Listed by EIA as “Idaho Power Co”.
Operates 31 plants (2,589.8 MW); owns 2,589.8 MW share-weighted; sells retail electricity.
2024 inventory
Sum of operating generator nameplate MW at plants where this organization is the reported operator
2024 inventory · reported · derived · valid · final
31 of 31 plants included.
Reported operating capacity; partial plant/unit coverage is marked
out_eia__yearly_utilities.parquet; report_date=2024-01-01; utility_id_eia=9191
Publisher & attribution ↗ Cite this released fact ↗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
22 of 22 plants included.
out_eia__yearly_utilities.parquet; report_date=2024-01-01; utility_id_eia=9191
Publisher & attribution ↗ Cite this released fact ↗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.
Not a Washington retail supplier in the Fuel Mix Disclosure extracts (CY2014–CY2024 loaded), or not linked by the reviewed claimant crosswalk
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
Emissions and Power by Year!AR51
Publisher & attribution ↗ Cite this released fact ↗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
Emissions and Power by Year!AS51
Publisher & attribution ↗ Cite this released fact ↗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
Emissions and Power by Year!AT51
Publisher & attribution ↗ Cite this released fact ↗Bonneville Power Administration: 0.0% of the MWh DEQ lists; unspecified purchases: 8.6%.Listed by DEQ as “Idaho Power Company” (investor owned utility).
| 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 | 673,939 MWh | 189,441 t CO2e | 0.281 t CO2e/MWh | Hydro 39.5% · Natural Gas 24.6% · Wind 10.4% | 0.0% | 8.6% |
| 2023 | 649,615 MWh | 180,954 t CO2e | 0.279 t CO2e/MWh | Hydro 38.9% · Natural Gas 16.3% · Coal 13.7% | 0.0% | 12.5% |
| 2022 | 695,393 MWh | 244,123 t CO2e | 0.351 t CO2e/MWh | Hydro 32.4% · Coal 20.7% · Unspecified 17.2% | 0.0% | 17.2% |
| 2021 | 685,578 MWh | 228,124 t CO2e | 0.333 t CO2e/MWh | Hydro 34.6% · Coal 17.8% · Natural Gas 16.6% | 0.0% | 15.1% |
| 2020 | 668,085 MWh | 206,060 t CO2e | 0.308 t CO2e/MWh | Hydro 44.4% · Coal 22.1% · Natural Gas 12.6% | 0.0% | 5.3% |
| 2019 | 826,131 MWh | 204,311 t CO2e | 0.247 t CO2e/MWh | Hydro 48.6% · Coal 16.7% · Natural Gas 11.7% | 0.0% | 6.1% |
| 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 | 837,162 MWh | 203,015 t CO2e | 0.243 t CO2e/MWh | — | ||
| 2017 | 830,376 MWh | 196,249 t CO2e | 0.236 t CO2e/MWh | — | ||
| 2016 | 775,754 MWh | 253,054 t CO2e | 0.326 t CO2e/MWh | — | ||
| 2015 | 754,251 MWh | 281,029 t CO2e | 0.373 t CO2e/MWh | — | ||
| 2014 | 775,493 MWh | 301,226 t CO2e | 0.388 t CO2e/MWh | — | ||
| 2013 | 772,644 MWh | 338,760 t CO2e | 0.438 t CO2e/MWh | — | ||
| 2012 | 772,917 MWh | 266,286 t CO2e | 0.345 t CO2e/MWh | — | ||
| 2011 | 866,523 MWh | 244,726 t CO2e | 0.282 t CO2e/MWh | — | ||
| 2010 | 778,669 MWh | 351,388 t CO2e | 0.451 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.
Oregon Department of Environmental Quality, Greenhouse Gas Reporting Program, 2010-2024 Greenhouse Gas Emissions From Electricity Use · DEQ's own electricity supplier workbook (2010–2024) ↗
Not a CETA-obligated electric utility in Ecology's allowance schedule (or not linked by the reviewed crosswalk); only Washington retail utilities subject to the Clean Energy Transformation Act receive no-cost allowances. Checked wa-ecology-cca-allowances 2026-09-18
FERC Form 1 Schedule 326 total settlement over named sellers (adjustment rows excluded), nominal dollars for the report year
2025 calendar year · reported · derived · valid · final
214 of 214 native rows included.
197 named sellers; 0 adjustment and 1 market-settlement rows and the filing total row excluded
utility_id_ferc1=216; report_year=2025
Publisher & attribution ↗ Cite this released fact ↗Partial or uncertain coverage: Sum of reported MWh on named counterparty rows; missing cells are excluded and coverage is explicit
FERC Form 1 Schedule 326 purchased MWh over named sellers (purchased_mwh through 2020, purchased other than storage from 2021)
2025 calendar year · reported · derived · suspect · final
212 of 214 native rows included.
Sum of reported MWh on named counterparty rows; missing cells are excluded and coverage is explicit
utility_id_ferc1=216; report_year=2025
Publisher & attribution ↗ Cite this released fact ↗FERC Form 1 Schedule 300 sales to ultimate consumers plus sales for resale, nominal dollars
2025 calendar year · reported · direct · valid · final
The form's own electric operating revenues total (Schedule 300), as filed
utility_id_ferc1=216; report_year=2025
Publisher & attribution ↗ Cite this released fact ↗Schedule 326 settlements for 2025, largest first(top 60 of 197). Seller names as filed; a link means a reviewed match to an organization in this atlas.
| Seller (as filed) | Type | MWh | USD | USD/MWh |
|---|---|---|---|---|
| Elkhorn Valley Wind filed as “telocaset wind power partners llc” | long_unit | 306,412MWh | 23,312,919USD | 76.08 USD/MWh |
| shell energy north america (us), l.p. | short_firm | 512,803MWh | 20,214,517USD | 39.42 USD/MWh |
| neal hot springs unit #1 | long_unit | 152,270MWh | 19,342,744USD | 127.03 USD/MWh |
| phillips 66 energy trading llc | short_firm | 530,846MWh | 19,300,646USD | 36.36 USD/MWh |
| rockland wind farm | long_unit | 219,377MWh | 17,608,230USD | 80.26 USD/MWh |
| ceyw excess generation | other_service | 0MWh | 15,327,316USD | Not reported |
| Grand View PV Solar Two, LLC filed as “grand view pv solar two” | long_unit | 185,695MWh | 13,455,919USD | 72.46 USD/MWh |
| powin llc | other_service | 0MWh | -12,462,239USD | Not reported |
| demand response avoided energy | other_service | 0MWh | 8,939,724USD | Not reported |
| franklin solar llc | long_unit | 240,371MWh | 7,099,897USD | 29.54 USD/MWh |
| raft river energy i llc | long_unit | 88,140MWh | 6,413,045USD | 72.76 USD/MWh |
| tuana springs expansion | long_unit | 63,610MWh | 6,266,599USD | 98.52 USD/MWh |
| Jackpot Solar filed as “jackpot holdings, llc” | long_unit | 270,421MWh | 6,042,917USD | 22.35 USD/MWh |
| id solar 1 | long_unit | 91,991MWh | 5,922,077USD | 64.38 USD/MWh |
| on-site generation - exports | other_service | 0MWh | 5,908,066USD | Not reported |
| cp energy marketing (us) inc. | short_firm | 151,925MWh | 5,462,989USD | 35.96 USD/MWh |
| two ponds windfarm | long_unit | 55,098MWh | 5,260,469USD | 95.47 USD/MWh |
| desert meadow windfarm | long_unit | 53,766MWh | 5,143,775USD | 95.67 USD/MWh |
| macquarie energy llc | short_firm | 94,000MWh | 5,039,844USD | 53.62 USD/MWh |
| hammett hill windfarm | long_unit | 52,591MWh | 5,018,693USD | 95.43 USD/MWh |
| idaho winds llc - sawtooth wind project | long_unit | 49,737MWh | 5,016,185USD | 100.85 USD/MWh |
| camp reed wind park | long_unit | 59,978MWh | 4,987,544USD | 83.16 USD/MWh |
| mainline windfarm | long_unit | 51,772MWh | 4,938,174USD | 95.38 USD/MWh |
| yahoo creek wind park | long_unit | 58,793MWh | 4,898,827USD | 83.32 USD/MWh |
| payne's ferry wind park | long_unit | 57,977MWh | 4,822,598USD | 83.18 USD/MWh |
| high mesa wind project | long_unit | 76,368MWh | 4,802,846USD | 62.89 USD/MWh |
| ryegrass windfarm | long_unit | 48,227MWh | 4,596,054USD | 95.3 USD/MWh |
| cold springs windfarm | long_unit | 46,182MWh | 4,406,150USD | 95.41 USD/MWh |
| adm investor services, inc. | other_service | 0MWh | 4,260,787USD | Not reported |
| salmon falls wind | long_unit | 58,266MWh | 4,163,420USD | 71.46 USD/MWh |
| transalta energy marketing (u.s.) inc. | short_firm | 84,564MWh | 4,134,867USD | 48.9 USD/MWh |
| avangrid power, llc | short_firm | 78,725MWh | 3,843,991USD | 48.83 USD/MWh |
| burley butte wind park | long_unit | 54,140MWh | 3,841,622USD | 70.96 USD/MWh |
| mercuria energy america, llc | short_firm | 99,968MWh | 3,711,263USD | 37.12 USD/MWh |
| j r simplot co. | long_unit | 66,125MWh | 3,616,857USD | 54.7 USD/MWh |
| horseshoe bend hydro | long_unit | 46,815MWh | 3,602,488USD | 76.95 USD/MWh |
| milner dam wind | long_unit | 50,520MWh | 3,590,440USD | 71.07 USD/MWh |
| salt river project | short_firm | 96,650MWh | 3,464,782USD | 35.85 USD/MWh |
| Simcoe Solar filed as “simcoe solar, llc” | long_unit | 48,890MWh | 3,444,400USD | 70.45 USD/MWh |
| Orchard Ranch Solar, LLC filed as “orchard ranch solar, llc” | long_unit | 45,754MWh | 3,158,090USD | 69.02 USD/MWh |
| marysville hydro partners- fall river | long_unit | 43,350MWh | 3,138,353USD | 72.4 USD/MWh |
| American Falls Solar II, LLC filed as “american falls solar ii, llc” | long_unit | 45,466MWh | 3,085,178USD | 67.86 USD/MWh |
| American Falls Solar LLC filed as “american falls solar, llc” | long_unit | 43,268MWh | 3,075,027USD | 71.07 USD/MWh |
| bennett creek wind farm | long_unit | 36,929MWh | 2,864,812USD | 77.58 USD/MWh |
| black mesa energy, llc | long_unit | 84,647MWh | 2,836,096USD | 33.5 USD/MWh |
| Murphy Flat Power, LLC filed as “murphy flat power, llc” | long_unit | 40,951MWh | 2,803,715USD | 68.47 USD/MWh |
| Portland General Electric filed as “portland general electric company” | short_firm, other_service | 82,927MWh | 2,693,762USD | 32.48 USD/MWh |
| jackalope wind, llc | other_service | 0MWh | -2,639,468USD | Not reported |
| hot springs wind farm | long_unit | 33,052MWh | 2,570,704USD | 77.78 USD/MWh |
| hazelton a | long_unit | 24,869MWh | 2,533,848USD | 101.89 USD/MWh |
| mt. home solar 1, llc | long_unit | 48,243MWh | 2,504,432USD | 51.91 USD/MWh |
| oregon trail wind park | long_unit | 34,931MWh | 2,483,280USD | 71.09 USD/MWh |
| willow spring windfarm | long_unit | 30,526MWh | 2,382,981USD | 78.06 USD/MWh |
| south forks joint venture-lowline canal | long_unit | 26,126MWh | 2,313,460USD | 88.55 USD/MWh |
| bypass | long_unit | 28,276MWh | 2,233,991USD | 79.01 USD/MWh |
| pilgrim stage station wind park | long_unit | 30,712MWh | 2,193,130USD | 71.41 USD/MWh |
| wilson lake hydro | long_unit | 26,968MWh | 2,158,438USD | 80.04 USD/MWh |
| altop energy trading llc | short_firm | 29,394MWh | 2,056,064USD | 69.95 USD/MWh |
| benson creek windfarm | long_unit | 26,324MWh | 2,055,824USD | 78.1 USD/MWh |
| golden valley wind park | long_unit | 28,932MWh | 2,033,243USD | 70.28 USD/MWh |
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
| Class | USD | MWh | USD/MWh | Customers (avg/month) |
|---|---|---|---|---|
| residential sales | 708,143,132USD | 6,010,290MWh | 117.82 USD/MWh | 554,211customers (monthly average) |
| small or commercial | 588,284,867USD | 6,366,016MWh | 92.41 USD/MWh | 97,672customers (monthly average) |
| large or industrial | 270,596,771USD | 3,778,206MWh | 71.62 USD/MWh | 149customers (monthly average) |
| public street and highway lighting | 4,516,904USD | 25,247MWh | 178.91 USD/MWh | 5,229customers (monthly average) |
| sales for resale | 124,539,480USD | 2,896,549MWh | 43 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)
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 216· XBRL entity C000620; link basis: pudl_assn_1to1.
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.
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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=commercial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=commercial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · valid · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=commercial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=industrial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=industrial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · valid · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=industrial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=residential; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=residential; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · valid · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=residential; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=transportation; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=transportation; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · not_applicable · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=ID; customer_class=transportation; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=commercial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=commercial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · valid · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=commercial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=industrial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=industrial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · valid · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=industrial; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=residential; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=residential; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · valid · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=residential; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=transportation; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗EIA-861 customer count for the stated utility, state, class and service type; year-end
2024 calendar year · reported · direct · valid · final
1 of 1 native rows included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=transportation; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗revenue_usd / (sales_mwh x 10) over bundled (full-service) rows only; a realized average, not a tariff or marginal rate
2024 calendar year · reported · derived · not_applicable · final
1 of 1 native rows with both revenue and sales included.
core_eia861__yearly_sales.parquet; report_date=2024-01-01; utility_id_eia=9191; state=OR; customer_class=transportation; business_model=retail; service_type=bundled
Publisher & attribution ↗ Cite this released fact ↗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.
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.
| Index | Major event days included | Major event days excluded | Included, loss of supply removed |
|---|---|---|---|
| SAIDIminutes/customer/year | 206.5 | 164 | 160.6 |
| SAIFIinterruptions/customer/year | 1.37 | 1.21 | 1.04 |
| CAIDIminutes/interruption | 150.7 | 135.5 | 154.4 |
| Index | Major event days included | Major event days excluded | Included, loss of supply removed |
|---|---|---|---|
| SAIDIminutes/customer/year | 509.9 | 434.8 | 234.6 |
| SAIFIinterruptions/customer/year | 2.57 | 2.48 | 1.55 |
| CAIDIminutes/interruption | 198.4 | 175.3 | 151.3 |
| Year | State | Standard | SAIDI with | SAIDI without | SAIFI with | SAIFI without | Customers |
|---|---|---|---|---|---|---|---|
| 2024 | ID | IEEE 1366 | 206.5 | 164 | 1.37 | 1.21 | 621,746 |
| 2024 | OR | IEEE 1366 | 509.9 | 434.8 | 2.57 | 2.48 | 20,146 |
| 2023 | ID | IEEE 1366 | 130.4 | 119.7 | 1.07 | 1 | 605,929 |
| 2023 | OR | IEEE 1366 | 174.3 | 165.4 | 1.34 | 1.31 | 19,518 |
| 2022 | ID | IEEE 1366 | 152.5 | 151.7 | 1.17 | 1.17 | 591,458 |
| 2022 | OR | IEEE 1366 | 129.1 | 128.8 | 0.79 | 0.78 | 19,867 |
| 2021 | ID | IEEE 1366 | 160.9 | 119.8 | 1.36 | 1.09 | 577,694 |
| 2021 | OR | IEEE 1366 | 214 | 197.1 | 1.48 | 1.42 | 19,677 |
| 2020 | ID | IEEE 1366 | 209.8 | 160.5 | 1.23 | 1.09 | 561,795 |
| 2020 | OR | IEEE 1366 | 185 | 165.8 | 0.97 | 0.9 | 19,515 |
| 2019 | ID | IEEE 1366 | 144 | 120 | 1.24 | 1.15 | 546,775 |
| 2019 | OR | IEEE 1366 | 121 | 118 | 0.63 | 0.63 | 19,231 |
| 2018 | ID | IEEE 1366 | 128.8 | 121.5 | 1.07 | 1.06 | 532,420 |
| 2018 | OR | IEEE 1366 | 148.7 | 148.7 | 0.95 | 0.95 | 18,963 |
| 2017 | ID | IEEE 1366 | 234 | 210 | 1.53 | 1.48 | 520,392 |
| 2017 | OR | IEEE 1366 | 221 | 220 | 1.23 | 1.22 | 18,780 |
| 2016 | ID | IEEE 1366 | 159.4 | 159.4 | 1.18 | 1.18 | 510,888 |
| 2016 | OR | IEEE 1366 | 173.2 | 173.2 | 1.06 | 1.06 | 18,790 |
| 2015 | ID | IEEE 1366 | 208 | 165.5 | 1.57 | 1.357 | 501,205 |
| 2015 | OR | IEEE 1366 | 370.9 | 368.2 | 1.948 | 1.931 | 18,651 |
| 2014 | ID | IEEE 1366 | 151.7 | 126.6 | 1.19 | 1.08 | 493,581 |
| 2014 | OR | IEEE 1366 | 205.9 | 203.3 | 1.63 | 1.59 | 18,500 |
| 2013 | ID | IEEE 1366 | 180 | 145 | 1.36 | 1.27 | 486,306 |
| 2013 | OR | IEEE 1366 | 419 | 277 | 2.41 | 2.01 | 18,349 |
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 ↗
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.
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.
| Class | Incremental annual energy savings, reporting year (annualized)MWh | Incremental annual peak demand savings, reporting yearMW | Incremental life-cycle energy savings (lump sum over the programmes' life)MWh · life cycle | Incremental life-cycle peak demand savings (average annual over the programmes' life)MW · life cycle | Weighted average life of the energy-efficiency portfolioyears | Customer incentives, reporting-year incremental cost (nominal)USD | 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 |
|---|---|---|---|---|---|---|---|---|---|
| CommercialIPCO | 31,531 MWh | 3.6 MW | 409,899 MWh | 3.6 MW | 13 years | $5,843,000 | $5,843,000 | $2,906,000 | $2,906,000 |
| IndustrialIPCO | 72,469 MWh | 8.3 MW | 1,014,568 MWh | 8.3 MW | 14 years | $7,725,000 | $7,725,000 | $6,724,000 | $6,724,000 |
| ResidentialIPCO | 35,547 MWh | 4.1 MW | 142,189 MWh | 4.1 MW | 4 years | $489,000 | $489,000 | $5,625,000 | $5,625,000 |
| TransportationIPCO | 0 MWh | 0 MW | 0 MWh | 0 MW | 0 years | $0 | $0 | $0 | $0 |
| Filer's totalIPCO | 139,547 MWh | 16 MW | 1,566,656 MWh | 16 MW | not applicable | $14,057,000 | $14,057,000 | $15,255,000 | $15,255,000 |
| CommercialIPCO | 272 MWh | 0 MW | 3,532 MWh | 0 MW | 13 years | $32,000 | $32,000 | $101,000 | $101,000 |
| IndustrialIPCO | 3,345 MWh | 0.4 MW | 46,831 MWh | 0.4 MW | 14 years | $457,000 | $457,000 | $273,000 | $273,000 |
| ResidentialIPCO | 435 MWh | 0.1 MW | 1,741 MWh | 0.1 MW | 5 years | $19,000 | $19,000 | $148,000 | $148,000 |
| TransportationIPCO | 0 MWh | 0 MW | 0 MWh | 0 MW | 0 years | $0 | $0 | $0 | $0 |
| Filer's totalIPCO | 4,052 MWh | 0.5 MW | 52,104 MWh | 0.5 MW | not applicable | $508,000 | $508,000 | $522,000 | $522,000 |
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.
| 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 |
|---|---|---|---|---|---|---|---|
| CommercialIPCO | 299 | 0 MWh | 27.8 MW | 23.8 MW | $504,900 | $80,300 | 0.4%299 of 75,435 |
| IndustrialIPCO | 2,481 | 0 MWh | 241.3 MW | 187.2 MW | $8,099,900 | $561,400 | 12.3%2,481 of 20,187 |
| ResidentialIPCO | 17,451 | 0 MWh | 22.3 MW | 20.4 MW | $345,800 | $578,500 | 3.3%17,451 of 525,751 |
| TransportationIPCO | 0 | 0 MWh | 0 MW | 0 MW | $0 | $0 | unsupported |
| CommercialIPCO | 10 | 0 MWh | 10.3 MW | 8.8 MW | $201,300 | $4,200 | 0.3%10 of 3,666 |
| IndustrialIPCO | 36 | 0 MWh | 1.7 MW | 1.3 MW | $43,700 | $73,200 | 1.5%36 of 2,430 |
| ResidentialIPCO | 190 | 0 MWh | 0.3 MW | 0.2 MW | $3,700 | $30,200 | 1.3%190 of 14,098 |
| TransportationIPCO | 0 | 0 MWh | 0 MW | 0 MW | $0 | $0 | unsupported |
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.
4th revision of Sheet 1-2, read from the complete tariff in the Idaho PUC file room; the company's own tariff pages answer scripted fetches with a 200 'Not Found' body. A 2025 rate case application proposed a 25.00 USD basic charge.Source sheet ↗read 2026-09-18· OpenEI entry ↗ dated 2025-02-01, a discovery index only
Modeled Computed 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 6 declared cases. 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 · summerJune 1 to September 30 | $87.72 | None priced on this sheet | $0.121195 | 14.62schedule charges ÷ kWh |
| 600 kWh over 30 days · non-summerOctober 1 to May 31 | $74.60 | None priced on this sheet | $0.099332 | 12.43schedule charges ÷ kWh |
| 900 kWh over 30 days · summerJune 1 to September 30 | $125.26 | None priced on this sheet | $0.132995 | 13.92schedule charges ÷ kWh |
| 900 kWh over 30 days · non-summerOctober 1 to May 31 | $104.90 | None priced on this sheet | $0.104305 | 11.66schedule charges ÷ kWh |
| 1,200 kWh over 30 days · summerJune 1 to September 30 | $165.16 | None priced on this sheet | $0.132995 | 13.76schedule charges ÷ kWh |
| 1,200 kWh over 30 days · non-summerOctober 1 to May 31 | $136.19 | None priced on this sheet | $0.104305 | 11.35schedule charges ÷ kWh |
| Line | Quantity | Price | Amount (USD) |
|---|---|---|---|
| Service Charge | 1 month | $15.0000 per month | $15.00 |
| Energy Charge0–800 kWh | 600 kWh | $0.121195 per kWh | $72.72 |
| Schedule charges | $87.72 | ||
| Line | Quantity | Price | Amount (USD) |
|---|---|---|---|
| Service Charge | 1 month | $15.0000 per month | $15.00 |
| Energy Charge0–800 kWh | 600 kWh | $0.099332 per kWh | $59.60 |
| Schedule charges | $74.60 | ||
| Line | Quantity | Price | Amount (USD) |
|---|---|---|---|
| Service Charge | 1 month | $15.0000 per month | $15.00 |
| Energy Charge0–800 kWh | 800 kWh | $0.121195 per kWh | $96.96 |
| Energy Charge800–2000 kWh | 100 kWh | $0.132995 per kWh | $13.30 |
| Schedule charges | $125.26 | ||
| Line | Quantity | Price | Amount (USD) |
|---|---|---|---|
| Service Charge | 1 month | $15.0000 per month | $15.00 |
| Energy Charge0–800 kWh | 800 kWh | $0.099332 per kWh | $79.47 |
| Energy Charge800–2000 kWh | 100 kWh | $0.104305 per kWh | $10.43 |
| Schedule charges | $104.90 | ||
| Line | Quantity | Price | Amount (USD) |
|---|---|---|---|
| Service Charge | 1 month | $15.0000 per month | $15.00 |
| Energy Charge0–800 kWh | 800 kWh | $0.121195 per kWh | $96.96 |
| Energy Charge800–2000 kWh | 400 kWh | $0.132995 per kWh | $53.20 |
| Schedule charges | $165.16 | ||
| Line | Quantity | Price | Amount (USD) |
|---|---|---|---|
| Service Charge | 1 month | $15.0000 per month | $15.00 |
| Energy Charge0–800 kWh | 800 kWh | $0.099332 per kWh | $79.47 |
| Energy Charge800–2000 kWh | 400 kWh | $0.104305 per kWh | $41.72 |
| Schedule charges | $136.19 | ||
Named on the sheet without a price, so in neither total: Schedule 54 (Fixed Cost Adjustment); Schedule 55 (Power Cost Adjustment); Schedule 91 (Energy Efficiency Rider); Schedule 95 (Adjustment for Municipal Franchise Fees); Schedule 96 (Blaine County Surcharge to Fund the Undergrounding of Certain Facilities); Schedule 98 (Residential and Small Farm Energy Credit). This sheet prices no adjustment, so there is no second total.
Not net metering: exported energy is credited at a published Export Credit Rate that varies by time of day and season, and the credit offsets the bill rather than the meter running backwards
Idaho replaced kilowatt-hour netting with an export credit in 2024, so an Idaho example cannot be compared with a Washington or Oregon one without saying so.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 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
core_eia861__yearly_net_metering_customer_fuel_class.parquet; report_date=2024-01-01; utility_id_eia=9191 (+ non-net-metering table)
Publisher & attribution ↗EIA-861 net metering schedule, leaf technology classes excluding storage
2024 calendar year · reported · derived · valid · final
1 of 1 reporting utilities included.
core_eia861__yearly_net_metering_customer_fuel_class.parquet; report_date=2024-01-01; utility_id_eia=9191 (+ non-net-metering table)
Publisher & attribution ↗EIA-861 non-net-metering distributed generation schedule, leaf technology classes excluding storage
2024 calendar year · reported · derived · valid · final
1 of 1 reporting utilities included.
core_eia861__yearly_net_metering_customer_fuel_class.parquet; report_date=2024-01-01; utility_id_eia=9191 (+ non-net-metering table)
Publisher & attribution ↗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.
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
1 of 1 reporting utilities included.
core_eia861__yearly_net_metering_customer_fuel_class.parquet; report_date=2024-01-01; utility_id_eia=9191 (+ non-net-metering table)
Publisher & attribution ↗EIA-861 net metering schedule; export to the utility, not customer generation
2024 calendar year · reported · derived · missing · final
0 of 1 reporting utilities included.
1 of 1 reporting utilities have no value for this metric
core_eia861__yearly_net_metering_customer_fuel_class.parquet; report_date=2024-01-01; utility_id_eia=9191 (+ non-net-metering table)
Publisher & attribution ↗Power rating in MW and energy capacity in MWh are separate measurements. These storage quantities are excluded from the generation capacity above.
EIA-861 storage technology classes (storage_pv, storage_nonpv, all_storage); power rating, kept separate from generation capacity
2024 calendar year · reported · derived · missing · final
0 of 1 reporting utilities included.
1 of 1 reporting utilities have no value for this metric
core_eia861__yearly_net_metering_customer_fuel_class.parquet; report_date=2024-01-01; utility_id_eia=9191 (+ non-net-metering table)
Publisher & attribution ↗EIA-861 storage technology classes; usable energy as reported
2024 calendar year · reported · derived · missing · final
0 of 1 reporting utilities included.
1 of 1 reporting utilities have no value for this metric
core_eia861__yearly_net_metering_customer_fuel_class.parquet; report_date=2024-01-01; utility_id_eia=9191 (+ non-net-metering table)
Publisher & attribution ↗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)
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.
Release 20260929T050546Z-51ae0f7d3c78 · Record JSON