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Alaska’s Renewable Energy Future: New Jobs, Aordable Energy
Endnotes
1 The combination of Onshore and Oshore Wind Energy
potential alone, in and around Alaska, has been estimated
to be on the order of 37,753 TWh/yr (onshore) + 10,043 TWh/
yr (oshore) for a total of 47,796 TWh/year which is 14 times
the total U.S. energy consumption of 3,397 TWh/yr (EIA, U.S.
Energy Consumption, 2020, 11.59 Quads). Onshore wind
energy potential estimate from Onshore wind energy atlas
for the United States accounting for land use restrictions and
wind speed thresholds, von Krauland, et al, Smart Energy,
3 (2021), 100046. Oshore wind energy potential estimate
from Oshore Wind Energy Resource Assessment for Alaska,
Doubrawa, et al, Golden, CO: NREL, December 2017.
2 The net zero emissions by 2050 target derives from The
Intergovernmental Panel on Climate Change (IPCC) Special
Report on Global Warming of 1.5°C which points to the need for
carbon neutrality by mid‐century (2050).
3 We asked local Alaska energy sector consultant Mark Foster
(MAFA), to review multiple recent studies on the local Alaska
employment potential of transitioning the Alaska energy sector
to 100% clean renewables. He reviewed four studies (JH
Williams et al, Carbon Neutral Pathways for the United States,
AGU Advances, Research Article 10.1029/2020AV000284, 12
Nov 2020; Cadmus, Alaska’s Renewable Energy Future: New
Jobs, Aordable Energy, December 2021; MZ Jacobson et al,
Zero Air Pollution and Zero Carbon from All Energy Without
Blackouts at Low Cost in Alaska, December 7, 2021; McKinsey,
The Net-Zero Transition: What it would cost, what it could
bring, January 2022) for their investment, benefits, jobs and
economic impact estimates and adjusted their estimated costs
and benefits to reflect local Alaska capital, operating, fuel costs
and energy systems performance and extended those results
through the NREL Jobs and Economic Impact (JEDI) models to
derive estimates of the jobs potential of a transition to 100%
clean renewables.
4 For an illustrative example of the basis for the job estimates,
MAFA adjusted the Jacobson job estimates Table 14. Changes
in Employment, Zero Air Pollution and Zero Carbon From All
Energy Without Blackouts at Low Cost in Alaska, Professor
Mark Z. Jacobson, Stanford University, December 7, 2021.
https://web.stanford.edu/group/efmh/jacobson/Articles/I/21-
USStates-PDFs/21-WWS-Alaska.pdf
The MAFA job estimates were developed based on Alaska
capital and operating costs [which ran from 25% to 225%
above the continental United States (hereinafter CONUS) basis
used by Jacobson] and rerun the resulting cost estimates
through the JEDI models for each respective renewable energy
technology. The result is an increase in local Alaska jobs from
82,843 to 103,554 which are oset by the Jacobson identified
anticipated loss of 36,338, for a net gain on the order of 67,216
jobs. MAFA notes that this may be a conservative figure in
light of the estimated magnitude of the capital investment
associated with the construction of the infrastructure to support
a transition to 100% clean renewable energy of roughly $128
billion (2020$) over 30 years. This is roughly comparable to
building the equivalent of the TransAlaska Pipeline System
($32 billion in 2020$) every 8 years.
5 See HB 301 and SB179, “Legislation setting Renewable Energy
Standard benchmarks to prepare the Railbelt for energy
independence”, introduced by Governor Dunleavy on February
4, 2022.
6 MAFA has reviewed the detailed renewable energy and energy
storage capacity requirements and associated capital cost
estimates of Jacobson (2021) and Williams (2020) and adjusted
each of the studies to reflect Alaska renewable energy
resource development costs *across Alaska* [Railbelt + Rural].
The net result is a 100% clean renewable energy investment
portfolio estimate on the order of $128 billion over 30 years.
7 The magnitude of the challenge to transition the energy
system from fossil fuels to 100% clean renewables, on the
order of 0.9% of Alaska GDP by 2050 [MAFA adjusted estimate
from J.H. Williams, et al (2020)], suggests substantive federal
support is in order. As Alaska (and Midwest to Western States)
well know, the Rural Electrification Administration and its
successor the Rural Utility Service of the Federal Government
have been essential in enabling rural America to construct
electric, telecommunications and water/sewer infrastructure
and transform rural America. Similarly, Eisenhower’s Interstate
Highway System launched by the Interstate Defense Highway
Act of 1956, has been an essential source of support for the
development of Alaska as well as the Midwest and Western
states. Using the Interstate Highway System funding model,
we might anticipate a state federal funding ratio of 1:9 for
the roughly 25% public co-investment estimated to bring the
total cost of energy in Alaska to be comparable to the long
run projections for fossil fuels [Williams (2020) Reference
Case, EIA AEO 2021 Outlook, Jacobson (2021), McKinley
(2022)] adjusted to reflect Alaska price outlook compared to
CONUS, e.g., Cook Inlet natural gas prices have been high and
trending upward compared to CONUS and rural Alaska diesel
and gasoline prices remain high. Starting with an estimated
total capital investment of $128 billion [roughly 4X TAPS in
2020$], 25% public funding = $32 billion of which the State of
Alaska:Federal match of 1:9 would yield a State of Alaska co-
investment of $3.2 billion.
8 See for example the collaboration between CDP and CALPERS
to ensure that CALPERS investments were assessing their
environmental footprints and associated risks.
9 For a comprehensive guide to utility IRPs, see the Renewable
Assistance Project / Institute for Market Transformation,
“Participating in Power: How to Read and Respond to
Integrated Resource Plans”, Duncan, et al, October 13, 2021.
In addition, a panel of practitioners in the field provided an
instructive update of recommendations for processes that
consider all available resources, align the plan process with
policy objectives and sort options to emphasize “least-regrets”
outcomes in “Building a Next-Generation Mix of Energy
Resources: Practical Perspectives”, Baak, et al, December
2, 2021, available at: https://www.raponline.org/event/
building-a-next-generation-mix-of-energy-resources-practical-
perspectives/ .
The integrated resource plans should not only include
consideration of future fossil fuel price escalation, but also
include explicit consideration for fossil fuel price volatility
and its attendant stress on household budgets compared for
example to the long term stability in the price of renewable
energy resources exemplified by residential electric rates in
Public Utilities District No. 1 of Douglas County, Washington
where the EIA 2020 Utility Bundles Sales to Ultimate
Consumers - Residential indicates an average price of 3.08
cents per kWh, a slow steady increase in nominal rates of
2.3% per year since 1994 (EIA earliest data currently available
on their web site, page 74 EIA/Electric Sales and Revenue,
1994), within 18 basis points of the consumer price index-
urban for the U.S. over the same time period without any
substantive volatility. In stark contrast, the price of diesel
/ home heating fuel rapidly rose from 2000-2008 and
bounced around, dropped from 2013 through 2016, then has
been rapidly escalating again in 2021/2022. Meanwhile the
prevailing price of natural gas in the Cook Inlet has been
steadily trending upward for the past ten years while CONUS
prices through 2019 were falling. While CONUS natural gas
prices have increased due in part to international LNG market
developments, the NYMEX natural gas futures outlook remains
downtrending following short term shortage and uncertainties.
In contrast, the State’s most recent study of Cook Inlet Natural