Utility / owner / operatorWAPolitical subdivision (e.g. public utility district)How EIA classifies an organization, such as a public utility, cooperative or investor-owned company.Definition ↗Consumer-ownedUtilities owned by the public they serve: municipal, cooperative, public utility district and other political subdivisions, state and federal. A grouping the atlas defines from EIA's owner types.Definition ↗
Clark Public Utilities
Listed by EIA as “PUD No 1 of Clark County - (WA)”.
Operated nameplate capacity, operating generatorsFull nameplate MW of operating generators at plants this organization runs, including shares held by other owners.Definition ↗
248MW
Source & method
Sum of operating generator nameplate MW at plants where this organization is the reported operator
2024 inventory · reported · derived · valid · final
1 of 1 plants included.
Reported operating capacity; partial plant/unit coverage is marked
Owned nameplate capacity, operating generatorsOperating generator nameplate MW multiplied by this organization’s ownership share, once per generator. This can include plants another organization operates.Definition ↗
248MW
Source & method
Sum over operating generators of nameplate MW x this organization's ownership fraction (reported schedule or EIA-860 schedule-4 default)
2024 inventory · reported · derived · valid · final
Example: an operating 100 MW generator with a 25% ownership share contributes 25 MW to owned capacity. Its operator counts the full 100 MW. Neither quantity establishes who buys its electricity.
Operates
Operating MWFull operating nameplate capacity at plants this organization runs, including shares held by other owners.Definition ↗
Share-weighted MWAn organization with a reported share of a generator. Owned MW applies that share to operating nameplate capacity; it does not establish who buys the output.Definition ↗
Through BPA: 54.5% of sales; unspecified purchases: 18.6%. Filed as claimant “Clark County PUD #1”.
By report year MWh and shares of Washington retail sales including losses; not generation, not a compliance finding
Each year as Commerce's fuel-mix system holds it: MWh and shares of the utility's Washington retail sales including line losses, never generation and never a compliance finding. Years before CY2018 are Commerce's restatement under the 2019 method, not the disclosure published for the year; no change is taken across that break.
Disclosed supply by report year
Report year
Washington retail sales · MWh
Mix · share of Washington sales
Through BPA · share
Unspecified · share
CY2018 onUnspecified power is disclosed as its own category, as the statute has required since ESHB 1428 (2019); Commerce's statutory aggregate carries an unspecified row from CY2018. CY2022-Aggregate Fuel Mix Time Series.xlsx ↗ (Info!A10; Info!A16)
CY2024
4,932,673 MWh
Hydro 42.5% · Natural Gas 28.7% · Market 18.6%
54.5%
18.6%
CY2023
5,002,389 MWh
Hydro 40.1% · Natural Gas 31.8% · Wind 10.7%
51.1%
8.8%
CY2022
5,065,107 MWh
Hydro 48.0% · Natural Gas 28.6% · Market 11.9%
56.2%
11.9%
CY2021
4,891,027 MWh
Hydro 45.7% · Natural Gas 34.3% · Market 10.0%
53.7%
10.0%
CY2020
4,623,703 MWh
Hydro 50.9% · Natural Gas 29.9% · Market 9.6%
59.7%
9.6%
CY2019
4,720,073 MWh
Hydro 46.0% · Natural Gas 31.4% · Market 12.7%
55.1%
12.7%
CY2018
4,683,621 MWh
Hydro 57.2% · Natural Gas 25.5% · Market 10.3%
65.7%
10.3%
Before CY2018: restatedCommerce's current system run over what utilities reported for a year before CY2018. The disclosure published for that year followed the old law, which required Commerce to assign fuel shares to unspecified power; this run keeps unspecified power as its own Market category, and Commerce's statewide totals for these years differ from the statutory reports. Not the label customers received, and not comparable with CY2018 on. CY2022-Aggregate Fuel Mix Time Series.xlsx ↗ (Info!A10; Info!A16)
Categories and shares as Commerce computed them from declared resources, the BPA system mix (BPA's own mix applied to BPA deliveries, remainder unspecified) and unspecified purchases; a declared resource needs ownership or an auditable contract and its REC; renewable power without the REC counts as unspecified. Not an emissions accounting.
Carbon allowances · no-cost allocationAn emissions allowance Washington assigns to an eligible utility without charge. It is not measured emissions.Definition ↗
Cap-and-investWashington’s program that limits covered greenhouse gas emissions and requires allowances for them.Definition ↗ period 1 · t CO2e
No-cost carbon allowances
1,020,697t CO2e
2023 calendar year
Source & method
Ecology's Electric Utility Allowance Allocation Schedule under WAC 173-446-230: allowances allocated at no cost to a CETA-obligated electric utility for the calendar year, one allowance = one metric ton of CO2 equivalent. An allocation computed from Ecology's forecast of the utility's Washington retail load and resource supply, not measured emissions and not a cap on the utility
2023 calendar year · reported · direct · valid · final
sheet AllowanceAllocation; Clark County PUD #1; 2023
Ecology's Electric Utility Allowance Allocation Schedule under WAC 173-446-230: allowances allocated at no cost to a CETA-obligated electric utility for the calendar year, one allowance = one metric ton of CO2 equivalent. An allocation computed from Ecology's forecast of the utility's Washington retail load and resource supply, not measured emissions and not a cap on the utility
2024 calendar year · reported · direct · valid · final
sheet AllowanceAllocation; Clark County PUD #1; 2024
Ecology's Electric Utility Allowance Allocation Schedule under WAC 173-446-230: allowances allocated at no cost to a CETA-obligated electric utility for the calendar year, one allowance = one metric ton of CO2 equivalent. An allocation computed from Ecology's forecast of the utility's Washington retail load and resource supply, not measured emissions and not a cap on the utility
2025 calendar year · reported · direct · valid · final
sheet AllowanceAllocation; Clark County PUD #1; 2025
Ecology's Electric Utility Allowance Allocation Schedule under WAC 173-446-230: allowances allocated at no cost to a CETA-obligated electric utility for the calendar year, one allowance = one metric ton of CO2 equivalent. An allocation computed from Ecology's forecast of the utility's Washington retail load and resource supply, not measured emissions and not a cap on the utility
2026 calendar year · reported · direct · valid · final
sheet AllowanceAllocation; Clark County PUD #1; 2026
The utility's no-cost allocation for the year multiplied by the settlement price of the most recent quarterly Cap-and-Invest auction. An illustration of scale, not revenue received: a utility consigns only part of its allocation, the price changes every quarter, and the proceeds of any sale must go back to customers
2026 calendar year · reported · derived · valid · final
2026 allocation at the $39.50 settlement price of auction #15 on 2026-09-02
At the settlement price of $39.50 per allowance from auction #15 on 2026-09-02 (Ecology’s summary report ↗), where 3,484,205 allowances were sold on behalf of consigning entities statewide. What the allocation would fetch at one auction's price. Utilities consign part of their allowances to these auctions and must return the proceeds to customers; the rest they hold for compliance or bank.
Allocated to “Clark County PUD #1” on Ecology’s schedule, filed as consumer-owned utility. A utility cannot sell these allowances to another company: it uses them for compliance, banks them, transfers them to an eligible generator, or consigns them to a quarterly auction, and the proceeds must go back to customers.
How Ecology computed each year
Year
Forecast WA load (MWh)
Forecast supply
Allowances (t CO2e)
Forecast filed in
2023
4,940,395MWh
Bonneville Power Administration 51.7% · Natural gas 38.6% · Renewable or non-emitting 3.5% · Unspecified market purchases 2.4%
1,020,697t CO2e
IRP
2024
4,985,474MWh
Bonneville Power Administration 52.8% · Natural gas 36.7% · Renewable or non-emitting 3.5% · Unspecified market purchases 4.5%
1,033,055t CO2e
IRP
2025
4,951,976MWh
Bonneville Power Administration 53.9% · Natural gas 35.2% · Renewable or non-emitting 3.5% · Unspecified market purchases 7.4%
Supply shares are Ecology’s forecast for the allocation, taken from the utility’s own filing. They are not the disclosed fuel mix above, which reports what was actually sold.
An allocation of allowances, not a measurement of emissions and not a cap on the utility. Ecology computes it from its forecast of the utility's Washington retail load and resource supply, and reissues the schedule as forecasts and the BPA emission factor change; the supply shares here are that forecast, not the disclosed fuel mix.
Money · FERC Form 1The annual financial report large investor-owned utilities file with the federal energy regulator.Definition ↗
FERC Form 1: not a respondent (public power, cooperative, federal or non-utility); checked PUDL v2026.9.0 respondent list 2026-09-18
Retail electricity sold
Full serviceA utility that sells electricity to customers. Full-service sales include both electricity and delivery.Definition ↗
Average revenue per kWhRevenue divided by electricity sold. This average is not a tariff or a household bill.Definition ↗ is realized revenue ÷ sales, not a tariff.
WA · commercial
Retail sales
1,365,364MWh
2024
Source & method
EIA-861 electricity sold to ultimate customers for the stated utility, state, customer class and service type; calendar year
2024 calendar year · reported · direct · valid · final
Sold to retail customers in the stated state (utility x state grain); bundled full-service rows only in the summaries; energy-only and delivery-only rows are listed but never added to bundled sales. Realized average revenue per kWh is not a tariff.
Clean-energy obligationsFive separate records of a clean-energy obligation, never merged: applicability (which statute reaches this utility and why), target (the figure as enacted or ordered, or as a filing or compilation restates it, with that standing marked), filed achievement (what the utility itself reported for a period), determination (what the issuing body decided about the filing, with its order number and date) and deciding event (the open proceeding, its next step and where to comment). A fuel-mix value is none of these, and a filing that restates a target does not enact it.Definition ↗
checked 2026-09-27
Five kinds kept apart: what applies, what is owed, what the utility filed, what the issuing body decided, and the open proceeding. The disclosed-supply block above is the same utility's fuel mix as Commerce computed it; read it beside these rows, never as a verdict on them. Rows checked through 2026-09-27; a row past its review date is marked, not removed.
Clean Energy Transformation Act RCW 19.405 ↗ · Washington State Department of Commerce (plan adopted by the utility's governing board)
Applicability not yet curated for this utility.
Clean energy implementation plan every four years (RCW 19.405.060) with interim targets; coal out of the allocation by 2025-12-31, greenhouse gas neutral retail sales from 2030-01-01, 100 percent renewable or nonemitting by 2045-01-01
What is owed The obligation as enacted or ordered; a utility’s own restatement does not enact it.
interim target for the 2022-2025 compliance periodcompiled Washington State Department of Commerce · CEIP Draft Aggregate Workbook 22.12.15.xlsx, sheet Interim targets· of retail electric load As the document puts itAnnual interim targets 2022 65, 2023 67, 2024 69, 2025 71 percent. Split over the period: renewable 61 percent, nonemitting 7 percent. Utility explanation: Clark Public Utilities' contract purchase of all Combine Hills II wind project generation and its 18% share of the Packwood hydro project are both 100% renewable energy purchases. Based on BPA's 2019 and 2020 fuel mix reports, 84% of BPA power is assumed to be renewable (hydro and wind) and 11% of BPA power is assumed to be non-emitting. Clark Public Utilities' BPA purchase is split approximately 50/50 between the block and slice products. Average water conditions were assumed for the BPA slice portion of Clark Public Utilities' BPA purchase. Clark Public Utilities' resource portfolio includes two emitting resources: o River Road Generating Plant (natural gas) o Unspecified market purchases. Based on BPA's fuel mix reports, 5% of BPA power is assumed to be unspecified market purchases. In 2012-20 economically displaced RRGP approximately 10 week or 2.5 months per year. The CEIP assumes no economic displacement in 2022, 2 weeks of displacement in 2023, 4 weeks of displacement in 2024 and 6 weeks of displacement in 2025. With more solar and wind coming on-line WECC-wide in the next 4 years it is expected that the opportunities to economically displace the plant with renewable power will increase each year. Given this trend, and the fact that RRGP has historically been economically displaced in January through July when hydro generation is plentiful, the CEIP assumes that renewable energy is procured to replace RRGP generation when the plant is economically displaced. Utility Number in the Commerce workbook is the EIA utility identifier.
eliminate coal-fired resources from the utility's allocation of electricityenacted Washington State Legislature · RCW 19.405.030 Coal-fired resources - Depreciation schedule - Penalties· of the utility's allocation of electricity supplied by coal-fired resources As the document puts itOn or before December 31, 2025. Excludes decommissioning and remediation costs; long-term BPA purchases are exempt unless the electricity is known to be coal-fired. The commission must set depreciation schedules ending no later than 2025-12-31.
greenhouse gas neutral retail sales, at least 80 percent from renewable and nonemitting resourcesenacted Washington State Legislature · RCW 19.405.040 Greenhouse gas neutral electricity supply· of retail sales of electricity to Washington retail electric customers As the document puts itBy January 1, 2030. Up to 20 percent of the obligation may be met by alternative compliance: alternative compliance payments, unbundled renewable energy credits or energy transformation projects. Four-year compliance periods 2030-2033, 2034-2037, 2038-2041 and 2042-2044.
nonemitting generation and renewable resources supply 100 percent of retail salesenacted Washington State Legislature · RCW 19.405.050 One hundred percent renewable and nonemitting electricity supply· of retail sales of electricity to Washington retail electric customers As the document puts itBy January 1, 2045, with an annual demonstration of compliance after that date.
What the utility filed Its own report of what it did; a number it reports, not a verdict.
Not yet curated As the document puts itThe atlas has not curated an assertion of this kind for this utility; this is the atlas's coverage, not the utility's record, and it is not a finding of compliance or of its absence The atlas has not curated this kind for this utility; that is the atlas’s coverage, not the utility’s record.
What the issuing body decided Orders and acknowledgments on the filings.
Not yet curated As the document puts itThe atlas has not curated an assertion of this kind for this utility; this is the atlas's coverage, not the utility's record, and it is not a finding of compliance or of its absence The atlas has not curated this kind for this utility; that is the atlas’s coverage, not the utility’s record.
The open proceeding Where the next decision is being made, and how to take part.
Not yet curated As the document puts itThe atlas has not curated an assertion of this kind for this utility; this is the atlas's coverage, not the utility's record, and it is not a finding of compliance or of its absence The atlas has not curated this kind for this utility; that is the atlas’s coverage, not the utility’s record.
What stays uncertain in these sources
No documented JSON API; the `apiproxy` host answered HTTP 500.30 all session and detail pages said "Record not found".The document endpoint served every filing read on 2026-09-19 and 2026-09-21; it remains undocumented.
resolved
Docket files before 2024 are not available. We are working to resolve the issue.
open
The collection of 2026-2029 CEIPs … are still ongoing.
open
Energy Independence Act (Initiative 937) RCW 19.285 ↗ · the utility's governing board, examined by the Washington State Auditor
Applicability not yet curated for this utility.
Biennial conservation acquisition target and an annual eligible-renewable target (15 percent of load from 2020) for utilities serving more than 25,000 Washington customers
What is owed The obligation as enacted or ordered; a utility’s own restatement does not enact it.
eligible renewable resources or renewable energy credits, or a combination, equal to at least 15 percent of load each year from 2020enacted Washington State Legislature · RCW 19.285.040 Energy conservation and renewable energy targets · (2)(a)(iii)· of the qualifying utility's load As the document puts it"At least 15 percent of its load by January 1, 2020, and each year thereafter" (2)(a)(iii), after 3 percent (2012-2015) and 9 percent (2016-2019). Initiative 937, approved 2006-11-07 (2007 c 1). Subsection (2) also provides alternative compliance paths (accelerated conservation and demand response; the four percent incremental-cost cap), so a utility can comply below 15 percent, as Clark Public Utilities does.
biennial conservation acquisition target for 2024-2025compiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · cell B7 As the document puts itBiennium 2024-2025. Prior biennium 2022-2023 target 82081 MWh; change from the 2022-2023 target -0.100316.
renewable energy target for 2026compiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Renewable by Utility· of average load 2024-2025 As the document puts itAverage load 2024-2025 4726287.640605 MWh. Clark invested 4 percent of its annual revenue requirement in renewables and used resource cost for EIA RPS compliance, so its qualifying share is below 15 percent.
What the utility filed Its own report of what it did; a number it reports, not a verdict.
conservation acquired in 2024compiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · cell C7 As the document puts itCounts toward the 2024-2025 biennial target.
2024-2025 conservation acquired as a share of retail load, as Commerce computed itcompiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · cell G7· of retail load over the biennial period's two load years (Commerce's sheet Select Data) As the document puts itCommerce's column G formula, (2024 acquired + 2025 acquired) / the biennial period's two load years on sheet Select Data (columns C and D); the cell's value, not recomputed. Commerce formats it as a percent to one decimal.
total conservation savings as a share of the 2024-2025 target, as Commerce computed itcompiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · cell F7· of the 2024-2025 conservation target in Commerce's column B As the document puts itCommerce's column F formula, (2024 acquired + 2025 acquired + excess from the prior two bienniums) / 2024-2025 target; the cell's value, not recomputed. Commerce formats it as a whole percent.
excess conservation carried from the prior two bienniums toward the 2024-2025 targetcompiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · cell E7 As the document puts itCommerce's column E.
conservation acquired in 2025compiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · cell D7 As the document puts itCounts toward the 2024-2025 biennial target.
qualifying renewable resources acquired for 2026compiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Renewable by Utility As the document puts itEqual to 0.080513 of average load 2024-2025; 2025 qualifying renewables were 715691 MWh. Incremental cost of eligible renewables as a share of revenue requirement 0.04. Clark invested 4 percent of its annual revenue requirement in renewables and used resource cost for EIA RPS compliance, so its qualifying share is below 15 percent.
What the issuing body decided Orders and acknowledgments on the filings.
Not yet curated As the document puts itThe atlas has not curated an assertion of this kind for this utility; this is the atlas's coverage, not the utility's record, and it is not a finding of compliance or of its absence The atlas has not curated this kind for this utility; that is the atlas’s coverage, not the utility’s record.
The open proceeding Where the next decision is being made, and how to take part.
Not yet curated As the document puts itThe atlas has not curated an assertion of this kind for this utility; this is the atlas's coverage, not the utility's record, and it is not a finding of compliance or of its absence The atlas has not curated this kind for this utility; that is the atlas’s coverage, not the utility’s record.
What stays uncertain in these sources
SAO says it examines "13 qualifying utilities" for EIA and "39 qualifying utilities" for CETA — the count difference (18 vs 13) is unexplained; cooperatives are audited independently.
open
After June 12, 2026, utilities will shift from annual reporting on EIA compliance progress to biennial reporting.
open
PDFs; findings are the legal compliance determinations for COUs.
Compiled by Commerce, not a compliance determination
RCW 19.285.040(1) ↗ · Washington State Department of Commerce, EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · utility reports submitted 2026-06-01 · checked 2026-09-27
Commerce's 2026 Energy Independence Act report summary, from the utilities' reports submitted 2026-06-01. Every value is Commerce's cell; the two percent columns are Commerce's own formulas, shown in Commerce's format and never recomputed. Rows are alphabetical and nothing is ranked. Whether a utility complied is decided by the commission for an investor-owned utility and examined by the State Auditor for a consumer-owned one.
Biennium 2024-2025. Each value is the publisher’s cell at the row and column given; this utility’s row is marked.
Utilitysheet row
TargetMWh · column B
Acquired in 2024MWh · column C
Acquired in 2025MWh · column D
Excess carried from the prior two bienniumsMWh · column E
Total savings, percent of the targetpercent, the publisher’s formula · column F
Acquired, percent of retail loadpercent, the publisher’s formula · column G
Consumer-owned utilities, each against its own targetEach sets its biennial target by action of its governing board (WAC 194-37-070(2) and (4)). A percent compares a utility with its own target, not with another utility's.
Investor-owned utilities, listed apartThe commission accepts these targets (WAC 480-109-120), and Commerce's target column does not use one basis for the three: each row says which figure Commerce printed, beside the commission's order.
Avista ↗row 3 Target column: Avista's total conservation goal: the commission's 63,374 MWh EIA target plus the 3,169 MWh decoupling penalty threshold (UE-230897 Order 01) 2024-2025 biennial conservation acquisition target accepted by the commission: 63,374 MWh · UE-230897 Order ↗2024-2025 EIA penalty threshold accepted by the commission: 47,635 MWh · UE-230897 Order ↗
66,543 MWh
51,580 MWh
45,279 MWh
0 MWh
146%
0.8%
PacifiCorp ↗row 15 Target column: the commission's 2024-2025 EIA target itself (UE-230904 Order 01); its penalty threshold is 74,839 MWh 2024-2025 biennial conservation acquisition target accepted by the commission: 84,971 MWh · UE-230904 Order ↗2024-2025 EIA penalty threshold accepted by the commission: 74,839 MWh · UE-230904 Order ↗
84,971 MWh
40,269 MWh
53,920 MWh
0 MWh
111%
1.2%
Puget Sound Energy ↗row 17 Target column: the commission's 2024-2025 EIA penalty threshold (UE-230892 Order 01), not its 304,400 MWh EIA target 2024-2025 biennial conservation acquisition target accepted by the commission: 304,400 MWh · UE-230892 Order ↗2024-2025 EIA penalty threshold accepted by the commission: 268,702 MWh · UE-230892 Order ↗
268,702 MWh
280,964 MWh
293,527 MWh
0 MWh
214%
1.4%
Totalrow 21 · Commerce's own line: its sum of all eighteen rows, the three investor-owned figures on their differing bases included. As printed, never recomputed.
SAIDISystem Average Interruption Duration Index: the minutes of sustained interruption the average customer had over the year, customer-minutes interrupted divided by customers served. Each utility calculates and reports its own figure on EIA-861 Schedule 3, under the method it declares. A system average says nothing about one address.Definition ↗, SAIFISystem Average Interruption Frequency Index: how many sustained interruptions the average customer had over the year, customers interrupted divided by customers served, as the utility reports it on EIA-861 Schedule 3.Definition ↗ and CAIDICustomer Average Interruption Duration Index: minutes per sustained interruption, SAIDI divided by SAIFI on the same basis. EIA-861 asks utilities for SAIDI and SAIFI only; EIA publishes CAIDI with the data and the atlas shows it as published, never recomputed.Definition ↗ count sustained interruptions. Figures with and without major event daysDays a utility sets apart from normal operation: EIA describes them as events such as snowstorms, floods or heatwaves, or periods of outages that differ greatly from the utility's own five-year history. EIA-861 asks for the indices both with and without them. Part B respondents determine them under IEEE 1366; Part C respondents define a major event themselves. The two series answer different questions and are never blended.Definition ↗ are different measures; compare like with like.
WA · IEEE 1366EIA-861 Schedule 3 has two parts. Part B is for utilities that calculate SAIDI and SAIFI and determine major event days under IEEE 1366-2003 or IEEE 1366-2012; Part C is for any other method, where the utility also states how it defines a momentary interruption and whether inactive accounts count as customers. Figures from the two parts are not comparable and the atlas never pools them; utilities under Part C do not share one method either.Definition ↗
Index
Major event days included
Major event days excluded
Included, loss of supply removed
SAIDIminutes/customer/year
144.8
59
126.2
SAIFIinterruptions/customer/year
1.47
1.13
1.13
CAIDIminutes/interruption
98.3
52.1
111.8
Customers the indices are based on
233,669 customers
Highest voltage counted as distribution
12.5 kV
How it was measuredDetermined under IEEE 1366-2003 or IEEE 1366-2012; the form does not record which edition
Outages recorded automatically: yes
Others reporting the same way · major event days included21 utilities in WA under IEEE 1366. Each counts once whatever its size; this is context, not a ranking.
SAIDI median 258.5 (52.9–1,887) minutes/customer/yearSAIFI median 1.41 interruptions/customer/year
Others reporting the same way · major event days excluded21 utilities in WA under IEEE 1366. Each counts once whatever its size; this is context, not a ranking.
SAIDI median 136.1 (39.5–604.7) minutes/customer/yearSAIFI median 1 interruptions/customer/year
Every year filed
As filed each year. SAIDI in minutes per customer per year; SAIFI in interruptions per customer per year. Blank cells were not reported.
Year
State
Standard
SAIDI with
SAIDI without
SAIFI with
SAIFI without
Customers
2024
WA
IEEE 1366
144.8
59
1.473
1.133
233,669
2023
WA
IEEE 1366
88.4
45
0.807
0.483
227,879
2022
WA
IEEE 1366
174.1
51.8
1.54
1.04
221,260
2021
WA
IEEE 1366
122.3
42.4
0.881
0.538
216,312
2020
WA
IEEE 1366
120.8
41.1
0.726
0.536
213,948
2019
WA
IEEE 1366
98.2
28.2
0.812
0.34
210,074
2018
WA
IEEE 1366
35.5
35.5
0.427
0.427
204,000
2017
WA
IEEE 1366
62.5
50.6
0.801
0.745
200,000
2016
WA
IEEE 1366
49.4
36.1
0.699
0.509
194,600
2015
WA
IEEE 1366
90.7
27.1
0.602
0.36
191,500
2014
WA
IEEE 1366
210.5
34.7
1.465
0.557
189,674
2013
WA
IEEE 1366
23.7
18.5
0.413
0.333
185,000
Reported by the utility on EIA-861 Schedule 3 under the method it declares. IEEE 1366 and other-method figures are not comparable, and values with and without major event days answer different questions. A system average says nothing about one address. CAIDI is published by EIA as SAIDI divided by SAIFI; it is not a line on the form. A value the utility left blank stays blank. Source and licence· Frozen facts for this utility ↗
Customer programmes
EIA-861 Schedule 6, as filed
Programme results as each utility filed them, by customer class and report year, each in its own unit. Classes are never added into a total, years are never added into a period, and savings are never divided by sales. The one ratio shown, enrolled demand-response customers against the utility's own EIA-861 customer count for the same state, class and year, carries both counts.
Energy efficiency EIA-861 Schedule 6 Part A
Reported by the utility on EIA-861 Schedule 6 Part A as adjusted gross savings at the customer meter under its own evaluation; figures are not comparable across utilities. Reporting-year incremental savings are annualized for participants new that year; life-cycle savings run over the programmes' planned life (energy as a lump sum, peak as the average annual reduction). Each class is shown as filed and the total row is the filer's own; nothing is summed here. Costs are nominal dollars of the report year (the form collects thousands; PUDL publishes dollars). A blank stays blank.
Report year 2024, WA. Each row is one customer class as filed; the filer's total is its own line and is not the sum of the rows above. Costs are nominal dollars.
Class
Incremental annual energy savings, reporting year (annualized)MWh
Customer incentives, incremental life-cycle cost (nominal)USD · life cycle
Other costs, incremental life-cycle (nominal)USD · life cycle
Other costs, reporting-year incremental (nominal)USD
CommercialBPAT
11,406 MWh
2.3 MW
102,654 MWh
2.3 MW
9 years
$2,583,000
$2,583,000
$86,000
$86,000
IndustrialBPAT
17,375 MWh
3.6 MW
191,125 MWh
3.6 MW
11 years
$3,916,000
$3,916,000
$0
$0
ResidentialBPAT
29,454 MWh
6 MW
88,362 MWh
6 MW
3 years
$2,556,000
$2,556,000
$386,000
$386,000
TransportationBPAT
not reported
not reported
not reported
not reported
not reported
not reported
not reported
not reported
not reported
Filer's totalBPAT
58,235 MWh
11.9 MW
382,141 MWh
11.9 MW
not applicable
$9,055,000
$9,055,000
$472,000
$472,000
Demand response EIA-861 Schedule 6 Part B
Reported by the utility on EIA-861 Schedule 6 Part B. Potential peak savings assume every programme is called; actual peak savings are what was achieved at the company's own annual peak hour, and the two are never merged. Customers are enrolled customers, a count. Costs are nominal dollars of the report year. The form has no total row and none is computed here. A blank stays blank.
Report year 2024, WA. Each row is one customer class as filed; the form has no total row and none is computed. Costs are nominal dollars.
Class
Customers enrolled in demand response programmescount
Energy savings from demand responseMWh
Potential peak demand savings, all demand response calledMW · potential
Actual peak demand savings at the annual system peak hourMW · achieved
Customer incentives (nominal)USD
Other programme costs (nominal)USD
Enrolled share of this class's customersderived
CommercialBPAT
not reported
not reported
not reported
not reported
not reported
not reported
not reported
IndustrialBPAT
5
381 MWh
11.1 MW
0 MW
$330,424
$0
16.7%5 of 30
ResidentialBPAT
629
46 MWh
not reported
0 MW
$36,700
$103,000
0.3%629 of 219,477
TransportationBPAT
not reported
not reported
not reported
not reported
not reported
not reported
not reported
Population: organizations of this release with EIA-861 rows in the core states. A short-form respondent has no figures to file; a long-form respondent without a row may have no programmes or may have a nonutility administrator reporting for it. Years without a row are listed against the table's span, not against the years this utility filed the form.
Distributed generationCustomer-sited and small generation reported by utilities in aggregate on EIA-861; no locations; a separate population from the plant inventory, never added to it.Definition ↗
Utility reports · no locations
Distributed generation reported by this utility to EIA-861 for 2024, by state
Utility-reported, no locations, not in the EIA-860 plant inventory (>= 1 MW). Storage is listed separately and never added to generation capacity. Non-net-metered units >= 1 MW can also appear in EIA-860; the overlap is disclosed, not resolved. Source rollup rows are excluded from every sum.
Sum of EIA-861 utility-reported nameplate capacity over leaf technology classes, excluding storage and source rollup rows; utility x state grain; no locations; not part of the EIA-860 plant inventory
2024 calendar year · reported · derived · valid · final
1 of 1 reporting utilities included.
net-metered + non-net-metered; the two EIA-861 schedules are disjoint by design
Customer counts can include the same customer under more than one technology. Energy sold to utilities measures exports; it does not measure all generation at customer sites.
Net-metered customers
3,098count
2024
Source & method
EIA-861 net metering customer count over leaf technology classes; a customer with two technologies can be counted twice by the source
2024 calendar year · reported · derived · valid · final
Washington State Legislature (RCW 19.405, RCW 19.285), Washington Utilities and Transportation Commission orders and docket filings, Washington State Department of Commerce EIA and CEIP report summaries, and each utility's own filings, cited per row
One assertion per row, five kinds kept apart: what applies, what is owed, what the utility filed, what the issuing body decided, and the open proceeding. A fuel-mix value is not a compliance verdict, and a filing that restates a target does not enact it; standing on each row says whose figure it is. An absent row states what was checked and when; a utility not in the file has not been curated.
Display names and aliases (pipeline/config/crosswalks/aliases.csv)
Display names verified against each organization's own website; EIA legal names retained as aliases
A display name is the name an organization uses for itself; the EIA name stays searchable and on the record. Each row cites the page that shows the name.
Catalyst Cooperative, PUDL v2026.9.0, derived from U.S. EIA Forms 860/923
Data transformed by PUDL from U.S. EIA forms; selected fields republished; EIA data is public with dated acknowledgment (https://www.eia.gov/about/copyrights_reuse.php)
Catalyst Cooperative, PUDL v2026.9.0, derived from U.S. EIA Forms 860/923
Data transformed by PUDL from U.S. EIA forms; selected fields republished; EIA data is public with dated acknowledgment (https://www.eia.gov/about/copyrights_reuse.php)
Catalyst Cooperative, PUDL v2026.9.0, derived from U.S. EIA Form 861
Data transformed by PUDL from U.S. EIA forms; selected fields republished; EIA data is public with dated acknowledgment (https://www.eia.gov/about/copyrights_reuse.php)
Catalyst Cooperative, PUDL v2026.9.0, derived from U.S. EIA Form 861
Data transformed by PUDL from U.S. EIA forms; selected fields republished; EIA data is public with dated acknowledgment (https://www.eia.gov/about/copyrights_reuse.php)
Catalyst Cooperative, PUDL v2026.9.0, derived from U.S. EIA Form 861
Data transformed by PUDL from U.S. EIA forms; selected fields republished; EIA data is public with dated acknowledgment (https://www.eia.gov/about/copyrights_reuse.php)
Catalyst Cooperative, PUDL v2026.9.0, derived from U.S. EIA Forms 860/923
Data transformed by PUDL from U.S. EIA forms; selected fields republished; EIA data is public with dated acknowledgment (https://www.eia.gov/about/copyrights_reuse.php)