Utility / owner / operatorRegional contextInvestor-owned utilityHow EIA classifies an organization, such as a public utility, cooperative or investor-owned company.Definition ↗
Operated nameplate capacity, operating generatorsFull nameplate MW of operating generators at plants this organization runs, including shares held by other owners.Definition ↗
2,136.6MW
Source & method
Sum of operating generator nameplate MW at plants where this organization is the reported operator
2024 inventory · reported · derived · valid · final
43 of 43 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 ↗
2,611.9MW
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: 0.9% of sales; unspecified purchases: 21.7%. Filed as claimant “PacifiCorp”.
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
4,256,364 MWh
Natural Gas 32.5% · Market 21.7% · Coal 19.7%
0.9%
21.7%
CY2023
3,984,915 MWh
Coal 34.8% · Market 20.4% · Natural Gas 18.8%
0.5%
20.4%
CY2022
4,327,543 MWh
Coal 41.1% · Natural Gas 17.5% · Wind 15.8%
0.6%
15.3%
CY2021
4,606,961 MWh
Coal 40.6% · Natural Gas 18.5% · Market 16.5%
0.8%
16.5%
CY2020
4,457,793 MWh
Coal 36.0% · Market 25.1% · Natural Gas 18.2%
2.3%
25.1%
CY2019
4,559,476 MWh
Coal 45.3% · Market 24.1% · Natural Gas 17.6%
1.5%
24.1%
CY2018
4,361,207 MWh
Coal 41.3% · Market 24.7% · Natural Gas 14.5%
3.6%
24.7%
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)
CY2017
4,609,855 MWh
Coal 44.5% · Hydro 20.3% · Market 18.3%
3.3%
18.3%
CY2016
4,432,074 MWh
Coal 40.7% · Market 23.9% · Hydro 16.4%
3.1%
23.9%
CY2015
— WithheldPacifiCorp's CY2015 sales sit under claimant 80 (Pacific Power (WA) w Adj) as one Utility Unspecified row of 4,528,663 MWh with no specified claims, and claimant 130 has no CY2015 rows. Commerce's own run of CY2015 under the same method (CY2022 Aggregate Fuel Mix Time Series, Post-2019 Methodology, column 2015) holds 9,895,807 MWh of Market and 10,188,318 MWh of Coal statewide; this extract sums to 14,427,604 and 7,164,461 MWh, its Market 4,531,797 MWh higher (about this row) and its other categories 4,474,690 MWh lower, where Coal agrees exactly in CY2014, CY2016 and CY2017: the row is not the utility's whole disclosure for the year (reviewed 2026-09-28)
CY2014
— WithheldPacifiCorp's row in the CY2014 extract totals 233,861 MWh, all unspecified, against the 4,117,647 MWh of Washington retail sales PacifiCorp reported to EIA for 2014 (EIA-861 via PUDL core_eia861__yearly_sales) and 3.98-4.61 million MWh under this claimant in every extract from CY2016 to CY2024: the row is not the utility's whole disclosure for the year (reviewed 2026-09-28)
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.
Oregon supply · DEQ supplier reportingOregon DEQ's Greenhouse Gas Reporting Program: every utility and electricity service supplier serving Oregon end users reports the MWh it delivered to them by source, and DEQ computes the emissions from its own emission factors and publishes both per supplier (OAR 340-215-0120). Bonneville Power Administration purchases are their own category. A different basis from Washington's fuel mix disclosure, and not a compliance determination.Definition ↗
2024 · Oregon end users
Electricity supplied to Oregon end users
14,270,935MWh
2024
Source & method
Oregon DEQ Greenhouse Gas Reporting Program (OAR 340-215-0120): the MWh DEQ lists for the supplier's electricity delivered to Oregon end users in the year, from specified sources (at the busbar, or with DEQ's 2% transmission-loss factor) and unspecified purchases; for a multi-jurisdictional utility, its Oregon retail sales including losses. Not generation, and not Washington's retail-sales basis
2024 calendar year · reported · direct · valid · final
Oregon DEQ Greenhouse Gas Reporting Program: the anthropogenic emissions DEQ's reporting system computes for the electricity the supplier delivered to Oregon end users, each source's MWh times DEQ's emission factor (unspecified power 0.428 t CO2e/MWh; a multi-jurisdictional utility's system factor applied to its Oregon MWh). An attribution from emission factors, not a stack measurement, and not a compliance determination under ORS 469A.410
2024 calendar year · estimated · direct · valid · final
Oregon DEQ's Emission Intensity column: the anthropogenic emissions it attributes to the supplier's Oregon deliveries divided by those MWh, as DEQ publishes it
2024 calendar year · estimated · direct · valid · final
Bonneville Power Administration: 0.8% of the MWh DEQ lists; unspecified purchases: 10.5%.Listed by DEQ as “Pacific Power (PacifiCorp)” (investor owned utility).
By year MWh supplied to Oregon end users and the emissions DEQ attributes to them; not generation, not a compliance finding
Oregon supply by year, on DEQ's basis
Year
Supplied · MWh
Emissions · t CO2e
Intensity · t CO2e/MWh
Fuel types · share of MWh
BPA · share
Unspecified · share
2019 on: by fuel type
2024
14,270,935 MWh
7,292,892 t CO2e
0.511 t CO2e/MWh
Coal 28.8% · Natural Gas 26.5% · Wind 16.3%
0.8%
10.5%
2023
14,228,213 MWh
7,653,943 t CO2e
0.538 t CO2e/MWh
Coal 37.8% · Natural Gas 21.4% · Wind 15.3%
0.4%
10.4%
2022
13,974,604 MWh
7,953,132 t CO2e
0.569 t CO2e/MWh
Coal 43.4% · Natural Gas 18.9% · Wind 14.8%
0.5%
7.6%
2021
13,780,530 MWh
8,257,701 t CO2e
0.599 t CO2e/MWh
Coal 46.6% · Natural Gas 17.9% · Wind 15.3%
0.3%
7.2%
2020
13,253,328 MWh
8,433,448 t CO2e
0.636 t CO2e/MWh
Coal 48.8% · Natural Gas 18.3% · Wind 11.5%
0.2%
9.8%
2019
13,117,259 MWh
9,042,557 t CO2e
0.689 t CO2e/MWh
Coal 55.9% · Natural Gas 14.0% · Unspecified 11.1%
0.3%
11.1%
Before 2019: totals onlyDEQ publishes fuel types from 2019, “when data collection was standardized in the Your DEQ Online reporting system” (workbook, Data Information)
2018
12,899,776 MWh
8,696,220 t CO2e
0.674 t CO2e/MWh
—
2017
13,236,666 MWh
8,628,965 t CO2e
0.652 t CO2e/MWh
—
2016
12,900,678 MWh
8,422,662 t CO2e
0.653 t CO2e/MWh
—
2015
13,119,710 MWh
9,701,719 t CO2e
0.739 t CO2e/MWh
—
2014
13,217,911 MWh
9,582,985 t CO2e
0.725 t CO2e/MWh
—
2013
13,351,768 MWh
9,626,625 t CO2e
0.721 t CO2e/MWh
—
2012
13,034,357 MWh
9,137,084 t CO2e
0.701 t CO2e/MWh
—
2011
13,274,864 MWh
8,880,884 t CO2e
0.669 t CO2e/MWh
—
2010
12,971,513 MWh
9,248,689 t CO2e
0.713 t CO2e/MWh
—
DEQ's basis (OAR 340-215-0120): electricity the supplier delivered to Oregon end users in the year, from specified sources (at the busbar, or with DEQ's 2% transmission-loss factor) and unspecified purchases, and the anthropogenic emissions DEQ's reporting system computes for it from DEQ's emission factors (unspecified power 0.428 t CO2e/MWh). A multi-jurisdictional utility reports its whole system and its Oregon retail sales including losses, and DEQ applies the system's factor to the Oregon figure. Not generation, not Washington's disclosure (a different basis, never added to it), and not a compliance determination.
Fuel types as DEQ names them: Bonneville Power Administration, Powerex and Tacoma are purchases from those systems, kept as their own categories and never resolved to plants; shares are of the MWh DEQ lists for the supplier, computed here from DEQ's rows.
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
2,489,384t 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
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
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
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
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 “PacifiCorp” on Ecology’s schedule, filed as investor-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
4,656,030MWh
Natural gas 21.6% · Renewable or non-emitting 27.5% · Unspecified market purchases 16.0% · Coal 34.9%
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 ↗
2025 · USD nominal
Purchased power, settlements
1,114,208,119USD
2025
Partial or uncertain coverage: 284 named sellers; 6 adjustment and 4 market-settlement rows and the filing total row excluded
Source & method
FERC Form 1 Schedule 326 total settlement over named sellers (adjustment rows excluded), nominal dollars for the report year
2025 calendar year · reported · derived · suspect · final
339 of 346 native rows included.
284 named sellers; 6 adjustment and 4 market-settlement rows and the filing total row excluded
Purchased power by seller Financial relationshipA documented financial relationship between named parties, with an amount where public and its reported or calculated basis.Definition ↗
Schedule 326 settlements for 2025, largest first(top 60 of 284). Seller names as filed; a link means a reviewed match to an organization in this atlas.
Seller (as filed)
Type
MWh
USD
USD/MWh
Grant PUD ↗ filed as “public utility district no. 2 of grant county”
california independent system operator corporationSF · market operator, not a bilateral seller
1,325,237 USD
california independent system operatorEX · market operator, not a bilateral seller
-59,091,032 USD
california independent system operatorEX · market operator, not a bilateral seller
-32,230,387 USD
california independent system operatorAD · market operator, not a bilateral seller
-3,778,361 USD
Adjustment rows filed on the same schedule (6)
ca solar retail customerLU · a mechanism, not a party
289,904 USD
ca solar retail customerAD · a mechanism, not a party
218,115 USD
idaho solar retail customerLU · a mechanism, not a party
10,109 USD
utah solar retail customerLU · a mechanism, not a party
16,299,169 USD
utah solar retail customerAD · a mechanism, not a party
Not reported USD
net power cost deferralsno type · a mechanism, not a party
648,185,422 USD
Missing cells stay missing; partial seller sums are marked and have no USD/MWh ratio. FERC Form 1 Schedule 326 rows for the report year; seller names as filed; an organization link exists only through a reviewed crosswalk row; MWh uses purchased_mwh through 2020 and purchased other than storage from 2021. A row counts as a seller when it names a party, whatever its purchase type: FERC's AD code marks an adjusting entry, and an adjusting entry naming a company is still money between that company and the respondent. Rows whose name is a mechanism (deferrals, allowances, the residential exchange) are listed as adjustments; rows naming a market operator are listed as market settlements
Revenue by customer class
Class
USD
MWh
USD/MWh
Customers (avg/month)
residential sales
2,769,186,023USD
18,269,615MWh
151.57 USD/MWh
1,867,245customers (monthly average)
small or commercial
2,504,346,609USD
22,673,128MWh
110.45 USD/MWh
233,923customers (monthly average)
large or industrial
1,675,916,847USD
18,167,642MWh
92.25 USD/MWh
32,689customers (monthly average)
public street and highway lighting
16,707,527USD
101,477MWh
164.64 USD/MWh
2,996customers (monthly average)
sales for resale
198,655,537USD
4,353,895MWh
45.63 USD/MWh
Not reported
Schedule 300 class lines as the form computes them (as_computed); usd_per_mwh is revenue over MWh sold for that class; the class lines are not re-summed here; EIA-861 revenue and price for the same utility are on the retail block and can differ (different survey, scope and year)
Operation and maintenance expenses
Total electric O&Mas the form computes it
5,093,553,255 USD
Power productionas the form computes it
3,530,583,993 USD
of which purchased power (account 555)reported line· account 555
1,676,351,194 USD
of which fuel, steam generation (501)reported line· account 501
862,964,197 USD
of which fuel, other generation (547)reported line· account 547
403,443,315 USD
Transmissionas the form computes it
294,174,783 USD
Distributionas the form computes it
363,892,002 USD
Customer accountsas the form computes it
93,627,273 USD
Customer service and informationas the form computes it
264,001,196 USD
Administrative and general, operationas the form computes it
508,619,665 USD
Administrative and general, maintenanceas the form computes it· account 935
38,654,343 USD
of which transmission by others (565)reported line· account 565
187,499,790 USD
Schedule 320 electric operation and maintenance: function totals as the form computes them (as_computed) with the purchased power, fuel and wheeling accounts listed beneath as components, never added again
Nominal dollars for the report year as filed; revisions arrive for months after the April deadline; the pinned PUDL release fixes the snapshot FERC respondent 303· XBRL entity C001646; link basis: pudl_assn_1to1.
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.
ID · commercial
Retail sales
577,677MWh
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 Utilities and Transportation Commission
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 2024filed PacifiCorp · docket UE-210829 · PacifiCorp 2025 Clean Energy Implementation Plan Progress Report, Table 1· of Washington retail electric sales As the document puts itTarget from the Revised 2021 CEIP filed 2023-03-13 in UE-210829. PacifiCorp reported 1,112,777 MWh, 27.1 percent of QF-adjusted Washington retail sales of 4,107,101 MWh, supplied by non-emitting and renewable resources in 2024. The 2023 Biennial Update proposed 25 percent for 2024; the UTC rejected the plan update on 2025-05-19 and granted a one-year exemption in Order 17 on 2025-06-27.
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.
interim target for 2026ordered PacifiCorp · docket UE-250617 · PacifiCorp 2025 Clean Energy Implementation Plan, Table 8; approved by UTC Order 01· of Washington retail electric sales As the document puts itFiled 2025-10-01 and approved as filed by Order 01, 2026-03-27 (https://apiproxy.utc.wa.gov/cases/GetDocument?docID=135&year=2025&docketNumber=250617), which lists the four annual targets at paragraph 5. Table 8 gives 1,353,697 MWh of renewable and non-emitting energy against 4,023,917 MWh of retail electric sales. A separate 2026 Protocol sensitivity and a low-renewable-output sensitivity in the same plan are not targets.
interim target for the 2026-2029 compliance periodordered PacifiCorp · docket UE-250617 · PacifiCorp 2025 Clean Energy Implementation Plan, Table 8; approved by UTC Order 01· of Washington retail electric sales As the document puts itThe plan's stated four-year average, 7,880,715 MWh against 16,750,396 MWh of retail electric sales. The 2025 CEIP Supplement filed 2026-05-14 under Order 01 conditions 1 and 4 restates the period at 37, 37, 48 and 68 percent, but says on its face that those figures are information only and do not re-cast the approved targets, so they are not recorded as targets here.
interim target for 2027ordered PacifiCorp · docket UE-250617 · PacifiCorp 2025 Clean Energy Implementation Plan, Table 8; approved by UTC Order 01· of Washington retail electric sales As the document puts itFiled 2025-10-01 and approved as filed by Order 01, 2026-03-27 (https://apiproxy.utc.wa.gov/cases/GetDocument?docID=135&year=2025&docketNumber=250617), which lists the four annual targets at paragraph 5. Table 8 gives 1,424,997 MWh of renewable and non-emitting energy against 4,160,614 MWh of retail electric sales. A separate 2026 Protocol sensitivity and a low-renewable-output sensitivity in the same plan are not targets.
interim target for 2028ordered PacifiCorp · docket UE-250617 · PacifiCorp 2025 Clean Energy Implementation Plan, Table 8; approved by UTC Order 01· of Washington retail electric sales As the document puts itFiled 2025-10-01 and approved as filed by Order 01, 2026-03-27 (https://apiproxy.utc.wa.gov/cases/GetDocument?docID=135&year=2025&docketNumber=250617), which lists the four annual targets at paragraph 5. Table 8 gives 2,055,679 MWh of renewable and non-emitting energy against 4,297,349 MWh of retail electric sales. A separate 2026 Protocol sensitivity and a low-renewable-output sensitivity in the same plan are not targets.
interim target for 2029ordered PacifiCorp · docket UE-250617 · PacifiCorp 2025 Clean Energy Implementation Plan, Table 8; approved by UTC Order 01· of Washington retail electric sales As the document puts itFiled 2025-10-01 and approved as filed by Order 01, 2026-03-27 (https://apiproxy.utc.wa.gov/cases/GetDocument?docID=135&year=2025&docketNumber=250617), which lists the four annual targets at paragraph 5. Table 8 gives 3,046,342 MWh of renewable and non-emitting energy against 4,268,516 MWh of retail electric sales. A separate 2026 Protocol sensitivity and a low-renewable-output sensitivity in the same plan are not targets.
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
All PDF; targets need hand transcription.
open
WAC 480-100-600 through -665 (CEIP content, biennial updates -640(11), public participation -655): snapshot; WAC not fetched.
open
Energy Independence Act (Initiative 937) RCW 19.285 ↗ · Washington Utilities and Transportation Commission
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.
2024-2025 biennial conservation acquisition target accepted by the commissionordered Washington Utilities and Transportation Commission · docket UE-230904 · Order 01 Accepting 2024-2033 Ten-Year Achievable Conservation Potential and 2024-2025 Biennial Conservation Target, Subject to Conditions · finding (7); ordering paragraph 25(1) As the document puts it"PacifiCorp's calculation of its 2024-2025 biennial conservation target (EIA Target) of 84,971 MWh is consistent with RCW 19.285.040(1) and WAC 480-109-120(1)"; the order also accepts a ten-year achievable potential of 406,486 MWh (2024-2033), an EIA penalty threshold of 74,839 MWh and a decoupling penalty threshold of 4,249 MWh (Order 12 in UE-152253); Staff's total two-year conservation goal is 89,220 MWh. Commerce's 2026 report summary carries 84,971 MWh as PacifiCorp's 2024-2025 target: the EIA target itself, neither the penalty threshold nor the total goal.
2024-2025 EIA penalty threshold accepted by the commissionordered Washington Utilities and Transportation Commission · docket UE-230904 · Order 01 Accepting 2024-2033 Ten-Year Achievable Conservation Potential and 2024-2025 Biennial Conservation Target, Subject to Conditions · finding (9); ordering paragraph 25(1) As the document puts it"PacifiCorp's calculation of its 2024-2025 EIA Penalty Threshold of 74,839 MWh is consistent with RCW 19.285.040(1) and WAC 480-109-120(1)". The threshold is the level below which RCW 19.285.060 penalties apply; the target is 84,971 MWh.
biennial conservation acquisition target for 2024-2025compiled Washington State Department of Commerce · EIA 2026 Report Summary and Detail.xlsx, sheet Conservation by Utility · cell B15· the commission's 2024-2025 EIA target itself (UE-230904 Order 01); its penalty threshold is 74,839 MWh As the document puts itBiennium 2024-2025. Prior biennium 2022-2023 target 94210 MWh; change from the 2022-2023 target -0.098068.
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 4057698.692 MWh.
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 C15 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 G15· 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 F15· 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 E15 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 D15 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 0.315288 of average load 2024-2025; 2025 qualifying renewables were 1027277 MWh. Incremental cost of eligible renewables as a share of revenue requirement -0.058712.
What the issuing body decided Orders and acknowledgments on the filings.
order accepting the 2024-2025 biennial conservation report: PacifiCorp in compliance with its biennial conservation targetsordered Washington Utilities and Transportation Commission · docket UE-230904 · Order 02 Accepting PacifiCorp's 2024-2025 Biennial Conservation Report · Table 1; findings (3)-(4); ordering paragraph 13(1) As the document puts itTable 1: total conservation goal 89,220 MWh, decoupling penalty threshold 4,249 MWh, total conservation achievement 94,188 MWh (106%), EIA target 84,971 MWh, EIA penalty threshold 74,839 MWh, penalty-liable achievement 84,676 MWh, excess savings 5,588 MWh. "PacifiCorp successfully met its conservation targets under the EIA and its decoupling commitment. As a result, PacifiCorp is in compliance with Order 1, WAC 480-109-120 and RCW 19.285.070"; "PacifiCorp achieved 5,588 MWh in excess conservation savings that may be used to mitigate shortfalls in the subsequent two biennial targets". Effective 2026-09-10.
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
"PSE exceeded its commission-approved target of 3,084,363 megawatt hours … acquiring 3,794,770" (news 2022, snapshot).
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 this utilityrow 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.
ID · 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
264.6
129.4
264.6
SAIFIinterruptions/customer/year
1.59
1.3
1.59
CAIDIminutes/interruption
166.4
99.6
166.4
Customers the indices are based on
89,035 customers
Highest voltage counted as distribution
34.5 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 included8 utilities in ID under IEEE 1366. Each counts once whatever its size; this is context, not a ranking.
SAIDI median 192.8 (8.6–264.6) minutes/customer/yearSAIFI median 1.22 interruptions/customer/year
Others reporting the same way · major event days excluded8 utilities in ID under IEEE 1366. Each counts once whatever its size; this is context, not a ranking.
SAIDI median 127.2 (6.8–198.9) minutes/customer/yearSAIFI median 0.93 interruptions/customer/year
OR · 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
368.4
107.6
367.4
SAIFIinterruptions/customer/year
1.41
0.88
1.36
CAIDIminutes/interruption
261.3
122.2
270.1
Customers the indices are based on
638,000 customers
Highest voltage counted as distribution
34.5 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 included12 utilities in OR under IEEE 1366. Each counts once whatever its size; this is context, not a ranking.
SAIDI median 439.1 (28.2–1,482.5) minutes/customer/yearSAIFI median 1.34 interruptions/customer/year
Others reporting the same way · major event days excluded11 utilities in OR under IEEE 1366. Each counts once whatever its size; this is context, not a ranking.
SAIDI median 107.6 (11.6–517.9) minutes/customer/yearSAIFI median 0.79 interruptions/customer/year
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
209.4
102
207.7
SAIFIinterruptions/customer/year
1.95
0.71
1.8
CAIDIminutes/interruption
107.4
143.6
115.4
Customers the indices are based on
138,254 customers
Highest voltage counted as distribution
34.5 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
ID
IEEE 1366
264.6
129.4
1.59
1.3
89,035
2024
OR
IEEE 1366
368.4
107.6
1.41
0.88
638,000
2024
WA
IEEE 1366
209.4
102
1.95
0.71
138,254
2023
ID
IEEE 1366
127.1
127.1
1.23
1.23
86,783
2023
OR
IEEE 1366
136.6
103.1
1.041
0.91
629,398
2023
WA
IEEE 1366
67
67
0.58
0.58
136,387
2022
ID
IEEE 1366
126.1
104.8
1.069
0.984
86,628
2022
OR
IEEE 1366
298
124.9
1.633
1.01
629,028
2022
WA
IEEE 1366
107.4
94.1
0.833
0.665
137,857
2021
ID
IEEE 1366
269.4
168.6
2.558
2.067
86,628
2021
OR
IEEE 1366
452.3
106.5
1.688
0.927
629,028
2021
WA
IEEE 1366
135.1
86.8
1.068
0.611
137,857
2020
ID
IEEE 1366
421.8
166
3.546
2.365
83,400
2020
OR
IEEE 1366
354
110.7
1.648
0.996
617,333
2020
WA
IEEE 1366
286
105.6
1.24
0.794
135,697
2019
ID
IEEE 1366
129.2
89.1
1.197
0.954
82,079
2019
OR
IEEE 1366
415.5
108.1
1.458
0.966
617,662
2019
WA
IEEE 1366
130.2
88.1
1.034
0.679
136,786
2018
ID
IEEE 1366
277.7
145.8
1.939
1.258
80,004
2018
OR
IEEE 1366
145.8
98
1.474
1.233
607,462
2018
WA
IEEE 1366
176.1
105.6
1.129
0.71
135,581
2017
ID
IEEE 1366
261.4
192.6
2.461
2.193
78,594
2017
OR
IEEE 1366
312
113.9
1.928
1.261
598,577
2017
WA
IEEE 1366
253.4
114.1
1.228
0.76
134,194
2016
ID
IEEE 1366
392.1
152.2
3.04
1.362
76,971
2016
OR
IEEE 1366
222.9
111.5
1.592
1.069
591,456
2016
WA
IEEE 1366
116.2
85.4
1.204
0.643
133,235
2015
ID
IEEE 1366
285.6
219.1
2.075
1.546
77,564
2015
OR
IEEE 1366
284.6
138.8
1.441
1.036
607,450
2015
WA
IEEE 1366
157.9
99.2
1.203
0.771
137,313
2014
ID
IEEE 1366
281.4
223
1.865
1.703
77,164
2014
OR
IEEE 1366
259.5
132.4
1.62
1.191
604,587
2014
WA
IEEE 1366
148.6
124.6
0.874
0.806
136,538
2013
ID
IEEE 1366
618.6
272.2
3.507
2.261
75,934
2013
OR
IEEE 1366
159.8
112.7
1.176
0.954
599,772
2013
WA
IEEE 1366
201.8
117.3
1.067
0.809
135,475
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, ID, 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
CommercialPACE
4,488 MWh
0.9 MW
58,921 MWh
0.9 MW
13.1 years
$628,864
$628,864
$1,300,568
$1,300,568
IndustrialPACE
3,161 MWh
0.6 MW
37,918 MWh
0.6 MW
12 years
$369,896
$369,896
$704,322
$704,322
ResidentialPACE
6,954 MWh
1.4 MW
25,413 MWh
1.4 MW
3.7 years
$467,838
$467,838
$635,065
$635,065
TransportationPACE
0 MWh
0 MW
0 MWh
0 MW
0 years
$0
$0
$0
$0
Filer's totalPACE
14,603 MWh
2.9 MW
122,252 MWh
2.9 MW
not applicable
$1,466,598
$1,466,598
$2,639,955
$2,639,955
CommercialPACW
24,579 MWh
3.4 MW
292,920 MWh
3.4 MW
11.9 years
$5,836,689
$5,836,689
$5,673,304
$5,673,304
IndustrialPACW
4,035 MWh
0.6 MW
52,278 MWh
0.6 MW
13 years
$878,689
$878,689
$1,015,443
$1,015,443
ResidentialPACW
12,141 MWh
1.7 MW
150,895 MWh
1.7 MW
12.4 years
$3,336,278
$3,336,278
$5,394,743
$5,394,743
TransportationPACW
0 MWh
0 MW
0 MWh
0 MW
0 years
$0
$0
$0
$0
Filer's totalPACW
40,754 MWh
5.6 MW
496,093 MWh
5.6 MW
not applicable
$10,051,656
$10,051,656
$12,083,490
$12,083,490
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, ID, OR. 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
CommercialPACE
not reported
not reported
not reported
not reported
not reported
not reported
not reported
IndustrialPACE
111
not reported
175 MW
121 MW
$1,578,463
$448,183
1.9%111 of 5,818
ResidentialPACE
not reported
not reported
not reported
not reported
not reported
not reported
not reported
TransportationPACE
not reported
not reported
not reported
not reported
not reported
not reported
not reported
CommercialPACW
not reported
not reported
not reported
not reported
not reported
not reported
not reported
IndustrialPACW
159
not reported
11 MW
8.8 MW
$358,532
$1,243,627
1.8%159 of 8,984
ResidentialPACW
not reported
not reported
not reported
not reported
not reported
not reported
not reported
TransportationPACW
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.
What the sheet says
TariffA utility’s published rates and charges, with an effective date.Definition ↗ · not a bill
Schedule 16· WA· effective 2026-01-01
Basic chargeper month, single-family; multi-family 6.75; three-phase 16.50 and 14.75
$8.50
EnergyResidential Service· WA UTC (tariff WN U-76, docket UE-250224)
0.10623 USD/kWh, all kWh
Adjustment schedules named on the sheetlisted, never added in
Schedule 80 summary of adjustments (91, 92 temporary coal cost, 93 decoupling, 94, 97 power cost adjustment, 98 Northwest Power Act credit)
5th revision of Sheet 16.1.Source sheet ↗read 2026-09-18
ModeledComputed billsA declared usage case priced on a published tariff sheet: kWh in one bill, the days it covers, and where the sheet has them a service size, dwelling type or jurisdiction and a season. The total is the schedule's own charges: the fixed charge plus the energy charge by tier. Where the same sheet prints prices for named adjustments or credits, a second, separately labelled total adds them; those prices change on their own schedules. Whatever the sheet only names, such as a city tax, is listed and never added, so neither total is a complete bill. It is an illustration, not a billing record, and it is not the realized average revenue per kWh that EIA-861 reports.Definition ↗ for 3 declared cases · Single-Phase, Single-Family Home. Prices are the sheet’s own; usage and days are assumptions.
Case
Schedule charges (USD)
With adjustments the sheet prices (USD)
Next kWh costs (USD/kWh)
Average (cents/kWh)
600 kWh over 30 days
$72.24
None priced on this sheet
$0.10623
12.04schedule charges ÷ kWh
900 kWh over 30 days
$104.11
None priced on this sheet
$0.10623
11.57schedule charges ÷ kWh
1,200 kWh over 30 days
$135.98
None priced on this sheet
$0.10623
11.33schedule charges ÷ kWh
How each total adds up
600 kWh over 30 days
Line
Quantity
Price
Amount (USD)
Basic Charge
1 month
$8.5000 per month
$8.50
Energy Charge
600 kWh
$0.10623 per kWh
$63.74
Schedule charges
$72.24
900 kWh over 30 days
Line
Quantity
Price
Amount (USD)
Basic Charge
1 month
$8.5000 per month
$8.50
Energy Charge
900 kWh
$0.10623 per kWh
$95.61
Schedule charges
$104.11
1,200 kWh over 30 days
Line
Quantity
Price
Amount (USD)
Basic Charge
1 month
$8.5000 per month
$8.50
Energy Charge
1,200 kWh
$0.10623 per kWh
$127.48
Schedule charges
$135.98
Named on the sheet without a price, so in neither total: Schedule 80. This sheet prices no adjustment, so there is no second total.
0.14499 USD/kWh, all kWh = delivery 0.06937 + supply 0.07562 (Schedule 200 base 0.02378, Schedule 201 net power costs 0.03777 and others)
Adjustment schedules named on the sheetlisted, never added in
Schedule 98 BPA credit -0.01331 USD/kWh on the first 2,000 kWh; schedules 93, 94, 96, 97, 190, 192, 202-207, 290-292
Read from the Oregon Price Summary, which states the prices in effect as of the effective date.Source sheet ↗read 2026-09-18· OpenEI entry ↗ dated 2026-01-01, a discovery index only
ModeledComputed billsA declared usage case priced on a published tariff sheet: kWh in one bill, the days it covers, and where the sheet has them a service size, dwelling type or jurisdiction and a season. The total is the schedule's own charges: the fixed charge plus the energy charge by tier. Where the same sheet prints prices for named adjustments or credits, a second, separately labelled total adds them; those prices change on their own schedules. Whatever the sheet only names, such as a city tax, is listed and never added, so neither total is a complete bill. It is an illustration, not a billing record, and it is not the realized average revenue per kWh that EIA-861 reports.Definition ↗ for 3 declared cases · Single Family. Prices are the sheet’s own; usage and days are assumptions.
Case
Schedule charges (USD)
With adjustments the sheet prices (USD)
Next kWh costs (USD/kWh)
Average (cents/kWh)
600 kWh over 30 days
$100.99
$104.45
$0.14499$0.14399 with adjustments
16.83schedule charges ÷ kWh
900 kWh over 30 days
$144.49
$147.65
$0.14499$0.14399 with adjustments
16.05schedule charges ÷ kWh
1,200 kWh over 30 days
$187.99
$190.85
$0.14499$0.14399 with adjustments
15.67schedule charges ÷ kWh
How each total adds up
600 kWh over 30 days
Line
Quantity
Price
Amount (USD)
Basic Charge
1 month
$14.0000 per month
$14.00
Energy Charge0–2000 kWh
600 kWh
$0.14499 per kWh
$86.99
Schedule charges
$100.99
System Benefits Charge (Schedule 291)adjustment priced on the sheet
600 kWh
$0.00065 per kWh
$0.39
Energy Trust of Oregon and Energy Efficiency Funding Charge (Schedule 292)adjustment priced on the sheet
600 kWh
$0.01166 per kWh
$7.00
BPA Credit (Schedule 98)adjustment priced on the sheet
600 kWh
$-0.01331 per kWh
$-7.99
Low Income Bill Payment Assistance Fund (Schedule 91)adjustment priced on the sheet
1 month
$1.4200 per month
$1.42
Low-Income Discount Cost Recovery Adjustment (Schedule 92)adjustment priced on the sheet
1 month
$2.6400 per month
$2.64
With adjustments the sheet prices
$104.45
900 kWh over 30 days
Line
Quantity
Price
Amount (USD)
Basic Charge
1 month
$14.0000 per month
$14.00
Energy Charge0–2000 kWh
900 kWh
$0.14499 per kWh
$130.49
Schedule charges
$144.49
System Benefits Charge (Schedule 291)adjustment priced on the sheet
900 kWh
$0.00065 per kWh
$0.59
Energy Trust of Oregon and Energy Efficiency Funding Charge (Schedule 292)adjustment priced on the sheet
900 kWh
$0.01166 per kWh
$10.49
BPA Credit (Schedule 98)adjustment priced on the sheet
900 kWh
$-0.01331 per kWh
$-11.98
Low Income Bill Payment Assistance Fund (Schedule 91)adjustment priced on the sheet
1 month
$1.4200 per month
$1.42
Low-Income Discount Cost Recovery Adjustment (Schedule 92)adjustment priced on the sheet
1 month
$2.6400 per month
$2.64
With adjustments the sheet prices
$147.65
1,200 kWh over 30 days
Line
Quantity
Price
Amount (USD)
Basic Charge
1 month
$14.0000 per month
$14.00
Energy Charge0–2000 kWh
1,200 kWh
$0.14499 per kWh
$173.99
Schedule charges
$187.99
System Benefits Charge (Schedule 291)adjustment priced on the sheet
1,200 kWh
$0.00065 per kWh
$0.78
Energy Trust of Oregon and Energy Efficiency Funding Charge (Schedule 292)adjustment priced on the sheet
1,200 kWh
$0.01166 per kWh
$13.99
BPA Credit (Schedule 98)adjustment priced on the sheet
1,200 kWh
$-0.01331 per kWh
$-15.97
Low Income Bill Payment Assistance Fund (Schedule 91)adjustment priced on the sheet
1 month
$1.4200 per month
$1.42
Low-Income Discount Cost Recovery Adjustment (Schedule 92)adjustment priced on the sheet
1 month
$2.6400 per month
$2.64
With adjustments the sheet prices
$190.85
Named on the sheet without a price, so in neither total: Public Purpose Charge (Schedule 290).
Schedule 135· Net Metering Service· effective 2021-01-01
Net excess generation becomes a kilowatt-hour credit on the following bill; any credit still unused after the March billing period each year is granted to the company without compensation. Meter aggregation is available to designated and aggregated meters
Schedule 136 carries the interconnection terms.Source ↗read 2026-09-18
The price on the utility's own sheet on the date it was read, with the adjustment schedules it names listed beside it and never added in. It is not a bill, and it is not the realized average revenue per kWh that EIA-861 reports above: the two answer different questions.
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
28,344count
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)
2010-2024 Greenhouse Gas Emissions From Electricity Use (ghgElectricityEms.xlsx; sheets Emissions and Power by Year and Raw Data 2019-2024), last modified 2026-06-15
Oregon Department of Environmental Quality, Greenhouse Gas Reporting Program, 2010-2024 Greenhouse Gas Emissions From Electricity Use
Each electricity supplier's electricity delivered to Oregon end users in MWh, and the anthropogenic emissions DEQ computes for it in metric tons CO2e from its own emission factors, by year, and by fuel type from 2019 (OAR 340-215-0120). Specified sources are reported at the busbar or with DEQ's 2% transmission-loss factor; unspecified purchases carry 0.428 t CO2e/MWh; a multi-jurisdictional utility reports its whole system and its Oregon retail sales including losses, and DEQ applies the system's factor to the Oregon figure. Bonneville Power Administration, Powerex and Tacoma are fuel types in DEQ's workbook and stay their own categories, never resolved to plants. Not generation, not Washington's Fuel Mix Disclosure (a different basis), and not a compliance determination.