HomeMy WebLinkAboutAlaska_Energy_Statistics_Final_Report_1960-2010_AEA_ISER_Jun_2012Alaska
Energy
Statistics
1960-2010
Final Report
By
Ginny Fay, Alejandra Villalobos Melendez
and Amber Converse
Institute of Social and Economic Research
University of Alaska Anchorage
in collaboration with
Alaska Energy Authority
June 2012
4 "SKA--
ENERGY AUTHORITY s
Acknowledgments
We sincerely appreciate the time and effort of numerous electric utilities, AEA program
managers and staff, and many other colleagues who shared information, reviewed this report
and provided valuable feedback.
Suggested citation:
Fay, Ginny, Alejandra Villalobos Melendez, and Amber Converse, 2011, Alaska Energy Statistics
1960-2010, prepared for Alaska Energy Authority, June 2012, 32 pages.
TABLE OF CONTENTS
INTRODUCTION............................................................................................................................................4
SUMMARYAND HIGHLIGHTS....................................................................................................................... 6
ElectricUtilities Summary Tables.......................................................................................................... 7
Table La Utilities/Communities Participating in Power Cost Equalization Program, 2010...................7
Figure 1. PCE Eligible Communities........................................................................................................8
Table 1.b Installed Capacity (kW), 2010.................................................................................................9
Table 1.c Net Generation (MWh), 2010...............................................................................................10
Table 1.d Net Generation by Fuel Type (MWh), 2010.........................................................................11
Figure 2. Alaska Utilities Net Generation by Fuel Type, 2010..............................................................11
Table 1.e Fuel Use for Power Generation, 2010..................................................................................12
Figure 3. Distribution of Fuel Used by Utilities for Power Generation in Alaska.................................13
Figure 4. Barrels of Oil Used for Electricity Generation by Utilities, by Energy Regions......................13
Table1.f Sales (MWh), 2010.................................................................................................................14
Table 1.g Revenue ($000), 2010...........................................................................................................15
Table 1.h Customers (Accounts), 2010.................................................................................................16
Figure 5. Distribution of Utility Sales, Revenue and Customers by Customer Type ............................17
Utility Installed Capacity and Net Generation over time...................................................................17
Figure 6. Installed Capacity by Prime Mover over Time.......................................................................18
Figure 7. Net Generation by Fuel Type over Time................................................................................18
AppendixA. Glossary of Terms.............................................................................................................19
Appendix B. Maps of Energy Regions...................................................................................................27
Appendix C. Data Sources for Electric Energy Statistics.......................................................................29
Appendix D. Reporting Requirements..................................................................................................31
3
INTRODUCTION
Prior to 1985, the federal Alaska Power Administration published the Alaska Electric Power Statistics.
Then, the Alaska Energy Authority (formerly the Alaska Power Authority) began gathering statistical data
and publishing this annual report. In 1988, the Alaska Electric Power Statistics report became a
combined effort between the Alaska Systems Coordinating Council and the Alaska Energy Authority.
Beginning in 1993, the report became a joint effort between the Alaska Systems Coordinating Council
and the Alaska Department of Community and Regional Affairs, Division of Energy. After the 1995
report, no further reports were published until 2003 when a report was prepared by the Institute of
Social and Economic Research (ISER), University of Alaska Anchorage (UAA), with funding provided by
the Alaska Energy Authority (AEA), the Regulatory Commission of Alaska (RCA), and the Denali
Commission.
This report of the twenty-fifth edition of the Alaska Electric Energy Statistics was prepared by the
Institute of Social and Economic Research in collaboration with the Alaska Energy Authority. Continuing
the new 2009 format, data tables are presented solely in digital form in a MS Excel file that contains all
data tables. The workbook containing the data tables are available on the ISER website at
http:liiser.uaa.alaska.edu/Publications/2012 06-AlaskaEner StatisticsCY2010Tab _) and the AEA
website(http://www.akenereyauthoritv.org/1.The data tables are presented in a dataset format for
convenient use and manipulation. All data presented is identified by the geographic regions used
historically in previous Alaska Electric Energy Statistics' as well as AEA energy regions, Native
corporation regions and census areas. The data tables available in the workbook are as follows:
Table
Description
Summary Tables By AEA Energy Regions
Table La Utilities Participating in the Power Cost Equalization program
Table 1.b
Installed Capacity (kW)
Table 1.c
Net Generation (MWh)
Table 1.d
Net Generation by Fuel Type (MWh)
Table Le
Fuel Use for Power Generation (Physical Units, MMBtu)
Table V
Sales (MWh)
Table 1.g
Revenue ($000)
Table 1.h
Customers (Accounts)
Detailed Tables
Installed Capacity
Table 2.1a
Installed Capacity by Prime Mover by Plant
Table 2.1b
Installed Capacity by Prime Mover (Percent Distribution)
Net Generation and Disposition
Table 2.2a
Net Generation and Total Disposition (MWH)
Table 2.3a
Net Generation by Prime Mover
Table 2.3b
Net Generation by Fuel Type and Fuel Use
Table 2.3c
Net Generation, Fuel Use, and Fuel Cost by Plant
' The regions are: Arctic Northwest, South Central, South East, South West and Yukon.
4
Table 2.4a
Utility CO2 Emissions
Revenue, Customers and Prices
Table 2.5a
Utility Sales, Revenue, and Customers
Table 2.5b
Average Annual Energy Use and Rates
Table 2.5c
Residential Rates and PCE payments
Electric Utility Historical Tables
Table 3.1
Utility Installed Capacity by Prime Mover
Table 3.2
Utility Installed Capacity by Region
Table 3.3
Utility Net Generation by Fuel
Table 3.4
Utility Net Generation by Region
Table 3.5
Utility Sales, Revenue, and Customers
Table 3.6
Average Annual Energy Use and Rates
This accompanying text is meant to provide a brief introduction, highlights and summary tables only.
The summary tables presented in this report use the AEA Energy Pathway publication regions. Maps
illustrating these regions are in Appendix B. We also include a glossary of terms.
The twenty-third edition (2008 tables) published in May 2011 included tables reporting military and
industrial generation data. However, due to lack of data availability this report does not contain that
information. Information on utility electricity capacity, generation, and other characteristics was
gathered from reports filed with the U.S. Department of Energy (DOE), Energy Information
Administration (EIA). Though data from these survey forms was not yet available on the EIA website
when the preliminary report was being prepared, the Alaska Energy Authority directly collected copies
of the EIA survey forms 860, 861 and 923 from a select number of utilities. After EIA data files were
finalized, a careful cross-check between preliminary data gathered by AEA and these final published data
files were conducted. Additionally, we used data collected by the Alaska Energy Authority through the
Power Cost Equalization (PCE) program and a limited number of direct contacts with electric power
producers. This change in methodology allowed us to produce a preliminary report in September 2011
which has now been completed after data files were published by EIA. This final report contains the best
available public information regarding electric utilities in Alaska.
All producers of electricity with installed capacity greater than one megawatt are required by law to
report their operations to the federal government. A number of utilities in Alaska fall below that
installed capacity threshold. Information for these smaller utilities came primarily from the PCE
program. The installed capacity table (Table 2.1a) includes all utilities for which data are available.
In many parts of the state there is no utility -produced electricity available and any activity requires that
electricity must self -generate. The number of such small installations (e.g. Point Baker, Port Protection,
Telida) is quite large and it would be a very expensive task to try to identify and contact each one
individually.
It is important to note, that this publication is meant to serve as general reference and broad overview
of electric power in Alaska. Because data comes from a variety of sources and imperfections in the
source data, the reader may find inconsistencies across different tables. For example, Table 2.5b shows
average rate per kilowatt-hour as calculated using the reported revenue, sales and customers; while
Table 2.5c shows average rate per kilowatt hour as reported by the utility to the PCE program; these two
rates are sometimes slightly differentz. Data in different tables may include different cases, or may be
guided by slightly different concept definitions depending on the data source. However, the authors of
this report believe that the data presented provide a reasonable and valuable overview of electric
power and energy across Alaska.
SUMMARY AND HIGHLIGHTS
The purpose of this report is to present electric power reference data for Alaska; it is not intended to
provide detailed analysis of energy production, consumption or uses. Nevertheless, this section
highlights information that may be of particular interest to the reader.
Scope of Report
The Alaska Energy Authority and the Institute of Social and Economic Research at the University of
Alaska Anchorage prepared this report, which primarily presents 2010 data on electricity produced by
utilities in Alaska, including summary and detailed tables showing:
• Installed capacity by:
• Net generation:
➢
type of utility,
➢
type of utility
➢
prime mover
➢
prime mover
➢
and plant
➢
and fuel type
• Fuel
• Utility
➢
use
➢
sales
➢
cost
➢
revenue
➢
CO2 emissions
➢
customers
■ average annual electricity
use
■ average annual electricity
price
Electricity Generation and Cost
• In 2010, Alaska had about 2,202 megawatts of utility installed capacity that generated about 6.5
million megawatt -hours of electricity.
• In 2010, the statewide portion of electricity generated by natural gas increased from 55% to
57%; the portion of hydroelectric power increased from 20% in 2009 to 22% in 20103;
generation from oil products decreased from 18% to 15%; while coal decreased from 7%to
6%.Generation from wind remained less than 1%; but it increased from about 0.14% in 2009 to
0.31% statewide. The statewide picture varies sharply by region.
• The Railbelt region is home to most of the state's population which uses most (about 78%) of
the electricity. Natural gas is used to generate most of the electricity for the Railbelt, but the
region also has hydroelectric capacity.
• Many (but not all) communities in Southeast Alaska generate electricity with hydroelectric
capacity; some rely on diesel. Most use diesel for back-up generation.
2 Only for PCE communities. Communities for which the data source is EIA report the same calculated rate as in
Table 2.5b.
s The amount of electricity produce from hydroelectric resources varies from year to year depending on water
levels. Over the last decade, hydro power does not show a significant positive trend.
• Rural communities in western and interior Alaska rely primarily on diesel to generate electricity,
but wind power is being added in a growing number of rural locations, financed largely by the
Alaska Renewable Energy Fund. Since 2008, the annual amount of electricity generated by wind
increased over nine fold to 20,348 MWh.
• Wood was used to generate heat in community -level thermal facilities in about ten
communities, mostly in Southeast where wood resources are abundant.
• The average annual residential use of electricity statewide in 2010 was about 7,670 kilowatt-
hours —but that ranged from around 1,100 kilowatt-hours in places where electricity is most
expensive to more than 13,800 where it is cheapest. The national average annual use is about
11,000 kilowatt-hours.
Communities in Southeast Alaska that rely primarily on hydroelectric power to generate electricity had
the lowest rates (as little as 10 cents per kilowatt-hour in 2010).4 Residents of Anchorage and other
places in Southcentral Alaska that rely mostly on natural gas for generation paid around 13 cents per
kilowatt hour in 2010. Alaskans in small remote rural places that rely on diesel had the most expensive
electricity (from roughly 50 cents to more than $1.50 per kilowatt hour in 2010). The state helps to
lower the price of electricity in most of those remote rural communities through the Power Cost
Equalization program, but electric bills still remain much higher in remote rural areas than in urban
communities.
Electric Utilities Summary Tables
Table 1.a Utilities5/Communities Participating in Power Cost Equalization Program, 2010
By AEA Energy Regions
AEA Energy Region
Aleutians
Bering Straits
Bristol Bay
Active
12
17
25
Inactive
1
0
1
Ineligible
0
0
0
Total
13
17
26
Percent Active
92%
100%
96%
Copper River/Chugach
6
0
2
8
75%
Kodiak
4
1
1
6
67%
Lower Yukon-Kuskokwim
48
0
0
48
100%
North Slope
7
1
0
8
88%
Northwest Arctic
12
1
0
13
92%
Railbelt
0
0
14
14
0%
Southeast
21
10
31
68%
Yukon-Koyukuk/Upper Tanana
38
3
2
43
88%
State Total
190
8
29
227
84%
"The construction of many of these facilities was paid for with public funds which accounts in part for the lower rates.
s Note: For utilities that serve many communities with no grid such as AVEC and AP&T, each community is counted
as a separate utility.
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Table 1.b Installed Capacity (kW), 2010
By AEA Energy Regions
AEA Energy Region
Total
Percent of
Total
Aleutians
34,945
2%
Bering Straits
38,709
2%
Bristol Bay
27,561
1%
Copper River/Chugach
56,255
3%
Kodiak
63,056
3%
Lower Yukon-Kuskokwim
51,102
2%
North Slope
40,600
2%
Northwest Arctic
32,042
1%
Railbelt
1,418,213
64%
Southeast
Yukon-Koyukuk/Upper Tanana
410,733
29,184
19%
1%
State Total
2,202,400
100%
Compared to 2009 the installed capacity remained stable without significant growth. The
exception was wind installed capacity which almost doubled from 7,884kW in 2009 to 11,707
kW in 2010. Since 2008, wind installed capacity increased more than four fold. However, wind
accounts for less than half of one percent of the total installed capacity in Alaska.
• Railbelt hydroelectric installed capacity is 13% of the Railbelt total
• Hydroelectric installed capacity is 20% of the statewide total
• Railbelt total installed capacity is 64% of the statewide total
Railbelt Hydroelectric: 190MW
Railbelt Total: 1,418 MW
Alaska Hydroelectric: 442 MW
Alaska Total: Z202 MW
Table 1.c Net Generation (MWh), 2010
By AEA Energy Regions
Percent of
AEA Energy Region
Total
Total
Aleutians
51,565
1%
Bering Straits
46,043
1%
Bristol Bay
45,428
1%
Copper River/Chugach
113,912
2%
Kodiak
148,013
2%
Lower Yukon-Kuskokwim 101,289 2%
North Slope 83,140 1%
Northwest Arctic 44,674 1%
Railbelt 5,031,183 78%
Southeast 789,060 12%
Yukon-Koyukuk/Upper Tanana 31,187 0%
State Total 6,485,494 100%
Compared to 2009, in 2010 net generation increased just over 1% point; except power
generated by wind which more than doubled from 9,152 MWh in 2009 to 20,348 MWh in 2010.
However, wind accounts for less than half of one percent of the total power generation in
Alaska.
• Railbelt hydroelectric generation remained stable at 9% of the Railbelt
total.
• Hydroelectric generation was 22% of the statewide total, increasing from
20% in 2009.
• Railbelt total generation was 78% of the statewide total, decreasing from
79% in 2009.
Railbelt Hydroelectric: 467,864 MWh
Railbelt Total: 5,031,183 MWh
Alaska Hydroelectric: 1,428,838 MWh
Alaska Total: 6,484,493 MWh
10
Table 1.d Net Generation by Fuel Type (MWh), 2010
By AEA Energy Regions
AEA Energy Region Oil Gas Coal Hydro Wind Total
Aleutians 49,236 2,328 51,564
Bering Straits 43,814 2,229 46,042
Bristol Bay
45,414
3
11
45,428
Copper River/Chugach
51,413
62,498
113,911
Kodiak
11,242
124,165
12,606
148,013
Lower Yukon-Kuskokwim
98,780
2,509
101,289
North Slope
28,460
54,680
83,140
Northwest Arctic
40,577
3,005
1,092
44,674
Railbelt
532,208
3,635,555 393,673 467,864
1,901
5,031,201
Southeast
20,086
768,974
789,060
Yukon -Koyukuk/
31,187
31,187
Upper Tanana
Total
952,417
3,690,235 393,673 1,428,837
20,348
6,485,510
15% 57% 6% 22.0% 0.31% 100%
Figure 2. Alaska Utilities Net Generation by Fuel Type, 2010
Wind
0%
Coa
6%
11
Table 1.e Fuel Use for Power Generation, 2010
By AEA Energy Regions
Oil Gas Coal
AEA Energy Region
(Short
(Barrels) (Mcf) Tons)
Aleutians
90,412
Bering Straits
69,846
Bristol Bay
87,683
Copper River/Chugach
117,887
Kodiak
20,812
Lower Yukon-Kuskokwim
180,810
North Slope
51,226
755,159
Northwest Arctic
58,761
Railbelt
889,067
38,976,546
409,828
Southeast
Yukon-Koyukuk/Upper Tanana
41,195
56,991
Total (Physical Units)
1,664,691
39,731,705
409,828
Conversion Factor 6(MMBtu)
5.825
1.025
19.536
Total MMBtu
9,696,822
40,724,998
8,006,400
The fossil fuel most used for electricity generation in Alaska is natural gas, though it is only
available in the Railbelt and some communities in the North Slope region. Natural gas accounts
for 70% of fossil fuels consumed by utilities for power generation, about a 4% points increase
from 2009. It appears that the increase in natural gas displaced diesel fuel, the second most
used fossil fuel for power generation, which decreased 4% points to about 16% of fuel used in
2010. The Railbelt region consumes the most diesel for power generation in Alaska (mostly for
stand-by). Compared to 2009, Railbelt consumption of diesel fuel decreased about 6% points to
53% of the 2010 statewide fuel used by Alaska utilities. The Lower Yukon-Kuskokwim region
had a 3% point increase in diesel fuel use raising its state's share to 11% of diesel fuel used.
Finally, coal makes up 14% of the fossil fuels used and had no change from 2009. Coal is only
used in the Railbelt regions, specifically in the Fairbanks area, which has a convenient local
supply.
In 2010, burning of fossil fuels to generate power produced about 3.6 million metric tons of
carbon dioxide, a 3% decrease. This decrease most likely resulted from the substitution of
6 Thermal conversion factors can be used to estimate the heat content in British thermal units (BTU) of a given
amount of energy measured in physical units. The conversion factors shown correspond the average amount of
BTUs found in barrels of oil Mcf of natural gas and short tons of coal respectively, as published by the U.S. Energy
Information Administration.
12
natural gas for diesel, as natural gas burns more cleanly'. About 60% of utility CO2 emissions
were produced from burning natural gas, 21%from coal and 19%from diesel.
Figure 3. Distribution of Fuel Used by Utilities for Power Generation in Alaska
*Distribution based on MMBtu energy equivalent units.
Figure 4. Barrels of Oil Used for Electricity Generation by Utilities, by Energy Regions
Railbelt, 53%
Otl
M ME
A
Lower Yukon-
Kuskokwim,
11%
Kodiak,1%
Northwest
Arctic, 4%
Yukon-
Koyukuk/Upper
Tanana, 3%
The amount carbon dioxide emissions associated with fuel consumption by stationary sources, such as a utility,
are lower when consuming natural gas (53.06 Kg CO2 /MMBtu, weighted national average) than when consuming
petroleum distillate fuels (73.15 Kg CO2/MMBtu). To find additional information please refer to the U.S. Energy
Information Administration website at
13
Table M Sales (MWh), 2010
By AEA Energy Regions
AEA Energy Region
Residential
Commercial
Others
Total
Percent of Total
Aleutians
8,752
34,008
10,065
52,826
1%
Bering Straits
14,124
16,924
10,519
41,567
1%
Bristol Bay
14,923
25,751
11,193
51,868
1%
Copper River/Chugach
23,747
72,149
4,721
100,617
2%
Kodiak
34,586
21,828
84,901
141,315
2%
Lower Yukon-Kuskokwim
North Slope
Northwest Arctic
Railbelt
Southeast
Yukon-Koyukuk/Upper
Tanana
Total
Percent of Total
31,302
35,914
21,725
88,942
17,199
58,556
1,465
77,221
12,699
12,017
8,138
32,853
1,619,410
2,126,687
1,036,081
4,782,178
308,371
310,686
176,606
795,663
11,334
8,087
8,445
27,866
2,096,447
34%
2,722,607 1,373,861
22%
44%
6,192,915
Electricity sales show a decrease of about 1.5% compared to 2009. Some regions appear to
have significant drops in reported sales. For example, North Slope shows a 37% decrease,
Bering Straits about 21%, Yukon-Koyukuk/Upper Tanana region about 15%. However, these
differences result from unavailable data or utilities with only partial reporting.9 So, it's likely
that statewide generation levels remain stable.
As expected most of the power sales were in the Railbelt region. The Southeast and Railbelt
regions had the highest annual average use per residential customer of about 9,620 kWh and
7,670 kWh, respectively. The Yukon-Koyukuk/Upper Tanana and Bering Straits regions had the
lowest annual average use per residential customer of about 3,822 kWh and 4,200 kWh,
respectively.
Overall, slightly less than half, about 44%, of the electricity produced in Alaska was sold to
commercial customers. The North Slope and Railbelt regions had the highest annual average
use per commercial customer of about 72,040 kWh and 71,470 kWh, respectively. The Yukon-
Koyukuk/Upper Tanana and Kodiak regions have the lowest annual average use per commercial
customer of about 13,110 kWh and 20,120 kWh, respectively.
s The significant differences between 2009 are 2010 figures are methodological. In 2010, industrial sales are
included in the 'Other' category. In 2009, industrial customers were included in the commercial category and
'Other included sales to community, governmental facilities and others.
9 For example: For the North Slope region, data for commercial sales from Deadhorse (TDX) is not available; for the
Bering Straits region only partial reporting is available for Nome Utilities (missing 4 months of data); for the Yukon-
Koyukuk/Upper Tanana region, data for Galena was not reported.
14
0%
Table 1.g Revenue ($000), 2010
By AEA Energy Regions
AEA Energy Region Residential Commercial Other Total Percent of Total
Aleutians 3,816 13,924 4,726 22,466 2%
Bering Straits
6,258
6,751
4,727
17,736
2%
Bristol Bay
6,543
11,310
5,011
22,865
2%
Copper River/Chugach
6,730
17,292
1,747
25,769
3%
Kodiak
6,368
3,932
13,782
24,081
3%
Lower Yukon-Kuskokwim
16,222
17,276
11,354
44,852
5%
North Slope
2,213
6,857
221
9,291
1%
Northwest Arctic
6,523
5,661
4,594
16,778
2%
Railbelt
244,732
244,451
147,352
636,535
69%
Southeast
37,064
35,742
18,506
91,312 10%
Yukon-Koyukuk/Upper Tanana
5,913
4,344
4,607
14,864 2%
Total
342,382
367,541
216,627
926,549
Percent of Total
37%
40%
23%
100%
Compared to 2009, 2010 revenues from electricity sales show a decrease about 4%. This is a
reflection of the decrease in the kWh sales. Distribution of revenues across energy regions
remained without significant change. The Northwest Arctic region had the highest average
revenue per residential customer per year of about $3,435, a 10% decrease from 2009;
followed by the Lower Yukon Kuskokwim region which averaged about $2,570, a 10% decrease
from 2009. The North Slope region had the lowest average revenue per residential customer
per year of about $1,020, a 4% decrease from 2009; followed by the Southeast region which
averaged about $1,160, a 2% decrease from 2009. Overall 40% of the revenues from electricity
sales came from the commercial sector because of their higher use (44% of sales, Table 1f).
15
Table 1.h Customers (Accounts), 2010
By AEA Energy Regions
AEA Energy Region
Residential
Commercial
Other
Total
Percent of Total
Aleutians
1,531
710
353
2,594
1%
Bering Straits
3,363
511
401
4,275
1%
Bristol Bay
3,008
1,006
505
4,519
1%
Copper River/Chugach
4,010
1,495
155
5,660
2%
Kodiak
4,895
1,085
139
6,118
2%
Lower Yukon-Kuskokwim
6,309
1,663
743
8,715
3%
North Slope
2,172
813
40
3,025
1%
Northwest Arctic
1,900
218
243
2,361
1%
Railbelt
211,108
29,758
615
241,481
75%
Southeast
32,057
8,273
784
41,114
13%
Yukon-Koyukuk/Upper Tanana
2,965
617
469
4,051
1%
Total
273,317
46,150
4,448
323,915
Percent of Total
84%
14%
1%
100%
As expected, the regions with the most customer accounts were the Railbelt and Southeast. All
other regions, only account for 13% of total power customers. There were no significant
changes in the number of customer accounts or regional distribution between 2009 and 2010.
Residential accounts made up most of the power customers in Alaska, about 84%. Figure 5
shows in detail the distribution of utility sales, revenue and customers by customer type.lo
io The significant differences between 2009 are 2010 figures are methodological. In 2010, industrial sales are
included in the 'Other' category. In 2009, industrial customers were included in the commercial category and
'Other' included sales to community, governmental facilities and others.
16
Figure 5. Distribution of Utility Sales, Revenue and Customers by Customer Type
100%
90
80
70
60
50
40 %
30
20%
10%
0%
Sales Revenue Customers
Other
Commercial
Residential
Utility Installed Capacity and Net Generation over time
Installed Capacity
In Alaska, utility installed capacity for power generation increased steadily between 1970s to
the late 1990s, peaking in 2001 at 2,259 MW. From 2002 to 2005 there was a steady decline to
about 1,890 MW. Since 2006, Alaska saw installed capacity growth, almost reaching 2001 levels
in 2010 with 2,189 MW.
The prime mover type with the largest share of installed capacity is combustion gas turbines,
which comprised about 36%. Hydroelectric turbines, internal combustion generators and
combined cycle gas turbines had equal shares of 20% each. Finally, steam and wind turbines
were the least common prime movers in Alaska with shares of 3% and 0.53%, respectively.
Net Generation
Since records have been available, net generation in Alaska steadily increased at an average
rate of 5% per year, except in 1998 when there was a significant drop of about 10%. Natural gas
is the most prevalent fuel used for power generation, 57% in 2010. Generation from hydro
power is the second most prevalent source of power and increased at about 5% per year. The
shares of net generation from petroleum products and coal remained stable over time, 15%
and 6%, respectively, in 2010. Since 2008, wind generation increased, though it does not
currently represent a significant share of statewide generation.
17
2,500
2,000
1,500
V
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a
v
v
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M
c
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0 '.
NI ,
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tD w tD 1- n n w w W w M M M O O O a-i
r-1 r-1 r-1 rq e-1 r-1 r-1 .--1 ei ei 'i ei ei N N N N
Figure 6. Installed Capacity by Prime Mover over Time
7000
6000
5000
L
3
c�
c 4000
0
L
d
aci 3000
t7
d
z
2000
1000
■ Combined Cycle
>• Combustion Gas Turbine
Steam Turbine
Internal Combustion
Wind Turbine
Hydro
Figure 7. Net Generation by Fuel Type over Time
Gas
Oil
Coal
Wind
Hydro
0 T I,
Cc yC�, �O Oti °�'3 y� �h �� � �i 0 `'' iP Oh 001 Ooj
ti0 ti0 ti0 10 ti� ti� ti� tiy� ,yoi y�1 'y,1,LO ,LO ,y,LO
18
Appendix A. Glossary of Terms11
Alaska Energy Authority (AEA): A public corporation of the state with a separate and
independent legal existence with the mission to construct, finance, and operate power projects
and facilities that utilize Alaska's natural resources to produce electricity and heat.
": / / _' Y Y i J.
Auxiliary Generator: A generator at the electric plant site that provides power for the
operation of the electrical generating equipment itself, including related demands such as plant
lighting, during periods when the electric plant is not operating and power is unavailable from
the grid. A black start generator used to start main central station generators is considered to
be an auxiliary generator.
Backup (Standby) Generator: A generator that is used only for test purposes, or in the event of
an emergency, such as a shortage of power needed to meet customer load requirements.
Barrel (bbl.): A unit of volume equal to 42 U.S. gallons.
Bituminous coal: A dense coal, usually black, sometimes dark brown, often with well-defined
bands of bright and dull material, used primarily as fuel in steam -electric power generation,
with substantial quantities also used for heat and power applications in manufacturing and to
make coke. Bituminous coal is the most abundant coal in active U.S. mining regions. Its
moisture content usually is less than 20%. The heat content of bituminous coal ranges from 21
to 30 million BTU per ton on a moist, mineral -matter -free basis. The heat content of
bituminous coal consumed in the United States averages 24 million BTU per ton, on the as -
received basis (i.e. containing both inherent moisture and mineral matter).
British Thermal Unit: The British thermal unit (BTU or Btu) is a traditional unit of energy equal
to about 1.06 kilojoules. It is approximately the amount of energy needed to heat 1 pound
(0.454 kg) of waterl'F (0.556'Q. It is used in the power, steam generation, heating and air
conditioning industries. In North America, the term "BTU" is used to describe the heat value
(energy content) of fuels, and also to describe the power of heating and cooling systems. When
used as a unit of power, BTU per hour (BTU/h) is the correct unit, though this is often
abbreviated to just "BTU".
Capital Cost: The cost of field development, plant construction, and the equipment required for
industry operations.
Climate Change: A term used to refer to all forms of climatic inconsistency, but especially to
significant change from one prevailing climatic condition to another. In some cases, "climate
11 U.S. Energy Information Administration glossary posted at plus multiple sources for additional
Alaska specific terms.
19
change" has been used synonymously with the term "global warming"; scientists, however,
tend to use the term in a wider sense inclusive of natural changes in climate, including climatic
cooling.
Coal: A readily combustible black or brownish -black rock whose composition, including inherent
moisture, consists of more than 50% by weight and more than 70% by volume of carbonaceous
material. It is formed from plant remains that have been compacted, hardened, chemically
altered, and metamorphosed by heat and pressure over geologic time. It is estimated that
Alaska holds about 15% of the world's coal resources, amounting to 170 billion identified short
tons. Major coal provinces include Northern Alaska, the Nenana area, Cook Inlet — Matanuska
Valley, the Alaska Peninsula, and in the Gulf of Alaska and the Bering River. Alaska coals exhibit
low metallic trace elements, good ash -fusion characteristics, and low nitrogen content making
them favorable for meeting environmental constraints on combustion in power plants.
Cogeneration system: A system using a common energy source to produce both electricity and
thermal energy for other uses, resulting in increased fuel efficiency.
Combined Cycle: An electric generating technology in which electricity is produced from
otherwise lost waste heat exiting from one or more gas (combustion) turbines. The exiting heat
is routed to a conventional boiler or to a heat recovery steam generator for utilization by a
steam turbine in the production of electricity. This process increases the efficiency of the
electric generating unit.
Combustion: Chemical oxidation accompanied by the generation of light and heat.
Commercial Sector: An energy -consuming sector that consists of service -providing facilities and
equipment of businesses; Federal, State, and local governments; and other private and public
organizations, such as religious, social, or fraternal groups. The commercial sector includes
institutional living quarters. It also includes sewage treatment facilities. Common uses of
energy associated with this sector include space heating, water heating, air conditioning,
lighting, refrigeration, cooking, and running a wide variety of other equipment. Note: This
sector includes generators that produce electricity and/or useful thermal output primarily to
support the activities of the above -mentioned commercial establishments.
Consumer (energy): Any individually metered dwelling, building, establishment, or location.
Diesel #1: Also known as DF1 or Jet A. Diesel #1 is commonly used as heating fuel throughout
most of northern rural AK. Diesel #1 has a lower gel temperature than Diesel #2 which is sold
for heating fuel in warmer climates. Diesel #1 is same fuel the refineries sell as Jet fuel (Jet A),
and in many tank farms it is stored as Jet A until sold as DF1.
Diesel #2: Is commonly used throughout the US. In Alaska it is used for marine and highway
diesel as well as heating fuel in warmer regions. Diesel #2 is preferred over #1 where it is warm
enough as it has higher energy content.
20
Diesel Fuel: A fuel composed of distillates obtained in petroleum refining operation or blends of
such distillates with residual oil used in motor vehicles. The boiling point and specific gravity
are higher for diesel fuels than for gasoline.
Distillate Fuel Oil: A generic name for a refined petroleum product. It can refer to diesel,
heating fuel or jet fuel.
Electricity: A form of energy characterized by the presence and motion of elementary charged
particles generated by friction, induction, or chemical change.
Energy Balance: The difference between the total incoming and total outgoing energy. When
the energy budget is balanced, the system neither gains nor loses energy.
Energy Information Agency (EIA): An independent agency within the U.S. Department of
Energy that develops surveys, collects energy data, and analyzes and models energy issues.
http://www.eia.doe.gov/
Exports: Shipments of goods from within the 50 States and the District of Columbia to U.S.
possessions and territories or to foreign countries.
Fuel: Any material substance that can be consumed to supply heat, power, or mechanical
energy. Included are petroleum, coal, and natural gas (the fossil fuels), and other consumable
materials, such as uranium, biomass, and hydrogen.
Furnished without payment (power): The amount of electricity furnished by the electric utility
without charge, such as a municipality under a franchise agreement or for public street and
highway lighting. It does not included energy consumed by the utility.
Gallon: A volumetric measure equal to four quarts (231 cubic inches) used to measure fuel oil.
Gas: A non -solid, non -liquid combustible energy source that includes natural gas, coke -oven
gas, blast -furnace gas, and refinery gas.
Grid: The layout of an electrical distribution system.
Gross Domestic Disposition: The total amount of energy available for sale in the domestic
region, i.e. energy produced for sale in the domestic region in addition to energy imported for
sale within the domestic region.
Gross Extraction: The total amount of fuel obtained or produced by a power production plant.
Gross Generation: The total amount of electric energy produced by generating units and
measured at the generating terminal in kilowatt-hours (kWh) or megawatt hours (MWh).
21
Heating Degree Days (HDD): A measure of how cold a location is over a period of time relative
to a base temperature, most commonly specified as 65 degrees Fahrenheit. The measure is
computed for each day by subtracting the average of the day's high and low temperatures from
the base temperature (65 degrees), with negative values set equal to zero. Each day's heating
degree days are summed to create a heating degree day measure for a specified reference
period. Heating degree days are used in energy analysis as an indicator of space heating energy
requirements or use.
Hydroelectric Power: The use of flowing water to produce electrical energy.
Imports: Receipts of goods into the 50 States and the District of Columbia from U.S. possessions
and territories or from foreign countries.
Industrial Sector: An energy -consuming sector that consists of all facilities and equipment used
for producing, processing, or assembling goods. The industrial sector encompasses the
following types of activity: manufacturing, agriculture, timber harvest and wood processing,
fishing and fish processing, hunting, mining, oil and gas extraction, and construction. Overall
energy use in this sector is largely for process heat and cooling and powering machinery, with
lesser amounts used for facility heating, air conditioning, and lighting. Fossil fuels are also used
as raw material inputs to manufactured products. Note: This sector includes generators that
produce electricity and/or useful thermal output primarily to support the above -mentioned
industrial activities.
Injections: Natural gas injected into storage reservoirs.
Installed Capacity: The maximum theoretical production output of a plant, based either on
nameplate capacity or actual (practically determined) capacity.
Internal Combustion: The process where fuel is burned, or combusted, inside a cylinder, such
as a diesel engine, producing power directly as opposed to fuel burning externally, such as in a
steam engine. The term internal combustion engine usually refers to an engine in which
combustion is intermittent, such as the more familiar four-stroke and two-stroke piston
engines. A second class of internal combustion engines uses continuous combustion: gas
turbines, jet engines and most rocket engines.
Kilowatt-hour (kWh): A unit of energy equal to one kW applied for one hour; running a one kW
hair dryer for one hour would dissipate one kWh of electrical energy as heat. Also, one kWh is
equivalent to one thousand watt hours.
Kilowatt (kW): One thousand watts of electricity (See Watt).
Load (Electric): Amount of electricity required to meet customer demand at any given time.
22
MCF: One thousand cubic feet.
Megawatt (MW): One million watts of electricity (See Watt).
Mining: An energy -consuming subsector of the industrial sector that consists of all facilities
and equipment used to extract energy and mineral resources.
Nameplate Capacity: The maximum rated output of an electric power production unit (i.e.
generator, prime mover) under specific conditions designated by the manufacturer. Capacity is
usually indicated on a nameplate physically attached to the generator.
Natural Gas: Gas in place at the time that a reservoir was converted to use as an underground
storage reservoir in contrast to injected gas volumes.
Net Capacity: The maximum load that an electrical apparatus (i.e. generating unit or station)
can carry, not including use by the electrical apparatus.
Net Domestic Disposition: The total amount of energy produced in the domestic region that is
available for sale within the domestic region, i.e. not including energy use by producers or
energy exported for sale outside of the domestic region.
Net Extraction: The total amount of fuel obtained or produced by a power production plant,
not including electric energy use by the plants.
Net Generation: The amount of gross generation not including the electrical energy consumed
at the generating station(s) for station service or auxiliaries. Note: Electricity required for
pumping at pumped -storage plants is regarded as electricity for station service and is deducted
from gross generation.
Oil: A mixture of hydrocarbons usually existing in the liquid state in natural underground pools
or reservoirs. Gas is often found in association with oil (See Petroleum).
O&M: Operations and maintenance
Other: The "other" category is defined as representing electricity consumers not elsewhere
classified. This category includes public street and highway lighting service, public authority
service to public authorities, railroad and railway service, and interdepartmental services.
Peak: The amount of electricity required to meet customer demand at its highest. The summer
peak period begins June 15t and ends September 30th, and the winter peak period begins
December 1st and ends March 31'
Petroleum: A broadly defined class of liquid hydrocarbon mixtures. Included are crude oil,
lease condensate, unfinished oils, refined products obtained from the processing of crude oil,
23
and natural gas plant liquids. Note: Volumes of finished petroleum products include non -
hydrocarbon compounds, such as additives and detergents, after they have been blended into
the products.
Petroleum Products: Petroleum products are obtained from the processing of crude oil
(including lease condensate), natural gas, and other hydrocarbon compounds. Petroleum
products include unfinished oils, liquefied petroleum gases, pentanes plus, aviation gasoline,
motor gasoline, naphtha -type jet fuel, kerosene -type jet fuel, kerosene, distillate fuel oil,
residual fuel oil, petrochemical feedstocks, special naphthas, lubricants, waxes, petroleum coke,
asphalt, road oil, still gas, and miscellaneous products
Plant: A term commonly used either as a synonym for an industrial establishment or a
generating facility or to refer to a particular process within an establishment.
Power: The rate of producing, transferring, or using energy that is capable of doing work, most
commonly associated with electricity. Power is measured in watts and often expressed in
kilowatts (kW) or megawatts (MW).
Power Cost Equalization Program (PCE): Participating utilities receive state funding to reduce
the charge to consumers in rural areas where prices can be three to five times higher than
prices in urban areas.
Prime Mover: The engine, turbine, water wheel, or similar machine that drives an electric
generator; or, for reporting purposes, a device that converts energy to electricity directly (e.g.
photovoltaic solar and fuel cells).
Prime Mover Prime Mover Description (U.S. EIA)
Code
ST........... Steam Turbine, including nuclear, geothermal and
solar steam (does not include combined cycle)
GT........... Combustion (Gas) Turbine (includes jet engine design)
IC........... Internal Combustion Engine (diesel, piston)
CA........... Combined Cycle Steam Part
CT........... Combined Cycle Combustion Turbine Part
CS........... Combined Cycle Single Shaft (combustion turbine and
steam turbine share a single generator)
CC........... Combined Cycle -Total Unit
HY........... Hydraulic Turbine (includes turbines associated with
delivery of water by pipeline)
PS........... Hydraulic Turbine — Reversible (pumped storage)
BT........... Turbines used in a binary cycle such as geothermal
PV........... Photovoltaic
WT........... Wind Turbine
CE........... Compressed Air Energy Storage
24
FC........... Fuel Cell
OT........... Other
NA........... Unknown at this time (use only for plants/generators
in planning stage)
Pro Forma: A Latin term means "for the sake of form," it describes a method of calculating
financial results in order to emphasize either current or projected figures.
Purchased Capacity: The amount of energy and capacity available for purchase from outside
the system.
Railbelt: The portion of Alaska that is near the Alaska Railroad, generally including Fairbanks,
Anchorage, the communities between these two cities, and the Kenai Peninsula.
Refinery: An installation that manufactures finished petroleum products from crude oil,
unfinished oils, natural gas liquids, other hydrocarbons, and oxygenates.
Reinjected: The forcing of gas under pressure into an oil reservoir in an attempt to increase
recovery.
Renewable Energy Fund (REF): Established by the Alaska State Legislature and administered by
the Alaska Energy Authority to competitively award grants to qualified applicants for renewable
energy projects.
Renewable Energy Resources: Energy resources that are naturally replenishing but flow -
limited. They are virtually inexhaustible in duration but limited in the amount of energy that is
available per unit of time. Renewable energy resources include biomass, hydro, geothermal,
solar, wind, ocean thermal, wave action, and tidal action.
Residential Sector: An energy -consuming sector that consists of living quarters for private
households. Common uses of energy associated with this sector include space heating, water
heating, air conditioning, lighting, refrigeration, cooking, and running a variety of other
appliances. The residential sector excludes institutional living quarters.
Residual Fuel Oil: A general classification for the heavier oils that remain after the distillate fuel
oils and lighter hydrocarbons are distilled away in refinery operations. It is used in steam -
powered vessels in government service and inshore power plants, and can be issued for the
production of electric power, space heating, vessel bunkering, and various industrial purposes.
Revenue (Electricity): The total amount of money received by an entity from sales of its
products and/or services; gains from the sales or exchanges of assets, interest, and dividends
earned on investments; and other increases in the owner's equity, except those arising from
capital adjustments.
25
Short Ton: A unit of weight equal to 2,000 pounds.
Space Heating: The use of energy to generate heat for warmth in housing units using space -
heating equipment. It does not include the use of energy to operate appliances (such as lights,
televisions, and refrigerators) that give off heat as a byproduct.
Steam: Water in vapor form; used as the working fluid in steam turbines and some heating
systems.
Transmission System (Electric): An interconnected group of electric transmission lines and
associated equipment for moving or transferring electric energy in bulk between points of
supply and points at which it is transformed for delivery over the distribution system lines to
consumers, or is delivered to other electric systems.
Tonne (Ton): A unit of mass equal to 1,000 kilograms or 2,204.6 pounds, also known as a metric
ton.
Total Disposition: The total amount of sold or transferred energy.
Turbine: A machine for generating rotary mechanical power from the energy of a moving force
(such as water, hot gas, wind, or steam). Turbines convert the kinetic energy to mechanical
energy through the principles of impulse and reaction, or a mixture of the two.
U.S. Department of Energy (DOE): Oversees programs, such as Wind Powering America, with
the mission to advance national, economic, and energy security; promote innovation; and
ensure environmental responsibility. http://www.energy.gov/
Watt (Electric): The electrical unit of power. The rate of energy transfer equivalent to one
ampere of electric current flowing under a pressure of one volt at unity power factor.
Watt (Thermal): A unit of power in the metric system, expressed in terms of energy per second,
equal to the work done at a rate of one joule per second.
Watt hour (Wh): The electrical energy unit of measure equal to one watt of power supplied to,
or taken from, an electric circuit steadily for one hour.
26
BER➢NG
STRAITS
r
ALERT g_
Appendix B. Maps of Energy Regions
Figurel. Alaska Energy Statistics 2003 Regions
Arctic & Northwest
r
Yukon
Southwest
Southcentral
Figure 2. Native Corporation Regions
SLOPEARCTtC
IF
DOYON
.CAM INLET
C1lLISTA
'
WSTOL
E CHUGACH
SAY
R0
.
KONIAG
Source: First Alaskans Institute
27
Southeast c
SEALASKA
Figure 3. Alaska Census Area Map
Alaska Borough & Census Area Boundaries - 2008
wm.1.6+p„ .w.arwy■+■n
w�
- e:..iyeResar...e..srts
a 1
`may - r■.n..n
ce..
lzoar
s
...
a
O-W
A.
0
e
Source: 2000 Census, Alaska Department of Labor and Workforce Development
Figure 4. Alaska Energy Regions Map
i
Alaska Energy Regions
'�. IdretYW.unJ:wkWrk�l �1
r
-v�3ir1 CI[p
Source: Alaska Energy Authority
28
Appendix C. Data Sources for Electric Energy Statistics
The primary data source for the electric power statistics are the U.S. Department of Energy
(DOE), Energy Information Administration (EIA) and the Alaska Energy Authority, Power Cost
Equalization program data. Every utility and industrial (including military) electrical generating
facility with a capacity greater than one megawatt is required to report their operating
characteristics to the EIA annually, and in some instances, monthly. This information is
compiled by the EIA and is available for every generating facility on their website:
(http:/Iwww.eia.doe.gov/ The forms of interest to compile this publication are the EIA 860,
861 and 923. These are reporting forms for capacity, generation, sales and revenues.
The use of the EIA database is a continuation of the methodology used in the 2008 and 2009
Alaska Electric Power Statistics update, however with some modifications in order to publish
this report more timely. Most utilities and industrial facilities are required by law to report to
the federal government each year on their activities using the EIA forms; this information is
then made available on the EIA website. This process causes a delay; the lag time for the
availability of the federal data is approximately two years. However, it is redundant to collect
the same information through a second questionnaire. Respondents are required by law to
report to the EIA and this should make the response rate high. In order to expedite this process,
the Alaska Energy Authority collected copies of the CY2010 EIA forms from a selective group of
utilities, and created a reduced data set.
Nonetheless, using EIA data poses some challenges because not all information reported in this
publication is collected via the EIA forms. First, the smallest utilities with installed capacity less
than one megawatt are not required to report to EIA and are not included in the EIA database.
Second, not all Alaska generating facilities report as required by law.
These forms collect data at different levels of aggregation; for example some at the utility level
only, while other data may be at the facility and/or generator level. This sometime causes
differences in the underlying definition of the data making reconciliation of the information in
the datasets within forms, and across the different forms sometimes difficult.
To supplement missing data we used the database for the annual Power Cost Equalization
Reports by the Alaska Energy Authority (AEA). Also, as needed, the Alaska Energy Authority and
ISER supplemented these data sources by contacting utilities directly.
These data sources allowed us to collect information for almost all the utilities in the state
without incurring the considerable cost of conducting a complete census of all producers. A
few of the smallest utilities that were not either in the EIA database or the Power Cost
Equalization database did not provide information for this report.
The 2010 Power Cost Equalization data provided data on the generation and sales (residential
and commercial) of all utilities participating in the Power Cost Equalization program, including a
breakdown by community for those utilities that operate in multiple communities, such as
Alaska Village Electric Cooperative (AVEC) and Alaska Power and Telephone (AP&T). The EIA
29
data for these utilities was in some cases reported only as a total across all communities, and
we used this as control totals. AEA, AVEC, AP&T and NSPL provided helpful assistance in
supplying installed capacity information for each plant not originally included in the PCE
database. In this case we were able to publish information taken directly from the utility
reflecting statistics from each of its serviced communities.
The PCE database contains information collected through AEA's PCE Utility Monthly Report
which PCE participants must file. Utilities also report to the RCA annually for fuel cost
adjustments. Reporting to both entities should be consistent, however discrepancies are not
unusual. These discrepancies may be due to high turnover in small utilities, poor reporting and
limited staff to verify the utilities' self -reported data.
In addition, there are data (energy loss, use by facility and energy provided without charges)
that is not included in the PCE report. Because of this, the values found in table 2.2a may not
reflect a summation of all AP&T communities as reported in the PCE report. Rather they reflect
what was reported to the EIA directly as prepared by the utility itself. This same methodology
was implemented in the sales and revenues tables (2.4a) when deemed appropriate. The
intent is to create as comprehensive of a table as possible.
The summary information in the historical tables was calculated from the same sources
mentioned above. Data from these sources was calculated and re -formatted where appropriate
and consolidated into master data files from which all the tables in this report where built.
Inevitably the use of multiple data sources introduces some inconsistencies in reporting.
Notwithstanding, we believe that the Alaska Electric Power Statistics 2010 update report
provides useful information on the state of electric power generation in Alaska.
30
Appendix D. Reporting Requirements
Energy Information Administration
Every utility facility with a capacity greater than one megawatt (MW) is required to report their
operating characteristics to the US Department of Energy (DOE), Energy Information
Administration (EIA) annually, and in some instances, monthly. This information is compiled by
the EIA and is available for every generating facility on their website (http://www.eia.doe.gov ).
Specific reporting requirements are determined by the Department of Energy but collected,
assembled, and evaluated by the EIA according to the Federal Energy Administration Act of
1974. We obtained data for year 2010. Three EIA forms were used in this report:
EIA-860 Annual Electric Generator Report. This report contains information on capacity
and types of fuel used. It is completed by all existing plants and proposed (5-year plans)
plants that: 1) have a total generator nameplate capacity (sum for all generators at a
single site) of one MW or greater; and 2) where the plant is connected to the local or
regional electric power grid and has the ability to draw power from the grid or deliver
power to the grid.
EIA -860M Monthly Update to the Annual Electric Generator Report. This report
contains monthly updates to the EIA-860. It is completed by those who also completed
EIA-860 and additionally indicated a proposed change in generator production within
one month of the report period. The proposed change may be due to: 1) a new
generator scheduled to start commercial operation; 2) an existing generator scheduled
to retire from service; or 3) an existing generator with a proposed modification
scheduled.
EIA-861 Annual Electric Power Industry Report. This report contains information on
peak production, net generation, sales, and revenues. It is completed by electric
industry distributors including: electric utilities, wholesale power marketers (registered
with the Federal Energy Regulatory Commission), energy service providers (registered
with the Regulatory Commission of Alaska), and electric power producers.
• EIA-923 Power Plant Operations Report. This report contains information on electric
power generation, fuel consumption, fossil fuel stocks, and fossil fuel cost and quality. It
is completed by all electric power plants that: 1) have a total generator nameplate
capacity (sum for generators at a single site) of one MW or greater; and 2) where the
plant is connected to the local or regional electric power grid and has the ability to draw
power from the grid or deliver power to the grid.
31
Power Cost Equalization Program and Regulatory Commission of Alaska
Participants of the Power Cost Equalization (PCE) program report to the Regulatory Commission
of Alaska (RCA) for fuel cost adjustments to their rates. The RCA has authority to maintain
accounts and records of public utilities that fall under its jurisdiction, under Alaska Statute
42.05.451. This responsibility allows the Regulatory Commission of Alaska to obtain
information from regulated utilities. Additionally, all utilities that serve ten or more customers
must obtain an operating certificate, which describes the authorized service area and scope of
operations of the utility. The RCA will issue a certificate when it finds the utility to be fit,
willing, and able to provide the service. The RCA maintains a list of both regulated and
unregulated certified utilities. Utilities report annually to the RCA, but file a PCE Utility Monthly
Report with AEA.
32
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