Washington State Electric Utility Resource Planning 2024 Report — Report to the Legislature (December 2025)
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Summary
The Washington State Electric Utility Resource Planning 2024 Report, a report to the Legislature dated December 2025 from the Energy Policy Office of the Washington State Department of Commerce. Required biennially per RCW 19.280.060, it summarizes load and resource data from Washington utilities' 2024 resource plans over a 10-year planning cycle, with most utilities using 2023 as the base year, and states that Commerce received reports from 61 utilities. The key findings state that utilities plan to reduce coal-fired generation and market purchases and increase hydropower, wind and utility-scale solar, and that the Mid-Columbia utilities forecast significant load growth from data centers. Table 1 reports statewide loads of 10,189 aMW in the base year and 12,245 aMW in the 10-year forecast. The report also covers overgeneration and resource adequacy and closes with a glossary of terms.
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“Washington State Electric Utility Resource Planning 2024 Report — Report to the Legislature (December 2025).”
Original at app.leg.wa.gov. Archived at Pandemic Darlings, https://pandemicdarlings.com/source-documents/2025-washington-state-electric-utility-resource-planning-2024-report-final/
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Washington State Electric
Utility Resource Planning
2024 Report
December 2025
Report to the Legislature
ENERGY POLICY OFFICE Director Joe Nguyễn
v4
Acknowledgments
Washington State Department of Commerce
Aaron Tam
Electric and Natural Gas Data Specialist
Glenn Blackmon
Director, Energy Policy Office
Austin Scharff
Senior Energy Policy Specialist
1011 Plum St. SE
P.O. Box 42525
Olympia, WA 98504-2525
www.commerce.wa.gov
For people with disabilities, this report is available on
request in other formats. To submit a request, please call
7-1-1 and ask to be connected to 360-725-4000.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 2
Table of contents
Executive summary .............................................................................................................................................4
Introduction ........................................................................................................................................................6
Utility reporting ...................................................................................................................................................7
Results ...............................................................................................................................................................8
Overgeneration ................................................................................................................................................. 19
Resource adequacy ........................................................................................................................................... 20
Appendix A: Utility cover sheets ........................................................................................................................ 23
Appendix B: Washington utility customer count, revenue, sales, and average price............................................. 24
Appendix C: Glossary of terms .......................................................................................................................... 28
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 3
Executive summary
Overview
Chapter 19.280 RCW requires electric utilities develop resource plans to assess their specific future load and
resource requirements. The Department of Commerce is tasked with collecting and analyzing the utility resource
plans and creating a summary report for the Legislature. 1
This report is required biennially per RCW 19.280.060, which states:
The department shall review the plans of consumer-owned utilities and investor-owned utilities, and data
available from other state, regional, and national sources, and prepare an electronic report to the legislature
aggregating the data and assessing the overall adequacy of Washington's electricity supply. The report shall
include a statewide summary of utility load forecasts, load/resource balance, and utility plans for the
development of thermal generation, renewable resources, conservation and efficiency resources, and an
examination of assessment methods used by utilities to address overgeneration events. The commission shall
provide the department with data summarizing the plans of investor-owned utilities for use in the department's
statewide summary. The department shall submit any reports it receives of existing and potential combined
heat and power facilities as reported by utilities to the Washington State University extension energy program
for analysis. The department may submit its report within the biennial report required under RCW 43.21F.045.
Key findings
This report collects and summarizes data from Washington state utilities' 2024 resource plans. The 2024 Utility
Resource Plan Report summarizes the findings of Washington state load and resource information for a 10-year
planning cycle — with most utilities using 2023 as the base year. This report does not reflect state or federal policy
changes post-2024. Key findings of the 2024 Utility Resource Plan report are:
Utilities plan to reduce their use of coal-fired electricity generation and market purchases serving Washington
retail customers in the forecast periods, and to increase their use of hydropower, wind power, and utility-scale
solar. Hydropower will remain the dominant source of electric for Washington utilities over the 10-year forecast
period.
Following successive years of stagnant or declining load forecasts, many utilities anticipate modest load growth
driven by population growth and transportation and building electrification over the next five to ten years. In
addition, the Mid-Columbia utilities (Grant, Douglas, and Chelan public utility districts) forecast significant load
growth from data centers.
Utilities anticipate a decline in savings potential from energy efficiency and conservation compared to past
resource plans due to building and appliance codes and standards, market saturation of efficient technologies,
and load growth from electrification.
Most utilities plan to meet load requirements in the lowest-cost, least-risk way by renewing Bonneville Power
Administration contracts (for slice or block products or shifting to a load-following product), pursuing new
renewable resources, and maximizing energy conservation measures. While several consumer-owned utilities plan
to remove natural gas from their resource portfolios in the next five and ten years, investor-owned utilities plan to
maintain relatively steady amounts of natural gas in their resource portfolio.
1 Section 19.280.060, Department's duties—Report to the legislature. (2025). Retrieved from Revised Code of Washington:
https://app.leg.wa.gov/RCW/default.aspx?cite=19.280.060.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 4
Assessments of resource adequacy from regional experts conclude the Northwest has adequate resources to
meet current demand for electricity and does not face a significant risk of outages in the near term. However, these
assessments assume the industry will be able to execute their planned capacity expansions. Confidence in these
assessments is also limited by the increasing level of uncertainty that planners face about future demand for
electricity. The sources of this uncertainty include the added volatility of our weather, the pace of consumer
conversion to electricity for transportation, heating and other end uses, changing federal and state policies, and the
growing energy demands of data centers.
The Clean Energy Transformation Act (CETA), Washington's 100% clean electricity law, includes requirements for
utilities to establish specific standards for resource adequacy and incorporate those standards into their planning
and compliance. While resource adequacy is an obligation of each electric utility serving end use customers in the
state, it also is a shared responsibility of the overall electric power system and the entities that operate, plan,
regulate, design, and fund the generation, transmission, and delivery of that system. As utilities reduce reliance on
coal-fired and gas-fired power plants and add variable renewable energy such as wind and solar, new approaches
and resources will be required to maintain resource adequacy to ensure reliable service to customers. It is equally
important to incorporate risks associated with fossil generating resources, including fuel supply risk and weather-
driven forced outage risks.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 5
Introduction
Background
Washington consumers and businesses depend on electricity service from more than 60 electric utilities operating
in this state. These utilities vary greatly in size, geographic scope, history and governance, but each is responsible
for ensuring an adequate supply of an essential resource.
Washington law requires each utility to plan for the future by examining the projected amounts of electricity that
will be required by customers in the coming decade and identifying the power resources that will be used to meet
those demands.2 Each utility must prepare a report every two years and submit it to Commerce. Commerce
reviews the utility reports and submits a summary to the Legislature. This is the ninth report since the Legislature
enacted the resource planning law in 2006. This report collects and summarizes data from Washington state
utilities' 2024 resource plans. Data collection was completed in early 2025.
Depending on their size and power sources, utilities submit either a resource plan (RP) or an integrated resource
plan (IRP). The RP is a short-form report of load 3 and resources and may be submitted only if the utility has fewer
than 25,000 customers or is a full requirements customer" 4 of Bonneville Power Administration. The IRP is a more
detailed plan and must incorporate a number of specific requirements identified in statute.
Purpose
Utilities develop resource plans to assess their future load and resource situations. This report aggregates the
individual utility submittals to provide an assessment at the statewide level of whether utilities are planning for
adequate supplies, and what resources are expected to meet any growth in electric power demand. The Legislature
has asked Commerce to provide this review and oversight of the resource planning process so that they can
understand and assist in meeting the state's electricity needs.
This report summarizes the electricity loads and resources reported by Washington utilities in their 2024 reports to
Commerce. It compares them to estimated summaries of previous years. Resources proposed to meet load are
categorized by generating fuel type and source type, i.e. "hydropower" or "market purchase." An imbalance of loads
and resources may indicate either a resource surplus or deficit.
The information collected for this report is limited to the identification of loads and resources and their associated
aggregate quantities. It does not attempt to evaluate specific goals or outcomes for resource acquisition strategies
used by utilities.
This report provides information on utilities’ energy efficiency and renewable energy resources. It does not analyze
issues related to the energy efficiency and renewable energy requirement of, or compliance with, the Energy
Independence Act (Chapter 19.285 RCW) or the Clean Energy Transformation Act (Chapter 19.405 RCW). It also
does not evaluate the impacts of new state or federal policies after 2024 which may contradict the assumptions
utilized in the utility resource plans, regional resource adequacy assessments, or regional forecasts summarized in
this report.
2 Chapter 19.280, Electric Utility Resource Plans. (2025). Retrieved from Revised Code of Washington
3 As used in the statute and this report, “load” means the amount of electric energy demanded by a utility’s customers during a defined
period.
4 "Full requirements customer" as defined in Section 19.280.020(7) means an electric utility that relies on the Bonneville Power
Administration for all power needed to supply its total load requirement other than that served by nondispatchable generating resources
totaling no more than six megawatts or renewable resources.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 6
Utility reporting
The utility resource planning statutes (Chapter 19.280 RCW) require that each utility prepare a resource plan (RP)
and submit it to Commerce by Sept. 1 of each even-numbered year. Commerce received reports from 61 5 utilities.
The individual reports are presented in Appendix A: Utility cover sheets. A summary of electricity sales to
customers is presented in Appendix B: Washington utility customer count, revenue, sales, and average price. A
glossary of terms is provided in Appendix C: Glossary of terms.
Electric utilities in Washington vary significantly in size and the scope of operations. This is reflected in the way
utilities approach resource planning and forecasting. Larger utilities typically use multiple sources of electricity
supply to meet their customers’ requirements and engage in sophisticated assessments of risks and benefits in
evaluating alternative sources of new energy. Many smaller utilities rely on the Bonneville Power Administration,
which undertakes the complex planning and forecasting exercise that leads to a resource plan.
The resource planning statute reflects this difference in approaches. As mentioned previously, it requires that
larger utilities prepare and submit IRPs, which are the product of a thorough assessment of future needs and
alternatives for meeting those needs through both demand-side and supply-side resources. Smaller utilities are
allowed to prepare and submit a simplified assessment of loads and resources.
Interpretation of base year, five-year and 10-year data
The resource plan summary submitted to Commerce includes load and resource information for three points in a
10-year planning cycle. These points are the base year, five-year and 10-year plans. In 2024, most utilities used
2023 as the base year, and the five-year and 10-year points are 2028 and 2033, respectively. However, utilities vary
in their planning cycles, and some utilities use an earlier or later set of years in their reporting; the base year ranges
from 2022 to 2024. For purposes of the statewide summary, Commerce aggregates all base-year data into a single
value (2023) and does likewise for the five-year (2028) data and 10-year data (2033).
Interpretation of conservation and load data
An important principle of integrated resource planning is that all resources should be evaluated on a consistent
basis. This includes different generating resources, such as wind and natural gas, as well as energy conservation
measures and demand response resources. With energy conservation measures and demand response being
analyzed and compared to supply-side options, utilities determine whether customers are better served by
increasing energy efficiency, demand reduction, or energy supply. Consequently, energy conservation measures are
sometimes portrayed as a reduction in the utility’s load and sometimes portrayed as resources available to meet
load. This can lead to confusion in interpreting utility plans.
Here is how this potential confusion is resolved:
Utilities report a base year load amount that reflects whatever conservation has occurred in the past. For the
five-year and 10-year values, utilities are directed to report the load that they would expect to serve in the
absence of any additional conservation savings, demand response, and behind-the-meter solar (BTM solar).
The report separately lists the conservation resources, demand response, and BTM solar that the utility
expects during the five-year and 10-year periods.
5 Commerce did not receive a resource plan coversheet from Consolidated Irrigation District #19 for 2024.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 7
In summary, the amounts reported as load for the five-year and 10-year intervals are based on an assumption of no
new conservation, demand response, or BTM solar. The actual loads at these future time points are likely to be
lower by the amount of energy conservation, demand response, and BTM solar identified by each utility.
Results
The 2024 resource plans submitted to Commerce are summarized in Table 1-4 and Figures 1-2.
Table 1 presents utility report information in units of average-Megawatts (aMW) 6 on statewide annual utility load
and resources, including imports and exports, for the base year (2023), and the five and 10-year forecasts. The right
two columns in the table illustrate the difference between the base year and the five and 10-year forecasts. Table 1
also presents the composition of electric generation resources for the base year, and the five and 10-year
forecasts. Table 1 shows the five and 10-year forecast for load growth is nearly double the amount presented from
two years ago, most of which comes from data center load growth in Chelan, Grant, and Douglas counties.
In this year of reporting, Commerce asked utilities to disaggregate "other renewable resources." We can see that
the use of biomass and utility-scale solar was nearly equal in the base year (55 and 56 aMW respectively), but
utilities are expecting substantial growth in utility-scale solar in the next five to 10 years as the use of biomass
resources remains steady.
Table 1: Washington's projected requirements and resources - annual energy aMW
Requirements Base Year 5-year Forecast 10-year Forecast 5-year Change 10-year Change
Loads 10,189 11,316 12,245 1,128 2,057
Exports 746 513 423 (234) (323)
Energy Conservation Measures No data (336) (790) (336) (790)
Demand Response No data (42) (57) (42) (57)
BTM Solar 0 (26) (52) (26) (52)
Total Net Requirements 10,935 11,425 11,770 490 835
Resources Base Year 5-year Forecast 10-year Forecast 5-year Change 10-year Change
Total BPA 4,511 4,844 4,985 333 474
Hydro 3,044 3,513 3,878 469 834
Thermal Natural Gas 1,101 1,206 855 105 (246)
Market Purchases 934 327 132 (607) (802)
Thermal Coal 450 No data No data (450) (450)
Other 850 196 161 (654) (689)
Wind 811 1,059 1,625 248 814
Imports 237 259 301 22 64
Cogeneration 2 2 2 No data No data
Biomass 55 62 62 7 7
6 aMW, or average megawatt, is an amount of electric energy equal to one megawatt-hour per hour for an entire year, or 8,760 megawatt-
hours.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 8
Resources Base Year 5-year Forecast 10-year Forecast 5-year Change 10-year Change
Utility-scale Solar 56 363 499 307 443
Other Distributed Renewables 25 25 25 (0) (0)
Geothermal 2 2 102 (0) 99
Landfill Gas 1 7 9 6 8
Undecided No data 175 94 175 94
FTM Distributed Solar No data 1 1 1 1
Nuclear No data No data 24 No data 24
Biogas No data No data No data No data No data
Total Resources 12,079 12,446 13,654 367 1,575
Load Resource Balance 1,144 1,021 1,884 (123) 740
Figure 1 presents the composition of electric generation resources for the five-year and 10-year forecasts. Table 1
and Figure 1 show that utilities plan to continue relying mostly on Bonneville Power Administration (BPA),
hydroelectric generation, and thermal natural gas plants to meet electricity demand. The BPA resource is a blended
resource and is typically 85% hydropower, 11% nuclear, and 4% unspecified market purchases.
While several consumer-owned utilities plan to remove natural gas from their resource portfolios in their five-year
forecast, all the investor-owned utilities forecast relatively steady amounts of natural gas in their resource
portfolios. For the first time since reporting started, Washington utilities forecast that wind power will surpass
thermal natural gas plants in meeting their 10-year resource need.
Figure 1: Forecast available resources
6,000
5,000
Annual Energy aMW
4,000
3,000
2,000
1,000
0
5-year Forecast 10-year Forecast
Table 2 presents in average-megawatts the differences between the 2022 and 2024 resource reports on statewide
annual utility load and resources and the five and 10-year forecasts. Table 2 shows a diminished contribution from
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 9
coal-fired electricity generation and natural gas-fired generation in the forecast period, and an increased reliance on
BPA resources, hydropower, wind, imports, and other renewables.
Table 2: Difference between 2024 and 2022 requirements and resources — annual
energy aMW
Requirements Base Year 5-year Forecast 10-year Forecast
Loads (14) 499 882
Exports 520 295 233
Energy Conservation Measures No data (70) (26)
Demand Response No data 18 24
BTM Solar No data 26 52
Total Net Requirements 507 819 1,066
Resources Base Year 5-year Forecast 10-year Forecast
Total BPA 151 352 316
Hydro 363 197 325
Thermal Natural Gas (1,591) (1,357) (1,578)
Market Purchases 718 249 18
Other (266) (44) (19)
Wind 173 (11) 599
Thermal Coal (275) (156) (67)
Imports 148 203 250
Other Renewables (29) 91 127
Distributed Generation 20 39 57
Cogeneration (13) (13) (13)
Undecided No data 174 82
Nuclear No data No data 24
Total Resources (454) 28 685
Load Resource Balance (961) (791) (380)
The shift in electric generation resources suggests progress towards meeting the requirements of the Clean Energy
Transformation Act (CETA). CETA prohibits utilities from using coal generation after 2025. 7 CETA requires all retail
sales of electricity to Washington be greenhouse gas neutral by 2030 8 and 100% non-emitting by 2045.9
7 Section 19.405.030(1), Coal-fired resources-Depreciation schedule-Penalties. (2025). Retrieved from Revised Code of Washington.
8 Section 19.405.040(1), Greenhouse gas neutrality-Responsibilities for electric utilities-Energy transformation project criteria-Penalties.
(2025). Retrieved from Revised Code of Washington.
9 Section 19.405.050(1), Clean energy implementation-Hydroelectric facilities-Special contracts. (2025). Retrieved from Revised Code of
Washington.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 10
Table 3 presents utilities' aggregated report information for their highest estimated one-hour load during the winter
season, 10 including imports and exports, for the base year (2023), and the five and 10-year forecasts. In the past,
utilities forecasted more reliance on market purchases to meet peak demand, but utilities are increasingly aiming
to decrease their reliance on short-term wholesale electricity markets (market purchases). The availability of
dispatchable generation resources is declining and market power prices and volatility is increasing, especially
during peak demand periods when prices can be high and supply uncertain. 11 Utilities are exploring various
solutions, including demand response programs, energy efficiency measures, and new generation resources.
Table 3: Washington projected requirements and resources — winter capacity MW
Requirements Base Year 5-year forecast 10-year forecast 5-year change 10-year change
Loads 14,584 15,976 17,224 1,391 2,640
Exports 1,093 802 741 (291) (352)
Energy Conservation Measures No data (404) (896) (404) (896)
Demand Response No data (387) (526) (387) (526)
BTM Solar 0 (12) (16) (12) (16)
Total Net Requirements 15,678 15,975 16,526 297 848
Resources Base Year 5-year forecast 10-year forecast 5-year change 10-year change
Hydro 5,171 6,195 6,750 1,024 1,578
Total BPA 4,334 4,725 4,808 391 474
Thermal Natural Gas 3,182 3,008 3,001 (174) (181)
Other 1,878 1,300 1,340 (578) (538)
Market Purchases 1,598 225 200 (1,373) (1,398)
Wind 770 1,420 1,953 649 1,183
Imports 654 526 584 (128) (70)
Thermal Coal 596 No data No data (596) (596)
Biomass 59 66 66 7 7
Other Distributed Renewables 26 26 26 No data No data
Utility-scale Solar 20 527 544 507 524
Cogeneration 5 90 90 85 85
Landfill Gas 2 8 11 6 9
Geothermal 2 2 102 (0) 100
Undecided No data 80 No data 80 No data
Nuclear No data No data 30 No data 30
FTM Distributed Solar No data 0 0 0 0
Biogas No data No data No data No data No data
10 Table 1 expressed in energy units of aMW, Table 3 in capacity units of MW.
11 Puget Sound Energy. (2023, Chapter 1, p. 5). Electric Progress Report.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 11
Resources Base Year 5-year forecast 10-year forecast 5-year change 10-year change
Total Resources 18,297 19,000 20,943 703 2,646
Load Resource Balance 2,619 3,025 4,417 405 1,798
Most Washington utilities experience their annual peak load during the winter months; however, due to climate
change, utilities anticipate less heating required in the winter and more cooling required during the summer. Table
4 presents utilities' aggregated report information for their highest estimated one-hour load during the summer
season, including imports and exports, for the base year (2023), and the five and 10-year forecasts.
Warmer average summer temperatures and more frequent and intense heat waves are leading to increased
demand for air conditioning and cooling, directly driving up electricity consumption during summer peak hours. For
instance, Puget Sound Energy (PSE) noted that incorporating climate change data into their demand forecast
resulted in increased summer peak temperatures and thus, increased summer demand. 12 Avista anticipates
needing to prepare for a near-term future as a dual summer and winter peaking utility due to these trends. 13
Table 4: Washington projected requirements and resources - summer Capacity MW
Requirements Base Year 5-year forecast 10-year forecast 5-year change 10-year change
Loads 11,996 13,911 15,517 1,915 3,520
Exports 1,427 1,385 1,295 (42) (133)
Energy Conservation Measures No data (392) (854) (392) (854)
Demand Response No data (400) (539) (400) (539)
BTM Solar 0 (83) (122) (83) (122)
Total Net Requirements 13,424 14,421 15,296 998 1,872
Resources Base Year 5-year forecast 10-year forecast 5-year change 10-year change
Hydro 5,392 6,262 6,509 870 1,117
Total BPA 3,301 3,421 3,582 120 281
Thermal Natural Gas 2,681 2,515 2,508 (166) (173)
Other 1,541 1,249 1,248 (292) (293)
Market Purchases 1,778 248 200 (1,530) (1,578)
Wind 547 1,216 1,759 669 1,212
Imports 282 222 280 (60) (2)
Thermal Coal 595 No data No data (595) (595)
Biomass 59 66 66 7 7
Other Distributed Renewables 22 22 22 No data No data
Utility-scale Solar 84 966 1,022 882 938
12 Puget Sound Energy. (2023, Chapter 3, p. 14). Electric Progress Report.
13 Avista. (2023, Chapter 2, p. 21). Electric Integrated Resource Plan.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 12
Resources Base Year 5-year forecast 10-year forecast 5-year change 10-year change
Cogeneration 4 4 89 No data 85
Landfill Gas 2 9 11 7 9
Geothermal 2 2 102 (0) 100
Undecided No data 128 No data 128 No data
Nuclear No data No data 31 No data 31
FTM Distributed Solar No data 1 2 1 2
Biogas No data No data No data No data No data
Total Resources 16,290 17,206 18,946 916 2,656
Load Resource Balance 2,866 2,784 3,649 (82) 783
Figure 2 shows Washington utilities' 10-year (2033) projected resources by utility ownership type. Most consumer-
owned utilities (public utility districts, municipal, and cooperatives) rely predominantly on BPA resources and
hydropower; however, municipal utilities forecast a higher use of wind power and energy conservation measures
than other consumer-owned utilities. Investor-owned utilities plan to rely on baseload natural gas generation for
approximately 20% of their 10-year projected resources; however, they plan to reduce their natural gas generation
by approximately 16% compared to the base year of 2023.
Figure 2: Washington 10-year projected resources by utility ownership type
5,000
4,000
Annual Energy aMW
3,000
2,000
1,000
-
Investor Owned Public Utility District Municipal Cooperative
Table 5 presents a time series of Commerce Utility Resource Plans. The information in the table presents
aggregated annual utility loads (base year, five-year and 10-year) for the 2008 through 2024 Commerce reports.
The forecast loads do not include the energy conservation measure (ECM) forecast by utilities. Figure 3 presents
the information in Table 5 in a graphical format. Table 6 and Figure 4 present the aggregated annual utility loads
(base-year, five-year and 10-year) and include energy conservation measures (ECM), demand response (DR), and
behind-the-meter (BTM) solar forecasts by utilities.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 13
Table 5 and 6 and Figure 3 and 4 show load growth forecasts by utilities for the five and 10-year points which have
typically trended down with each successive report; however, this year, the forecasts do not follow the trend. This is
due to new high load growth rates from factors, such as data center growth, population growth, and electrification.
The Mid-Columbia utilities, Grant, Chelan, and Douglas PUDs, are forecasting high load growth rates due to the
growth of data centers, computing demand, cryptocurrency mining, and industrial load.
Chelan County PUD forecasts a very high average annual growth rate of 31.71%, 31.88%, and 32.23% for High
Density Loads 14, cryptocurrency processing, and large loads during the planning period. 15
For Grant County PUD, over the past the twenty years, industrial class load growth has made up an ever-increasing
portion of their total retail load, and data centers have grown to dominate load growth in that sector. Industrial
loads have transitioned from a 28% share twenty years ago to a 47% share of total Grant PUD load today. 16
Over the last decade, Douglas PUD experienced a load growth of 76% principally due to large loads. 17 Douglas PUD
expects elevated levels of load growth to continue. Douglas PUD reports it has instituted a number of policies to
curb risk associated with data loads. One of these policies requires large contract customers to enter into special
contracts that mitigate risk associated with transmission and distribution build-out by requiring customers to pay
for all required infrastructure upgrades upfront. 18
Other utilities are also predicting increasing load growth (though not at the very high rates from data centers,
computing demand, cryptocurrency mining, and industrial and manufacturing growth) due to electrification of
buildings and transportation and population growth. Clark Public Utilities (CPU) projects an average year-over-year
load growth of 1.98%, with a high scenario reaching 3.12% for 2025-2044. The load forecast in CPU's study
incorporates additional load growth due to building and vehicle electrification beyond what has been seen
historically. Over the study period, CPU shifts from a predominantly winter-peaking utility to a summer-peaking
utility. CPU is currently forecast to have sufficient resources available to meet average energy demand through
2035. However, on a capacity basis, CPU is currently at a deficit and is projected to grow that deficit to roughly 750
MW of summer capacity and 500 MW of winter capacity by the end of the study period absent additional resource
procurement. That deficit is partially exacerbated by the additional capacity required to comply with the Western
Resource Adequacy Program (WRAP), which is modeled to take effect in November 2027.19 Moreover, Puget Sound
Energy (PSE) primarily serves residential and commercial customers, and it expects energy demand to grow an
average rate of 1.8 percent annually from 2024-2045.20 Rising customers and electric vehicle counts drive most of
the growth in energy demand for PSE. This demand growth is partially, but not entirely, offset by decreasing
residential heating energy demand — a consequence of adopting trended normal temperatures consistent with
climate change impacts.
Table 5: Utility report time series — base year and forecast loads without ECM
Utility Report
Base Year Base Year, aMW 5-year Est. 5-year Est. aMW 10-year Est. 10-year Est. aMW
Year
2008 2007 10,008 2012 11,304 2017 12,270
14 These are typically server farms and similar technological operations.
15 Chelan PUD. (2023, p. 15-16). Integrated Resource Plan Progress Report.
16 Grant PUD. (2024, p. 54). Integrated Resource Plan.
17 Douglas PUD. (2024, p. 6). Integrated Resource Plan Update.
18 Douglas PUD. (2024, p. 7). Integrated Resource Plan Update.
19 Clark Public Utilities. (2024, p. 6). Integrated Resource Plan.
20 Puget Sound Energy. (2023, Chapter 6, p. 1). Electric Progress Report.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 14
Utility Report
Base Year Base Year, aMW 5-year Est. 5-year Est. aMW 10-year Est. 10-year Est. aMW
Year
2010 2009 10,606 2014 11,737 2019 12,717
2012 2011 10,265 2016 11,264 2021 12,126
2014 2013 10,166 2018 11,502 2023 12,380
2016 2015 10,099 2020 10,875 2025 11,576
2018 2017 10,231 2022 10,816 2027 11,356
2020 2019 10,307 2024 10,775 2029 11,372
2022 2021 10,202 2026 10,818 2031 11,363
2024 2023 10,189 2028 11,316 2033 12,245
Figure 3: Utility report time series — base year and forecast loads without ECM
13,000
12,500
12,000
11,500
aMW
11,000
10,500
10,000
9,500
Base Year 5-year Forecast 10-year Forecast
2008 2010 2012 2014 2016 2018 2020 2022 2024
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 15
By comparing, Table 5 and 6 as well as Figure 3 and 4 it is evident that utility conservation programs significantly
reduce aggregate load growth.
Table 6: Utility report time series — base year and forecast loads with ECM, DR, and
BTM solar
Utility
Base Year Base Year, aMW 5-year Est. 5-year Est. aMW 10-year Est. 10-year Est. aMW
Report Year
2008 2007 10,008 2012 10,890 2017 11,524
2010 2009 10,555 2014 11,145 2019 11,691
2012 2011 10,265 2016 10,692 2021 11,107
2014 2013 10,166 2018 11,017 2023 11,423
2016 2015 10,099 2020 10,347 2025 10,629
2018 2017 10,231 2022 10,345 2027 10,582
2020 2019 10,307 2024 10,272 2029 10,548
2022 2021 10,202 2026 10,389 2031 10,514
2024 2023 10,189 2028 10,912 2033 11,347
Figure 4: Utility report time series — base year and forecast loads with ECM, DR, and
BTM solar
13,000
12,500
12,000
11,500
aMW
11,000
10,500
10,000
9,500
Base Year 5-year Forecast 10-year Forecast
2008 2010 2012 2014 2016 2018 2020 2022 2024
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 16
Table 7 presents the individual utility growth forecasts and the percentage of load growth anticipated to be met by
energy conservation measures. The average load growth with no conservation across utilities has more than
doubled compared to the 2022 resource plan report. The average 5-year load growth with no conservation
increased from 3.2% in 2022 to 8.5% in 2024, and the average 10-year load growth with no conservation increased
from 6.2% in 2022 to 15.5% in 2024. Most of this load growth comes from data centers, computing demand, and
cryptocurrency mining in the service territories of Chelan County PUD, Douglas County PUD, and Grant County PUD.
Table 7: Individual utility load forecasts without conservation and with
conservation
Utility Name 5-year 10-year 5-year 10-year
load growth load growth load growth load growth
change % change % change % change %
without without met by met by
conservation conservation conservation conservation
Asotin County PUD No. 1 6.01% 6.20% 0.00% 0.00%
Avista 6.12% 12.81% 47.63% 45.71%
Benton County PUD No. 1 -0.95% 2.34% -239.74% 194.86%
Benton Rural Electric Assn 2.84% 7.27% 0.00% 0.00%
Big Bend Electric Cooperative 9.16% 11.60% 3.81% 3.01%
Blaine, City of 34.09% 46.81% 0.21% 0.15%
Centralia, City of 7.94% 9.23% 0.00% 0.00%
Chelan County PUD No.1 72.93% 140.13% 4.98% 6.36%
Cheney, City of 3.63% 7.19% 3.39% 1.71%
Chewelah, City of -0.49% -0.45% -80.35% -87.70%
Clallam County PUD No. 1 3.33% 8.13% 134.19% 109.77%
Clark Public Utilities 3.62% 12.50% 0.00% 0.00%
Columbia REA 0.74% 4.86% 0.00% 0.00%
Coulee Dam, Town of 1.02% 3.47% 0.00% 0.00%
Cowlitz County PUD No. 1 31.61% 32.21% 0.00% 0.00%
Douglas County PUD No. 1 106.98% 171.13% 0.00% 0.00%
Eatonville, Town of 0.00% 0.00% 0.00% 0.00%
Ellensburg, City of 8.29% 9.79% 5.76% 4.88%
Elmhurst Mutual Power and Light 0.72% 2.35% 150.00% 46.15%
Company
Ferry County PUD -1.07% 1.15% -9.46% 8.79%
Franklin County PUD No. 1 23.87% 32.56% 0.00% 0.00%
Grant County PUD No. 2 37.89% 54.16% 2.50% 4.21%
Grays Harbor County PUD No. 1 9.33% 7.40% 0.00% 0.00%
Inland Power and Light 11.24% 21.75% 0.00% 0.00%
Jefferson County PUD No. 1 1.59% 2.84% 31.05% 17.35%
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 17
Utility Name 5-year 10-year 5-year 10-year
load growth load growth load growth load growth
change % change % change % change %
without without met by met by
conservation conservation conservation conservation
Kalispel Tribal Utilities 25.31% 32.70% 0.00% 0.00%
Kittitas County PUD No. 1 10.87% 21.01% 2.00% 1.03%
Klickitat County PUD No. 1 -3.44% 3.23% 0.00% 0.00%
Lakeview Light & Power 1.83% 2.86% 21.82% 13.95%
Lewis County PUD No. 1 2.93% 8.07% 0.00% 0.00%
Mason County PUD No. 1 2.26% 4.20% 0.00% 0.00%
Mason County PUD No. 3 7.82% 16.30% 21.08% 10.42%
McCleary, City of 4.47% 5.83% 0.00% 0.00%
Milton, City of -0.06% 0.16% -775.00% 281.82%
Modern Electric -0.20% 2.14% -126.68% 11.88%
Nespelem Valley Electric Cooprative 4.99% 7.09% 0.00% 0.00%
Ohop Mutual Light Company 3.22% 7.95% 14.03% 5.68%
Okanogan County Electric Cooperative 9.41% 16.15% 0.00% 0.00%
Okanogan County PUD No. 1 4.73% 8.45% 0.00% 0.00%
Orcas Power and Light Cooperative 6.34% 8.82% 0.00% 0.00%
Pacific County PUD No. 2 2.75% 5.23% 50.00% 21.05%
PacifiCorp 9.82% 15.91% 72.64% 80.89%
Parkland Light and Water Company 1.42% 2.39% 10.47% 6.23%
Pend Oreille PUD -58.45% -56.90% 0.00% 0.00%
Peninsula Light -4.67% -4.14% -14.62% -16.50%
Port Angeles, City of 5.02% 6.70% 28.51% 43.42%
Puget Sound Energy 1.68% 4.61% 369.23% 363.55%
Richland, City of 11.05% 16.16% 26.78% 66.31%
Seattle City Light 8.62% 19.37% 52.69% 44.02%
Seattle, Port of 2.53% 23.11% 31.90% 3.50%
Skamania County PUD No. 1 5.62% 9.05% 1.05% 0.65%
Snohomish County PUD No. 1 9.56% 25.45% 42.27% 40.96%
Steilacoom, Town of 4.75% 7.01% 5.71% 3.87%
Sumas, City of 4.85% 4.85% 11.11% 11.11%
Tacoma Power -2.78% 1.99% -154.95% 478.49%
Tanner Electric 18.69% 21.78% 0.89% 0.77%
Vera Water and Power 3.52% 7.02% 4.93% 2.47%
Wahkiakum County PUD No. 1 8.10% 11.96% 0.00% 0.00%
Whatcom County PUD No. 1 10.51% 47.71% 0.00% 0.00%
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 18
Utility Name 5-year 10-year 5-year 10-year
load growth load growth load growth load growth
change % change % change % change %
without without met by met by
conservation conservation conservation conservation
Yakama Power 4.71% 6.01% 5.88% 4.61%
Average 8.47% 15.46% -4.07% 30.59%
Energy efficiency and conservation (also referred to as energy conservation measures) is a fundamental resource
for utilities in their long-term planning, but utilities are anticipating energy efficiency and conservation to contribute
less towards meeting load growth. Projected load growth across utilities is also greater than prior resource plans
due to the incorporation of new load growth projections due to building and transportation electrification. For
instance, Avista anticipates that energy conservation measures will meet a significant portion of future load
growth, although the percentage may be lower than in previous forecasts due to factors like electric transportation,
building electrification, and market saturation of efficient technologies. Energy conservation measures meet more
than 27% of all future load growth for Avista, where prior IRP forecasts found energy conservation measures met
nearly 70% of future load growth. 21
Several utilities are actively exploring and implementing demand response programs, specifically targeting large
load customers, including data centers and cryptocurrency miners, to manage peak demand. For instance, Grant
PUD is currently operating a pilot demand response program aimed at high load factor customers, including
cryptocurrency miners. They are also considering direct load curtailment for irrigation customers. Grant PUD
anticipates these programs can help reduce near-term capacity shortfalls and compete with storage and peaking
assets. They estimate 30 to 50 MW could be available through these DR programs by 2026. 22 Tacoma Power is
testing demand response as a potential resource option under scenarios where they anticipate capacity shortfalls.
They have considered generic demand response resources that either shift usage or are called upon during peak
events, equivalent to approximately 20 to 30 MW by the late 2030s. 23 In 2024, Clark Public Utilities (CPU) launched
an industrial demand response incentive pilot program allowing qualified customers to nominate load reductions
during a demand response event. CPU plans to continue expanding demand response programs as they become
more cost-effective and with the adoption of Advanced Metering Infrastructure (AMI). 24
Overgeneration
In 2013, the Legislature amended the resource planning statute to address concerns about the potential for
“overgeneration” events. 25 The legislation required that utilities consider this potential in their planning “if
applicable to the utility's resource portfolio,” and required that Commerce include in this report an assessment of
utility approaches to overgeneration.
The statute defines an overgeneration event as:
21 Avista. (2023, Chapter 9, p. 7). Electric Integrated Resource Plan.
22 Grant PUD. (2024, p. 77). Integrated Resource Plan.
23 Tacoma Power. (2024, p. 39-40). Integrated Resource Plan.
24 Clark Public Utilities. (2024, p. 74). Integrated Resource Plan.
25 Section 19.280.060, Department's duties—Report to the legislature. (2025). Retrieved from Revised Code of Washington.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 19
An event within an operating period of a balancing authority when the electricity supply, including generation
from intermittent renewable resources, exceeds the demand for electricity for that utility's energy delivery
obligations and when there is a negatively priced regional market.
Overgeneration is also referred to as oversupply. It might occur when high river flows and high wind volumes
coincide with low load. It might also occur when the hours of solar generation misalign with peak electricity
demand. The capacity of the hydroelectric system to store extra river flow is limited, and even the option of spilling
water over the dams is restricted by fish mortality concerns. In these circumstances, the regional power system
may have more electric generation from hydroelectric, wind, and solar resources than what is required to meet
regional loads and export opportunities. This oversupply results in negatively priced spot market prices. The
consequence is that a utility must pay another entity to take unwanted power or generation is curtailed. Many wind
generators receive federal incentive credits and/or payments based upon their wind production, and they can sell
the RECs from this generation. Thus, these generators can withstand some degree of negative pricing and still
make a profit. 26
Since 2013, the Bonneville Power Administration has adopted an Oversupply Management Protocol, providing tools
for the operators of the hydroelectric system and transmission grid to manage oversupply situations. 27 In the
Northwest, the BPA has business practices that push the burden of oversupply back to the market and away from
themselves. These practices include not selling at negative prices until spilled water reaches dissolved gas limits,
holding renewable generators to a fixed schedule, not accepting unplanned surplus, and canceling transmission
loss returns. 28 The implementation of this protocol has generally shifted the overgeneration issue from a planning
concern to an operational concern.
In many cases, utilities did not find it necessary in their 2022-2024 resource plans to address overgeneration, or
generation curtailment, as an issue separate from the more general assessment of generating resource
alternatives.
Resource adequacy
Most utilities plan to meet load requirements in the lowest-cost, least-risk way by renewing BPA contracts (for slice
or block products or shifting to a load following product), maximizing energy conservation measures, and
implementing new demand and response programs.
Many consumer-owned utilities already have 80% or more renewable generation, and they plan to comply with
CETA requirements between 2030 and 2045 using clean energy credits. With the emergence of the Western
Resource Adequacy Program (WRAP) and increased reliance on regional markets for power, some utilities, such as
Snohomish PUD and Benton PUD, are moving to BPA load-following customers to rely on BPA to ensure resource
adequacy.
Other strategies utilities reported considering include:
Developing WRAP
Investigating dispatchable, renewable and non-emitting resources, such as batteries, hydrogen, geothermal and
small modular nuclear reactors
Diversifying the geographic location of their renewable resources
26 Chelan PUD. (2023, p. 24-25). Integrated Resource Plan Progress Report.
27 Oversupply. (n.d.). Retrieved from Bonneville Power Administration.
28 Chelan PUD. (2023, p. 25). Integrated Resource Plan Progress Report.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 20
Enhancing the capacity of their transmission lines
Regional resource adequacy forecasts
Commerce and the Utilities and Transportation Commission (UTC) regularly review regional resource adequacy
assessments and other load forecasts and scenario studies,29 and convene an annual meeting with regional
resource adequacy experts, utilities, and other stakeholders per RCW 19.280.065.
The joint meeting between the UTC and Commerce in September 2024 found assessments of resource adequacy
from regional experts show the Northwest has adequate resources to meet current demand for electricity and does
not face a significant risk of outages in the near term. 30 However, these assessments assume the industry will be
able to execute their planned capacity expansions. Confidence in these assessments is also limited by the
increasing level of uncertainty that planners face about future demand for electricity. The sources of this
uncertainty include the added volatility of our weather, the pace of consumer conversion to electricity for
transportation, heating and other end uses, and the growing energy demands of data centers. Common themes
across resource adequacy assessments and other regional load forecasts and scenario studies include:
Participation of utilities in WRAP is crucial for the future of regional resource adequacy
Limited transmission capacity is a key binding constraint that once addressed would enable utilities to more
efficiently access a diverse set of cost-effective resources from across the West, mitigate weather disruptions,
and enhance regional resource adequacy
Demand-side management and virtual power plants have significant potential to shave peak load and maintain
resource adequacy
Traditional battery storage technologies can help enable the smooth integration of intermittent renewables onto
the electric grid while emerging long duration storage technologies can support the electric grid for multiple days
during potential natural gas supply or electric generation disruptions
Emerging technologies, such as green hydrogen and enhanced geothermal, show promise as firm power
supplies free of greenhouse gas emissions
High data center load growth and lower than expected energy efficiency scenarios would place severe resource
demands on the grid and put the adequacy of the electric grid at risk
The region needs to steadfastly permit, site, and build resources to maintain current levels of resource adequacy
over the medium-to-long term
Conclusion
The 2024 Washington State Electric Utility Resource Planning report reveals modest load growth increasingly met
by clean energy resources. Utilities plan to cut coal and market purchases, and increase use of hydropower, wind,
and solar.
After years of declining or stagnant load forecasts, utilities across the state project modest load growth from
population increases and electrification. Alongside this general assessment, substantial load growth was
forecasted by Grant, Douglas, Chelan PUDs, driven by potential data center electricity needs.
To meet these demands, consumer-owned utilities are focusing on renewing their Bonneville Power Administration
(BPA) contracts, and both consumer-owned utilities and investor-owned utilities are developing new renewables
29 These studies include but are not limited to: the Western Electricity Coordinating Council Resource Assessment of Resource Adequacy,
the Pacific Northwest Power and Conservation Council Power Supply and Adequacy Assessment; and Pacific Northwest Utilities Conference
Committee Northwest Regional Forecast, the latter of which is not a resource adequacy assessment.
30 2024 Resource Adequacy Letter and Summary; Western Assessment of Resource Adequacy 2024.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 21
and maximizing conservation. While many consumer-owned utilities plan to phase out natural gas, investor-owned
utilities project stable usage. Wind power is notably forecasted to surpass natural gas within ten years, advancing
Clean Energy Transformation Act (CETA) goals. Some utilities are preparing for dual winter and summer peaks due
to increased summer temperatures and household cooling demands driven by climate change. Regional
assessments indicate adequate resources to meet loads in the near term, but maintaining resource adequacy
depends on successful capacity expansions and increased regional cooperation between utilities.
The 2024 report presents several other developments since the 2022 legislative report:
Incorporation of climate change and electrification modelling: The resource plans summarized in the 2024 report
more thoroughly accounted for the impacts of climate change and electrification. These changes resulted in a
shift in peak demand for some utilities and modest load growth for many utilities.
Energy conservation contribution: The 2024 report offers a more cautious outlook on the incremental
contribution of energy conservation measures (ECM) to meet future load growth compared to 2022. Planned
five-year ECM is 70 aMW lower than the 2022 report's anticipation for that period.
Reduced market reliance for peak demand: The 2024 report indicates utilities have a stronger intent to reduce
reliance on short-term wholesale market purchases for peak demand, a shift from earlier forecasts where such
purchases were more prominent in peak capacity strategies.
Load resource balance: The 2024 report projects a tighter (lower) load-resource balance (surplus) for base, five-
year, and ten-year forecasts compared to 2022's anticipated balances, suggesting a closer but adequate margin
between expected resources and requirements.
Finally, this report points to a continued need to improve clean energy siting and permitting processes and enhance
transmission capacity in Washington and across the Western Interconnection. Increased deployment of demand-
side management, virtual power plants, and traditional battery storage systems, accompanied by emerging
technologies and utility participation in the Western Regional Adequacy Program (WRAP), are additional actions
that would further resource adequacy and the clean energy transition.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 22
Appendix A: Utility cover sheets
Washington Electric Utility Loads and Resources Estimates reported to the Department of Commerce in 2024 are
available in this Excel workbook.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 23
Appendix B: Washington utility customer count, revenue, sales,
and average price31
Customers Revenue (Thousand Retail Sales Average Price
Behind the Meter
(Count) Dollars) (Megawatthours) (Cents/kWh)
Tesla Inc. 99 $67 608 11¢
Sunnova 60 $11 64 17¢
Customers Revenue (Thousand Retail Sales Average Price
Cooperative
(Count) Dollars) (Megawatthours) (Cents/kWh)
Inland Power & Light
44,400 $85,033 1,016,225 8¢
Company
Peninsula Light Company 35,429 $60,993 624,171 10¢
Elmhurst Mutual Power &
16,037 $21,137 279,846 8¢
Light Co
Benton Rural Electric Assn 15,962 $44,938 620,972 7¢
Orcas Power & Light Coop 15,855 $36,214 214,371 17¢
Modern Electric Water
10,615 $15,619 227,881 7¢
Company
Lakeview Light & Power 10,481 $23,781 251,778 9¢
Big Bend Electric Coop, Inc 9,946 $42,454 564,937 8¢
Columbia Rural Elec Assn,
6,490 $33,210 367,976 9¢
Inc
Tanner Electric Coop 5,317 $12,949 99,247 13¢
Ohop Mutual Light Company,
5,017 $8,438 98,989 9¢
Inc
Parkland Light & Water
4,591 $9,005 117,676 8¢
Company
Okanogan County Elec Coop,
4,143 $6,798 67,139 10¢
Inc
Yakama Power 2,298 $7,004 95,343 7¢
Nespelem Valley Elec Coop,
1,538 $5,535 59,863 9¢
Inc
Clearwater Power Company 1,046 $2,326 21,443 11¢
Kootenai Electric Cooperative 98 $267 2,626 10¢
Northern Lights, Inc 15 $30 252 12¢
31 Energy Information Administration. (2023). Annual Electric Power Information Report.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 24
Customers Revenue (Thousand Retail Sales Average Price
Federal
(Count) Dollars) (Megawatthours) (Cents/kWh)
Bonneville Power
10 $31,985 1,195,413 3¢
Administration
Customers Revenue (Thousand Retail Sales Average Price
Investor owned
(Count) Dollars) (Megawatthours) (Cents/kWh)
Puget Sound Energy Inc 1,223,225 $2,753,519 23,436,236 12¢
Avista Corp 270,433 $610,155 5,739,294 11¢
PacifiCorp 136,363 $387,829 3,850,048 10¢
Customers Revenue (Thousand Retail Sales Average Price
Municipal
(Count) Dollars) (Megawatthours) (Cents/kWh)
City of Seattle - (WA) 503,221 $1,048,523 9,228,431 11¢
City of Tacoma - (WA) 196,833 $410,927 4,552,573 9¢
City of Richland - (WA) 27,048 $77,437 997,726 8¢
City of Port Angeles - (WA) 11,018 $27,557 396,839 7¢
City of Centralia - (WA) 10,701 $26,675 265,359 10¢
City of Ellensburg - (WA) 10,582 $19,101 221,650 9¢
City of Cheney - (WA) 6,007 $8,359 148,111 6¢
Town of Steilacoom 3,782 $4,335 38,733 11¢
City of Blaine - (WA) 3,766 $7,244 83,974 9¢
City of Milton - (WA) 3,593 $5,964 55,110 11¢
City of Chewelah 1,363 $2,115 24,088 9¢
Town of Eatonville - (WA) 1,278 $2,302 28,247 8¢
City of McCleary - (WA) 1,194 $3,752 31,649 12¢
City of Sumas - (WA) 1,028 $2,582 31,283 8¢
Town of Ruston - (WA) 622 $1,368 10,382 13¢
City of Coulee Dam - (WA) 602 $1,243 16,701 7¢
PUD No 1 of Asotin County 3 $14 245 6¢
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 25
Customers Revenue (Thousand Retail Sales Average Price
Political subdivision
(Count) Dollars) (Megawatthours) (Cents/kWh)
PUD No 1 of Snohomish
377,261 $668,410 6,794,876 10¢
County
PUD No 1 of Clark County -
235,481 $392,180 4,785,718 8¢
(WA)
PUD No 1 of Benton County 57,263 $134,664 1,838,441 7¢
PUD No 2 of Grant County 55,012 $269,355 5,958,946 5¢
PUD No 1 of Cowlitz County 53,155 $232,091 4,104,045 6¢
PUD No 1 of Chelan County 49,579 $67,197 1,876,426 4¢
PUD No 1 of Grays Harbor
45,223 $106,199 930,270 11¢
County
PUD No 3 of Mason County 35,985 $80,923 695,379 12¢
PUD No 1 of Lewis County 34,809 $81,808 964,301 8¢
PUD No 1 of Clallam County 33,931 $72,147 665,293 11¢
PUD No 1 of Franklin County 29,428 $87,670 1,103,231 8¢
PUD No 1 of Okanogan
22,018 $53,592 633,607 8¢
County
PUD No 1 of Jefferson
20,873 $42,250 391,951 11¢
County
PUD No 2 of Pacific County 18,338 $27,693 315,430 9¢
PUD No 1 of Douglas County 17,364 $53,512 1,345,707 4¢
PUD No 1 of Klickitat County 14,111 $38,965 441,885 9¢
Vera Irrigation District #15 13,509 $20,325 239,014 9¢
PUD No 1 of Pend Oreille
10,008 $53,256 695,193 8¢
County
PUD No 1 of Skamania Co 6,571 $15,873 137,082 12¢
PUD No 1 of Mason County 5,610 $10,251 83,748 12¢
PUD No 1 of Ferry County 3,783 $7,784 80,287 10¢
PUD No 1 of Kittitas County 3,771 $12,800 112,794 11¢
PUD No 1 of Wahkiakum
2,776 $4,638 46,164 10¢
County
PUD No 1 of Whatcom
1 $10,206 229,343 4¢
County
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 26
Customers Revenue (Thousand Retail Sales Average Price
Retail power marketer
(Count) Dollars) (Megawatthours) (Cents/kWh)
Shell Energy North America (US), L.P. 3 $33,821 486,097 7¢
BP Energy Company 2 $82,247 830,991 10¢
Brookfield Renewable Energy
1 $19,697 361,074 5¢
Marketing US LLC
Avangrid Renewables 1 $1,019 32,879 3¢
Calpine Energy Solutions, LLC 1 $970 8,012 12¢
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 27
Appendix C: Glossary of terms
Average annual energy: one megawatt is equal to one million watts. One million watts delivered continuously 24
hours a day for a year (8,760 hours) is called an average megawatt. The maximum amount of power a generating
plant is capable of producing over the course of an average year is called its generating capability or average
annual energy, expressed in average megawatts.
Behind-the-meter (BTM) solar: refers to customer-sited solar energy panels. BTM solar includes the expected
generating capability that is customer-owned, utility-owned, and third-party owned.
Cogeneration: the sequential production of electricity and useful thermal energy from a common fuel source.
Demand response: the voluntary and temporary reduction in consumers’ use of electricity when the power system
is stressed. It includes voluntary demand response, demand response with paid incentives, time-of-use, and
demand voltage reduction programs.
Distributed generation: an eligible renewable resource where the facility or any integrated cluster of generating
units has a generating capacity of not more than five megawatts.
Duration value at risk (VaR Duration): longest shortfall event for the 97.5th worst simulation year. VaR Duration
sets a limit for shortfall duration during rare (once per 40 year) events. To calculate this metric, the duration of the
longest shortfall event for each simulation year is recorded (or zero if there is no shortfall). The Duration VaR97.5 is
the 97.5th highest duration from that record. Choosing the 97.5th percentile limits the risk of an excessively long
shortfall event to no more than once per 40 years.
Energy conservation measures (also referred to as conservation and efficiency resources): any reduction in
electric power consumption resulting from increases in the efficiency of energy use, production, or distribution.
Energy value at risk (VaR energy): total annual shortfall energy for the 97.5th worst simulation year. VaR Energy
set limits for the big energy shortfalls during rare (once per 40 year) events.
Front-of-the-meter (FTM) distributed solar: refers to solar power that is located on the distribution system or any
subsystem of the distribution system.
Loss of load probability (LOLP): traditionally, a power supply is deemed to be adequate when its annual Loss of
Load Probability (LOLP) is 5% or less; that is, when the likelihood of having one or more shortfalls during an
operating year is less than or equal to 5%. A 5% LOLP means that the simulated operation of the power supply
yields only one year out of 20 with shortfalls.
Loss of load events (LOLEV): the expected number of shortfall events per year. A shortfall event is a set of
contiguous hours of unserved demand. LOLEV is equal to the total number of shortfall events divided by the total
number of simulation years.
Net short-term contracts/market purchases: refers to limited duration wholesale power purchase not to exceed
one month, made by an electric utility for delivery to Washington retail electric customers for which the source of
the power is not known at the time of entry into the transaction to procure the electricity.
Loads: electric loads include retail sales + line losses + utility needs. The base year includes existing conservation
or demand reduction as a part of base year load. All projected electric loads (non-base year) are estimated before
reductions from energy conservation measure programs or demand response program estimates. Additional future
conservation and demand response are treated as resources to meet future load.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 28
Peak energy: highest estimated one-hour load for summer and winter, normalized for weather.
Peak Value at Risk (VaR Peak): highest single-hour shortfall for the 97.5th worst simulation year. VaR Peak set
limits for occurrences of big energy shortfalls during rare (once per 40 year) events.
Resource adequacy: the ability of the electricity system to supply the aggregate electric power and energy
requirements of the electricity consumers at all times, taking into account scheduled and expected unscheduled
outages of system components.
Renewable resources: RCW 19-280, Electricity Utility Resource Plans, defines “renewable resources” as “electricity
generation facilities fueled by: (a) Water; (b) wind; c) solar energy, (d) geothermal energy, (e) landfill gas, (f)
biomass energy utilizing animal waste, solid organic fuels from wood, forest or field residues or dedicated energy
crops that do not include wood pieces that have been treated with chemical preservatives such as creosote,
pentachlorophenol, or copper-chrome-arsenic; (g) by-products of pulping or wood manufacturing processes,
including but not limited to bark, wood chips, sawdust, and lignin in spent pulping liquors; (h) ocean thermal, wave
or tidal power; and (i) gas from sewage treatment facilities.”
Utility-scale solar: refers to a large-scale solar power project that is interconnected to the transmission system.
Western Electricity Coordinating Council (WECC): WECC promotes bulk power system reliability and security in the
Western Interconnection. WECC is the regional entity responsible for compliance monitoring and enforcement and
oversees reliability planning and assessments. In addition, WECC provides an environment for the development of
reliability standards and the coordination of the operating and planning activities of its members.
Western interconnection: the geographic area containing the synchronously operated electric grid in the western
part of North America, which includes parts of Montana, Nebraska, New Mexico, South Dakota, Texas, Wyoming
and Mexico and all of Arizona, California, Colorado, Idaho, Nevada, Oregon, Utah, Washington and the Canadian
provinces of British Columbia and Alberta.
Western Resource Adequacy Program (WRAP): The Western Resource Adequacy Program (WRAP) is the first
regional reliability planning and compliance program in the history of the West.
It will deliver a region-wide approach for assessing and addressing resource adequacy and provide an important
step forward for reliability in the region.
WASHINGTON STATE UTILITY RESOURCE PLANNING REPORT 2024 29
File and source
- File
- 2025_washington-state-electric-utility-resource-planning-2024-report-final-.pdf
- Size
- 863,720 bytes
- SHA-256
- 2598026bce225b45007167998ed283eaa522466b2e70529354506d6919ab6dd5
- Original
- app.leg.wa.gov