university generation system, and three military installations.
They are 1 i sted be 1 ON:
Fairbanks Municipal Utilities System (FMUS) -Municipal Utility
Golden Valley Electric Association (GVEA), Inc. -REA
University of Alaska, Fairbanks -University
Eielson AFB -Military
Fort Greeley-Military
Fort Wainwright -Military
2.3
Clear ~ir Force Station is located in this area but is not interconnected with
the distribution grid.
Total nameplate generating capacity for the utilities is presented in
Table 2.3 and capacity for the military installatio.ns is presented in Table 2.4
There are no firm plans for capacity additions in the Fairbanks-Tenana
Valley Area.
2.3 GLENNALLEN -Valdez Area
The Glennallen-Valdez area has a single REA, the Copper Valley Electric
Association, Inc. Their capacity as of 1980 is shown in Table 2.5. The
Copper Valley Electric Association has a hydroelectric generating project
under construction at Solomon Gulch. This facility is expected to come
on-line in 1981 with a capacity of 12 MW.
TABLE 2.3. Total Nameplate Generating Capacity Fairbanks-
Tenana Valley Area Utilities (1980)
CCCT(a) Diesel H,Ydro RCCT seer ST
Fairbanks Municipal
Utilities System 0 8.25 0 0 28.35 29.0
Golden Valley Elec-
tric Association 0 17.95 0 0 170.80 25.0
University of
Alaska 0 5.50 0 0 0 13 .o
TOTAL 0 31.70 0 0 199.15 67.0
(a) CCCT -Combined-Cycle Combustion Turbine
Diesel -Diesel Cycle
Hydro -Hydraulic Turbine
RCCT -Regenerat1ve Cycle Combustion Turbine
SCCT -Simple Cycle Combustion Turbine
ST -Steam Turbine
2.4
Total
65.6
213.75
18.50
297.85
TABLE 2.4. Total Nameplate Generating Capacity, Fairbanks-
Tenana Valley Area Military Installations (1980)
CCCT(a) Diesel Hydro
Eielson AFB 0 0 0
Fort Greeley 0 5.5 0
Fort Wainwright 0 0 0
TOTAL 0 5.5 0
(a) CCCT -Combined-Cycle Combustion Turbine
Diesel -Diesel Cycle
Hydro -Hydraulic Turbine
RCCT -Regenerative Cycle Combustion Turbine
SCCT -Simple Cycle Combustion Turbine
ST -Steam Turbine
RCCT SCCT ST
0 0 8.75
0 0 0
0 0 22.0
0 0 30.75
TABLE 2.5. Total Nameplate Generating Capacity Glennallen-
Valdez Area (1980)
Total
8.75
5.5
22.0
36.25
(a)
CCCT Diesel Hydro RCCT SCCT ST Tota 1
Copper Valley Elec-
tric Association, Inc. 0 16.10
(a) CCCT -Combined-Cycle Combustion Turbine
Diesel -Diesel Cycle
Hydro -Hydraulic Turbine
RCCT -Regenerative Cycle Combustion Turbine
SCCT -Simple Cycle Combustion Turbine
ST -Steam Turbine
2.5
0 0 2.8 0 18.9
APPENDIX A
EXISTING AND PLANNED GENERATING FACILITIES FOR
RAILBELT UTILITIES AND MILITARY INSTALLATIONS
APPENDIX A
EXISTING AND PLANNED GENERATING FACILITIES FOR
RAILBELT UTILITIES AND MILITARY INSTALLATIONS
Tables A.l through A.ll present the existing and planned capacity data
for the utility and military installations in the Anchorage-Cook Inlet area,
the Fairbanks-Tenana Valley area and the Glennallen-Valdez area. Matanuska
Electric Association, Inc. has no existing or planned generating facilities,
so it has not been included in the following tables.
NOTES FOR EXISTING AND PLANNING CAPACITY DATA TABLES
1. Prime Mover:
The power source for the generating unit.
Diesel-Diesel Cycle
SCCT -Simple Cycle combustion Turbine
RCCT -Regenerative cycle Combustion Turbine
ST -Steam Turbine
CCCT -Combined-Cycle Combustion Turbine
Hydro -Hydraulic Turbine
2. Fuel Type:
The primary fuel type used by the generating unit.
Dist. -Distillate Fuel Oil (Includes diesel fuel oil and turbine fuel)
NG -Natural Gas
Coal -Coal
Resid -Residual Fuel Oil
3. Fuel ~upply:
The company or field supplying the fuel.
NEN -Nenana Coal Field
AGAS -Alaska Gas and Service Co.
NP -North Pole Refinery
A.l
Prod -Direct Purchase from Beluga Producers
LS -Local Suppliers
4. Installation Date:
The year the generating unit was installed/came on-line.
5. Retirement Date:
The year the unit is planned to be retired. The following lifetimes
have been assumed for the various types of generating units. These
lifetimes are the same as those assumed by Acres American Inc.
(1981), with the exception of the lifetime for natural-gas-fired gas
turbines. Acres uses a 30-year lifetime, while a 20-year lifetime
will be assumed in this analysis. This reduced lifetime was
selected to more accurately reflect the current Alaska Public
Utilities Commission ruling that the useful depreciated life of a
simple-cycle gas turbine is 16 2/3rds years.
Large Steam Turbines {>100MW) = 30 years
Small Team Turbines (<lOOMW) = 35 years
Oil-Fired Gas Turbines = 20 years
,Natural-Gas-Fired Gas Turbines = 20 years
Diesels = 30 years
Combined-Cycle Units = 30 years
Conventional Hydro = 50 years
6. Nameplate Capacity (MW):
The rated or nameplate capacity of the unit.
7. Generating Capacity at 0°F (MW):
Actaul generating capacity at 0°F. In most cases this is
essentially the same as the nameplate capacity. However, generating
capacity for combustion turbine capacity increases as the ambient
temperature decreases. Since the system load also increases with
decreases in ambient temperature, this increased capacity can be
used to meet peak system load. In most cases the nameplate capacity
A.2
is given for a standard temperature of 60°F. The increase in
generating capacity from 60°F to 0°F is approximately 25%. In other
cases, the nameplate capacity is given for a standard temperature of
35°F. The increase in generating capacity from 35°F to 0°F is
approximately 15%. These factors were used to compute the
generating capacity of combustion turbine capacity at 0°F given the
nameplate· capacity if utility data have not been obtained or if they
were not available.
8. Heat Rate (Btu/kWh):
Average annual heat rate for the unit based upon typical operation.
The following heat rates have been tentatively assumed for the
various types of prime movers if utility data have not been obtained
or if they were not available.
Diese 1 Cycle
Simple Cycle Combustion Turbine
Regenerative Cycle Combustion Turbine
I
Combined-Cycle Combustion Turbine
Steam Turbine (less than 20 MW)
Steam Turbine (greater than 20 MW)
9. Forced Outage Rate:
10,500
15,000
10,000
8,500
12,000
10,000
This is the probability that a plant will not operate when called
upon to generate power. The forced outage rate does not include
scheduled maintenance. The following forced outage rates have been
tentatively assumed:
Diesel 0.10
Simple Cycle Combustion Turbine 0.10
Regenerative Cycle Combustion Turbine 0.10
Combined-Cycle Combustion Turbine 0.10
Steam Turbine 0.10
Hydro 0.05
A.3
10. Maximum Annual Capacity Factor:
where
The maximum annual capacity factor is the percent of time the
generating unit is available. This includes both maintenance and
forced outages. For purposes of this project, the following
equation should be satisfied.
MACF = (1 -FOR) (1 -AMR)
MACF = maximum annual capacity factor
FOR = forced outage rate
AMR =annual maintenance rate.
The following maximum annual capacity factor and annual maintenance
rates have been assumed:
Diesel
Simple Cycle Combustion Turbine
Regenerative Cycle Combustion Turbine
Combined-Cycle Combustion Turbine
Steam Turbine
Hydro
AMR
0.10
0.10
0.10
0.10
0.10
0.05
MACF
0.81
0.81
0.81
0.81
0.81
0.95
Maximum annual capacity factors for hydroelectric plants vary
depending upon site hydrologic conditions.
11. Loading Order/Operating Mode:
The typical loading order or operating mode for the generating unit
(peaking, intermediate, base, load following, etc.).
A.4
):::o .
TABLE A.l. Existing and Planned Capacity Data
UTILITY: Alaska Power Administration
Nameplate Generating Average Forced Maximum
Prime Fuel Fuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit Mover ~ ~ Date Date (MW) @ O"F (MW) Rate (Btu/kWh) Rate cit~ Factor Comments
EXISTING
Eklutna Hydro 1955 2005 30.0 0.01 0.95(a)
PLANNED
Bradley Lake flydro 1988 2038 90 90 0.01 o.9s(b)
(a) Average annual energy production for Eklutna is approximately 147,875,000 kWh. This is equivalent to an annual load factor of 0.56.
(b) Average annual energy production from Bradley Lake is expected to be approximately 347,000,000 kWh. Of this total, 315,000,000 kWh wi'll
be firm energy and 32,000,000 kWh will be secondary. The equivalent annual load factor is 0.44.
TABLE A.2. Existing and Planned Capacity Data
UTILITY: Anchorage Municipal Light and Power
Fuel(a)
Nameplate Generating Average Forced Maximum
Prime Fuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit Mover ~ ~ Date Date (MW) @ o•F (MW) Rate (Btu/kWh) Rate citl Factor ..0.!!!!!~-~
EXISTING
Station #1
Unit #1 SCCT NG/Dist AGAS/LS 1962 1982 14.0 16.25 14,000 0.10 0.81 Reserve/
Peaking
Unit 112 SCCT NG/Dist AGAS/LS 1964 1984 14.0 16.25 14,0DO 0.10 0.81 Reserve/
Peaking
Unit 1/3 SCCT NG/Dist AGAS/LS 1968 1988 18.0 18.0 14,000 0.10 0.81
Unit 114 SCCT NG/Dist AGAS/LS 1972 1992 28.5 32.0 12,500 0.10 0.81
):::o Diesel 1(b) Diesel Dist LS 1962 1982 1.1 1.1 10,500 0.10 0.81 Black Start . Unit
CTI
Diesel 2(b) Diesel Dist LS 1962 1982 1.1 1.1 10,500 0.10 0.81 Black Start
Unit
Station 112
Unit #5 SCCT NG/Dist AGAS/LS 1974 1994 32.3 40.0 12,500 0.10 0.81
Unit #6(c) CCST 1979 20og 33.0 33.0 0.10 0.81
Unit 1/7 SCCT NG/Dist AGAS/LS 1980 2000 73.6 90.0 11,000 0.10 0.81
PLANNED
Station 112
Unit #8 SCCT NG/Dist AGAS/LS 1982 2002 73.6 90.0 12,500 0.10 0.81
(a) All AML&P SCCTs are equipped to burn natural gas or oil. In normal operation they are supplied with natural gas from AGAS. All units have reserve oil
storage for operation in the event gas is not available.
(b) These are black-start units only. They are not included in total capacity.
(c) Units 115, 6, and 7 are designed to operate as a unit combined-cycle plant. When operated in this mode, they have a generating capacity at 0°F of
approximately 139 MW with a heat rate of 8500 Btu/kWh.
TABLE A.3. Existing and Planned Capacity Data
UTILITY: Chugach Electric Association
Nameplate Generating Average Forced Maximum
Prime Fuel Fuel Installation Retirement Capacity Ca~acity Annual Heat Outage Annual Capa-
Plant/Unit Mover ..l1l!L ~ Date Date (MW) @ 0 F (MW) Rate ! Btu/kWh l Rate citx Factor _j;_omm~'l!L-
EXISTING
Beluga
Unit Ill SCCT NG Prod. 1968 1988 14.0 16.1 15,000 0.10 0.81
Unit 112 SCCT NG Prod. 1968 1988 14.0 16.1 15,000 0.10 0.81
Unit #3 RCCT ng prod. 1973 1993 51.0 53.0 10,000 0.10, 0.81
Unit #4 SCCT NG Prod. 1976 1996 9.3(a) 10.7 15,000 0.10 0.81 Jet Engine
Unit 1/5 RCCT NG Prod. 1975 1995 60.0 58.0 10,000 0.10 0.81
)> Unit 1/6 SCCT NG Prod. 1976 1996 62.0 68.0 15,000 0.10 0.81
..;,_, Unit 117 SCCT NG Prod. 1977 1997 62.0 68.0 15,000 0.10 0.81
Bernice Lake
Unit 11 SCCT NG AGAS 1963 1983 7.5 8.6 23,400 0.10 0.81
Unit #2 SCCT NG AGAS 1972 1992 16.5 18.9 23,400 0.10 0.81
Unit #3 SCCT NG AGAS 1978 1998 23.0 26.4 23,400 0.10 0.81
Cooper Lake
Unit #1, 2 Hydro 1961 2011 16.0 16.0 0.05 o.95(b)
International
Unit #1 SCCT NG AGAS 1964 1984 14.0 14.0 40,000 0.10 0.81
Unit #2 SCCT NG AGAS 1965 1985 14.0 14.0 40,000 0.10 0.81
Unit 113 SCCT NG AGAS 1970 1990 17.0 18.0 40,000 0.10 0.81
Plant/Unit
Knik Ann(c)
Unit #l
Unit 1/2
Unit 113
Unit 114
Unit #5
PLANNED
Beluga Unit 9(d)
Bernice Lake #4
Prime Fuel Fuel
Mover ~ ~..I!.lL
ST
ST
ST
ST
ST
CCST
SCCT
NG
NG
NG
NG
NG
NG
AGAS
AGAS
AGAS
AGAS
AGAS
AGA~
TABLE A.3. Existing and Planned Capacity Data (contd)
UTILITY: Chugach Electric Association
Installation
Date
1952
1952
1957
1957
1957
1982
1982
Retirement
Date
1987
1987
1992
1992
1992
2012
2002
Nameplate
Capacity
~j_
0.5
3.0
3-.0
3.0
5.0
54
23.0
Generating
Ca~acity
@ 0 F (MW)
0.5
3.0
3.0
3.0
5.0
54
26.4
Average
Annual Heat
Rate (Btu/kWh)
12,000
Forced
Outage
Rate
0.10
0.10
0.10
0.10
0.10
0.10
Maximum
Annual Capa-
city F.actor
0.81
0.81
0.81
0.81
0.81
0.81
(a) Beluga Unit #4 is a jet engine used for peaking only. It is not included in total capacity.
(b) Average annual energy production for Cooper Lake is approximately 42,000,000 kWh. This is equivalent to an annual load factor of 0.30.
(c) Knik Ann units are old and have higher heat rates. They are not included in total.
(d) Beluga Units 116, 7, and 8 will operate as a unit combined-cycle plant in 1g82. When operated in this mode, they will have a generating capacity of
about 178 MW with a heat rate of 8500 Btu/kWh. Thus, Units 116 and 7 will be retired from "gas turbine operation" and added to "gas combined-cycle
operations."
Plant/Unit
EXISTING
Seldovia
Plant/Unit
EXISTING
ALCO
EMD
Prime Fue 1 Fue 1
Mover ~ ~
Diese 1 Dist. LS
None
Prime Fuel Fuel
Mover ~ ~
Diesel Dist.
Diesel Dist.
None
LS
LS
TABLE A.4. Existing and Planned Capacity Data
UTILITY: Homer Electric Association
Installation
Date
1957
Retirement
Date
1987
Nameplate
Capacity
(MW)
1.50
Generating
Capacity
!J!.:.Utm
1.50
Average
Annual Heat
Rate (Btu/kWh)
10,500
Forced
Outage
Rate
0.10
TABLE A.5. Existing and Planned Capacity Data
UTILITY: Seward Electric Association
Installation
Date
1965
1976
Retirement
Date
1985
1996
Nameplate
Capacity
(MW)
3.0
2.5
Generating
Capacity
@ o•F (MW)
3.0
2.5
Average
Annual Heat
Rate (Btu/kWh)
10,500
10,500
Forced
Outage
Rate
0.10
0.10
Maximum
Annua 1 Cap a-
city Factor
0.81
Maximum
Annual Capa-
city Factor
0.81
0.81
Standby
Comments
Standby
Standby
TABLE A.6. Existing and Planned Capacity Data
UTILITY: Military Installations -Anchorage Area
Nameplate Generating Average Forced Madmum
Prime Fuel Fuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit Mover ~ ~!!lL Date Date (MW) @ O"F J!1!tl Rate (Btu/kWh) Rate cit~ Factor Co11111E!nts
EXISTING
Elmendorf AF B
)::o . Total Diesel Diese 1 Diese 1 LS 1952 2.1 10,500 0.10 0.81 ..,...
0 Total ST ST NG AGAS 1952 31.5 12,000 0.10 0.81
Fort Richardson
Total Diesel Diese 1 Diese 1 LS 1952 7.2 10,500 0.10 0.81 Cold Start
Units
Total ST ST NG AGAS 1952 18.0 19,000-0.10 0.81 Cogeneration
20,000 Used for
Steam
lleating
PLANNED None
TABLE A. 7. Existing and Planned Capacity Data
UTILITY: Golden Valley Electric Association
Nameplate Generating Average Forced Maximum
Prime Fuel Fuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit ~lover ..ll'I!L ~ __ Qill._ Date !MW) @ 0°F !MW) Rate !Btu/kWh) Rate cIt~ Factor Conrnents
EXISTING
Healy Coal ST Coal NEN 1967 2002 25.0 25.0 13,200 0.01 0.92
Healy Diesel Diesel Dist. LS 1967 1987 2. 75 2.75 10,500 0.01 0.81 Peaking/
Black
Start Unit
North Pole
Unit #1 SCCT Dist. LS 1976 1996 64.7 65.0 14,000 0.022 0.81
)::o Unit 1/2 SCCT Dist. LS 1977 1997 64.7 65.0 14,000 0.015 0.81
...... ...... Zendher
GT 1 SCCT Dist. LS 1971 1991 18.4 18.4 15,000 0.10 0.81
GT 2 SCGT Dist. LS 1972 1992 17.4 17.4 15,000 0.10 0.81
GT 3 SCCT Dist. LS 1975 1995 2.8 3.5 15,000 0.10 0.81
GT 4 SCCT Dist. LS 1975 19g5 2.8 3.5 15,000 0.10 0.81
Combined Diesel Diesel Dist. LS 1960-70 1995 21.0 21.0 10,500 0.10 0.81
PLANNED None
TABLE A.8. Existing and Planned Capacity Data
UTILITY: University of Alaska -Fairbanks
Nameplate Generating Average Forced Maximum
Prime Fuel Fuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit Mover ~ ~ Date Date {MW) @ o•F {MW) Rate {Btu/kWh) __!!!!:.!!._ cit~ Factor __f_ommen t s
51 ST Coal NEN 1.50 1.50 12,000 0.10 0.81
S2 ST Coal NEN 1g80 1.50 1.50 12,000 0.10 0.81
53 ST Coal NEN 10.0 10.0 12,000 0.10 0.81
D1 Diesel Dist. LS 2.75 2.75 10,500 0.10 0.81
D2 Diesel Dist. LS 2.75 2. 75 10,500 0.10 0.81
TABLE A.9. Existing and Planned Capacity Data
UTILITY: Fairbanks Municipal Utilities System
)::> . Nameplate Generating Average Forced Maximum 1-'
N Prime Fuel Fuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit Mover ..1.ru_ ~ Date Date (MW) @ o•F (MW) Rate (Btu/kWh) Rate cit~ Factor Conme'!_t:.L_
EXISTING
Chen a
Unit #1 ST Coal NEN 1954 1989 5.0 5.0 18,000 0.10 0.81
Unit 1/2 ST Coal NEN 1952 1987 2.0 2.0 22,000 0.10 0.81
Unit 1/3 ST Coal NEN 1952 1987 1.5 1.5 22,000 0.10 0.81
Unit 1/4 SCCT Dist. LS 1963 1983 5.25 6.6 15,000 0.10 0.81
Unit 1/5 ST Coal NEN 1970 2005 20.5 20.5 13,320 0.10 0.81
Unit 1/6 SCCT Dlst. LS 1976 1996 23.1 28.8 15,000 0.10 0.81
Diese 1 1 Diesel Dist. LS 1967 1987 2.75 2.75 12,150 0.10 0.81
Diesel 2 Diesel Dist. LS 1968 1988 2.75 2.75 12,150 0.10 0.81
Diesel 3 Diesel Dist. LS 1968 1988 2.75 2.75 12,150 0.10 0.81
PLANNED None
TABLE A.lO. Existing and Planned Capacity Data
UTILITY: Military Installations -Fairbanks
Nameplate Generating Average Forced Maximum
Prime Fuel CFuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit Mover ~ ~ Date Date _<m!l_ @ O"F {MW) Rate {Btu/kWh) Rate citx Factor Comments
EXISTING
Eielson AFB
)> Sl, S2 ST Oil LS 1953 2.50 0.10 0.81 . ..... S3, S4 ST Oil LS 1953 6.25 0.10 0.81 w
Fort Gree 1 ey
Dl, D2, D3 Diesel Oil 3.0 10,500 0.10 0.81 Standby
D4, D5 Diesel Oil 2.5 10,500 0.10 0.81 Standby
Ft. Wainwright
Sl, S2, S3, 54 ST Coal NEN 1953 20 19,000-0.10 0.81 Cogeneration
20,000 Used for
Steam
Heating
55 ST Coal NEN 1953 2 0.10 0.81 Standby
PLANNED None
TABLE A.11. Existing and Planned Capacity Data
UTILITY: Copper Valley Electric Association, Inc.
Nameplate Generating Average Forced Maximum
Prime Fuel Fuel Installation Retirement Capacity Capacity Annual Heat Outage Annual Capa-
Plant/Unit Mover ~ ~ Date Date (MW) @ O"F (MW) Rate (Btu/kWh) Rate citx Factor Comments
EXISTING
Glennallen
Units #1, 112 Diesel Dist. LS 1959 1981 0.64 0.64 10,500 0.10 0.81
Unit #3 Diesel Dist. LS 1963 1983 0.56 0.56 10,500 0.10 0.81
Units 114, #5 Diesel Dist. LS 1966 1986 2.4 2.4 10,500 0.10 0.81
:;J::o . Unit 116, #7 Diesel Dist. LS 1975-76 1996 5.2 5.2 10,500 0.10 0.81
......
.j:>.
Valdez
Units #1, H2, 113 Diesel Dist. LS 1967 1987 1.8 1.8 10,500 0.10 0.81
Unit #4 Diesel Dist. LS 1972 1992 1.9 1.9 10,500 0.10 0.81
Unit 115 Diesel Dfst. LS 1975 1995 1.0 1.0 10,500 0.10 0.81
Unit #6, Diesel Dist. LS 1975 1995 2.6 2.6 10,500 0.10 0.81
Unit 117, SCCT Dist. LS 1976 1996 2.8 3.5 14,500 O.lO 0.81
PLANNED
Sol001on Gulch Hydro 1981 2031 12.0 12.0 0.01 o.gs(a)
(a) Average annual energy production from Solomon Gulch is expected to be approximately 55,000,000 kWh.
be firm energy and 16,000,000 will be secondary. The equivalent annual load factor is 0.52.
Of this total 39,000,000 kWh will
REFERENCES
Acres American Incorporated. 1981. Susitna Hydroelectric Project
Development Selection Report. Prepared for the Office of the Governor,
State of Alaska, Juneau, Alaska.
R.1