Portland General Electric (POR) 10-Q 30 Jul 21 2021 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2021	Jul. 26, 2021
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2021
Document Transition Report	false
Entity File Number	001-5532-99
Entity Registrant Name	PORTLAND GENERAL ELECTRIC COMPANY
Entity Incorporation, State or Country Code	OR
Entity Tax Identification Number	93-0256820
Entity Address, Address Line One	121 SW Salmon Street
Entity Address, City or Town	Portland
Entity Address, State or Province	OR
Entity Address, Postal Zip Code	97204
City Area Code	503
Local Phone Number	464-8000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		89,405,455
Entity Central Index Key	0000784977
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Medium-term Notes [Member]
Title of 12(b) Security	9.31% Medium-Term Notes due 2021
Trading Symbol	POR 21
Security Exchange Name	NYSE
Title of 12(b) Security	9.31% Medium-Term Notes due 2021
Trading Symbol	POR 21
Security Exchange Name	NYSE
Common Stock [Member]
Title of 12(b) Security	Common Stock, no par value
Trading Symbol	POR
Security Exchange Name	NYSE
Title of 12(b) Security	Common Stock, no par value
Trading Symbol	POR
Security Exchange Name	NYSE

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income and Comprehensive Income (Unaudited) - USD ($) shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Revenue, net	$ 545	$ 469	$ 1,157	$ 1,033
Alternative revenue programs, net of amortization	(8)	0	(11)	9
Total revenues	537	469	1,146	1,042
Operating expenses:
Purchased power and fuel	185	109	354	262
Generation, transmission and distribution	76	77	156	150
Administrative and other	79	74	165	145
Depreciation and amortization	101	104	204	212
Taxes other than income taxes	35	34	73	69
Total operating expenses	476	398	952	838
Income from operations	61	71	194	204
Interest expense, net	33	34	67	67
Other income:
Allowance for equity funds used during construction	5	4	9	7
Miscellaneous income (loss), net	3	3	5	(1)
Other income, net	8	7	14	6
Income before income tax expense	36	44	141	143
Income tax expense	4	5	13	23
Net income	32	39	128	120
Other comprehensive Income	0	0	0	1
Comprehensive Income	$ 32	$ 39	$ 128	$ 121
Weighted-average common shares outstanding (in thousands):
Basic	89,554	89,489	89,555	89,459
Diluted	89,672	89,625	89,687	89,602
Basic	$ 0.36	$ 0.44	$ 1.43	$ 1.34
Diluted	$ 0.36	$ 0.43	$ 1.43	$ 1.34

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Current assets:
Cash and cash equivalents	$ 17	$ 257
Accounts receivable, net	274	271
Inventories	74	72
Regulatory assets - current	20	23
Other current assets	219	98
Total current assets	604	721
Electric utility plant, net	7,693	7,539
Regulatory assets - noncurrent	543	569
Nuclear decommissioning trust	43	45
Non-qualified benefit plan trust	46	42
Other noncurrent assets	170	153
Total assets	9,099	9,069
Current liabilities
Accounts payable	196	153
Liabilities from price risk mangement activities - current	55	14
Short-term debt	200	150
Current portion of long-term debt	20	160
Current portion of finance lease obligation	16	16
Accrued expenses and other current liabilities	369	322
Total current liabilities	856	815
Long-term debt, net of current portion	2,887	2,886
Regulatory liabilities-noncurrent	1,354	1,369
Deferred income taxes	402	374
Unfunded status of pension and psotretirement plans	299	299
Liabilities from price risk management activities-noncurrent	69	136
Asset retirement obligations	263	270
Non-qualified benefit plan liabilities	100	101
Finance lease obligations, net of current portion	127	129
Other noncurrent liabilities	81	77
Total liabilities	6,438	6,456
Commitments and contingencies (see notes)
Shareholders' Equity:
Preferred stock, no par value, 30,000,000 shares authorized; none issued and outstanding as of June 30, 2021 and December 31, 2020	0	0
Common stock, no par value, 160,000,000 shares authorized; 89,401,722 and 89,537,331 shares issued and outstanding as of June 30, 2021 and December 31, 2020, respectively	1,235	1,231
Accumulated other comprehensive loss	(11)	(11)
Retained earnings	1,437	1,393
Total shareholders' equity	2,661	2,613
Total liabilities and shareholders' equity	$ 9,099	$ 9,069

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - $ / shares	Jun. 30, 2021	Dec. 31, 2020
Preferred stock, no par value	$ 0	$ 0
Preferred stock, shares authorized	30,000,000	30,000,000
Preferred stock, issued	0	0
Preferred stock, outstanding	0	0
Common stock, no par value	$ 0	$ 0
Common stock, shares authorized	160,000,000	160,000,000
Common stock, shares issued	89,401,722	89,537,331
Common stock, shares outstanding	89,401,722	89,537,331

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020
Cash flows from operating activities:
Net income	$ 128	$ 120
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	204	212
Deferred income taxes	6	4
Pension and other postretirement benefits	12	12
Allowance for equity funds used during construction	(9)	(7)
Decoupling mechanism deferrals, net of amortization	11	(8)
(Amortization) of net benefits due to Tax Reform	0	(11)
Deferral of incremental storm costs	(52)	0
Other non-cash income and expenses, net	19	46
Changes in working capital:
Decrease in accounts receivable, net	(9)	40
(Increase) in inventories	(3)	(13)
(Increase)/decrease in margin deposits	(35)	(9)
(Decrease) in accounts payable and accrued liabilities	13	(27)
Other working capital items, net	32	18
Other, net	(41)	(21)
Net cash provided by operating activities	276	356
Cash flows from investing activities:
Capital expenditures	(326)	(370)
Sales of Nuclear decommissioning trust securities	7	4
Purchases of Nuclear decommissioning trust securities	(5)	(3)
Other, net	(13)	(1)
Net cash used in investing activities	(337)	(370)
Cash flows from financing activities:
Proceeds from Issuance of long-term debt	0	319
Payments on long-term debt	(140)	(98)
Borrowings on short-term debt	200	200
Repayments of Short-term Debt	(150)	(50)
Dividends paid	(73)	(69)
Other	(4)	(15)
Net cash provided by (used in) financing activities	(179)	287
Increase (Decrease) in cash and cash equivalents	(240)	273
Cash and cash equivalents, beginning of period	257	30
Cash and cash equivalents, end of period	17	303
Supplemental cash flow information is as follows:
Cash paid for interest, net of amounts capitalized	61	56
Cash paid for income taxes, net	11	$ 5
Other	$ (12)
Other	(6.10%)	0.00%

Basis of Presentation (Notes)

Basis of Presentation (Notes)	6 Months Ended
	Jun. 30, 2021
Basis of Presentation [Abstract]
BASIS OF PRESENTATION	BASIS OF PRESENTATION Nature of Business Portland General Electric Company (PGE or the Company) is a vertically-integrated electric utility engaged in the generation, purchase, transmission, distribution, and retail sale of electricity in the State of Oregon. The Company participates in the wholesale market by purchasing and selling electricity and natural gas in an effort to provide reasonably-priced power for its retail customers. PGE operates as a single segment, with revenues and costs related to its business activities recorded and analyzed on a total electric operations basis. The Company’s corporate headquarters is located in Portland, Oregon and its 4,000 square mile, state-approved service area encompasses 51 incorporated cities entirely within the State of Oregon. As of June 30, 2021, PGE served 912,000 retail customers within a service area of 1.9 million residents. Condensed Consolidated Financial Statements These condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the United States Securities and Exchange Commission (SEC). Certain information and note disclosures normally included in financial statements prepared in conformity with accounting principles generally accepted in the United States of America (GAAP) have been condensed or omitted pursuant to such regulations, although PGE believes that the disclosures provided are adequate to make the interim information presented not misleading. The financial information included herein as of and for the three and six months ended June 30, 2021 and 2020 is unaudited; however, in the opinion of management, such information reflects all adjustments necessary to fairly present the condensed consolidated financial position, condensed consolidated income and comprehensive income, and condensed consolidated cash flows of the Company for these interim periods. All such adjustments are of normal recurring nature, unless otherwise noted. The financial information as of December 31, 2020 is derived from the Company’s audited consolidated financial statements and notes thereto for the year ended December 31, 2020, included in Item 8 of PGE’s Annual Report on Form 10-K, filed with the SEC on February 19, 2021, which should be read in conjunction with the interim unaudited Financial Statements. Comprehensive Income No material change occurred in Other comprehensive income in the three and six months ended June 30, 2021 and 2020. Use of Estimates The preparation of condensed consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, and disclosures of gain or loss contingencies, as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results experienced by the Company could differ materially from those estimates.

Revenue Recognition (Notes)

Revenue Recognition (Notes)	6 Months Ended
	Jun. 30, 2021
Revenue Recognition and Deferred Revenue [Abstract]
Revenue Recognition, Multiple-deliverable Arrangements [Table Text Block]	REVENUE RECOGNITION Disaggregated Revenue The following table presents PGE’s revenue, disaggregated by customer type (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Retail: Residential $ 249 $ 223 $ 559 $ 502 Commercial 170 140 332 299 Industrial 62 53 122 104 Direct access customers 13 12 24 23 Subtotal 494 428 1,037 928 Alternative revenue programs, net of amortization (8) — (11) 9 Other accrued revenues, net (2) 1 11 6 Total retail revenues 484 429 1,037 943 Wholesale revenues * 41 27 74 74 Other operating revenues 12 13 35 25 Total revenues $ 537 $ 469 $ 1,146 $ 1,042 * Wholesale revenues include $4 million and $8 million related to electricity commodity contract derivative settlements for the three months ended June 30, 2021 and 2020, respectively, and $9 million and $24 million for the six months ended June 30, 2021 and 2020, respectively. Price risk management derivative activities are included within total revenues but do not represent revenues from contracts with customers as defined by GAAP. For further information, see Note 5, Risk Management. Retail Revenues The Company’s primary revenue source is the sale of electricity to customers at regulated, tariff-based prices. Retail customers are classified as residential, commercial, or industrial. Residential customers include single-family housing, multiple-family housing (such as apartments, duplexes, and town homes), manufactured homes, and small farms. Residential demand is sensitive to the effects of weather, with demand highest during the winter heating and summer cooling seasons. Commercial customers accept energy deliveries at voltages equivalent to those delivered to residential customers and are also sensitive to the effects of weather, although to a lesser extent than residential customers. Commercial customers include most businesses, small industrial companies, and public street and highway lighting accounts. Industrial customers consist of non-residential customers who accept delivery at higher voltages than commercial customers. Demand from industrial customers is primarily driven by economic conditions, with weather having little impact on energy use by this customer class. In accordance with state regulations, PGE’s retail customer prices are based on the Company’s cost of service and determined through general rate case proceedings and various tariff filings with the Public Utility Commission of Oregon (OPUC). Additionally, the Company offers pricing options that include a daily market price option, various time-of-use options, and several renewable energy options. Retail revenue is billed based on monthly meter readings taken at various cycle dates throughout the month. At the end of each month, PGE estimates the revenue earned from energy deliveries that have not yet been billed to customers. This amount, classified as Unbilled revenues, which is included in Accounts receivable, net in the Company’s condensed consolidated balance sheets, is calculated based on actual net retail system load each month, the number of days from the last meter read date through the last day of the month, and current customer prices. PGE’s obligation to sell electricity to retail customers generally represents a single performance obligation representing a series of distinct services that are substantially the same and have the same pattern of transfer to the customer that is satisfied over time as customers simultaneously receive and consume the benefits provided. The Company applies the invoice method to measure its progress towards satisfactorily completing its performance obligations. Pursuant to regulation by the OPUC, PGE is mandated to maintain several tariff schedules to collect funds from customers for programs that benefit the general public, such as conservation, low-income housing, energy efficiency, renewable energy programs, and privilege taxes. For such programs, the Company generally collects the funds and remits the amounts to third party agencies that administer the programs. In these arrangements, PGE is considered to be an agent, as the Company’s performance obligation is to facilitate a transaction between customers and the administrators of these programs. Therefore, such amounts are presented on a net basis and are not reflected in Revenues, net within the condensed consolidated statements of income and comprehensive income. Wholesale Revenues PGE participates in the wholesale electricity marketplace in order to balance its supply of power to meet the needs of its retail customers. Interconnected transmission systems in the western United States serve utilities with diverse load requirements and allow the Company to purchase and sell electricity within the region depending upon the relative price and availability of power; hydro, solar and wind conditions; and daily and seasonal retail demand. PGE’s Wholesale revenues are primarily short-term electricity sales to utilities and power marketers that consist of single performance obligations that are satisfied as energy is transferred to the counterparty. The Company may choose to net certain purchase and sale transactions in which it would simultaneously receive and deliver physical power with the same counterparty; in such cases, only the net amount of those purchases or sales required to meet retail and wholesale obligations will be physically settled and recorded in Wholesale revenues. Other Operating Revenues Other operating revenues consist primarily of gains and losses on the sale of natural gas volumes purchased that exceeded what was needed to fuel the Company’s generating facilities, as well as revenues from transmission services, excess transmission capacity resales, utility pole attachment revenues, and other services provided to customers. Arrangements with Multiple Performance Obligations Certain contracts with customers, primarily wholesale, may include multiple performance obligations. For such arrangements, PGE allocates revenue to each performance obligation based on its relative standalone selling price. The Company generally determines standalone selling prices based on the prices charged to customers.

Balance Sheet Components (Notes

Balance Sheet Components (Notes)	3 Months Ended
	Jun. 30, 2021
Balance Sheet Components [Abstract]
BALANCE SHEET COMPONENTS	BALANCE SHEET COMPONENTS Inventories PGE’s inventories, which are recorded at average cost, consist primarily of materials and supplies for use in operations, maintenance, and capital activities, as well as fuel, which includes natural gas, coal, and oil, for use in the Company’s generating plants. Periodically, PGE assesses whether inventories are recorded at the lower of average cost or net realizable value. Accounts Receivable, Net Accounts receivable, net includes $99 million and $97 million of unbilled revenues as of June 30, 2021 and December 31, 2020, respectively. Accounts receivable, net is net of an allowance for credit losses of $22 million as of June 30, 2021. The following summarizes activity in the allowance for credit losses (in millions): Three Months Ended June 30, Six Months Ended 2021 2021 Balance as of beginning of period $ 20 $ 16 Increase in provision 8 15 Amounts written off (8) (12) Recoveries 2 3 Balance as of end of period $ 22 $ 22 Other Current Assets Other current assets consist of the following (in millions): June 30, 2021 December 31, 2020 Prepaid expenses $ 51 $ 57 Assets from price risk management activities 125 33 Margin deposits 43 8 Other current assets $ 219 $ 98 Electric Utility Plant, Net Electric utility plant, net consists of the following (in millions): June 30, 2021 December 31, 2020 Electric utility plant $ 11,168 $ 10,974 Construction work-in-progress 510 429 Total cost 11,678 11,403 Less: accumulated depreciation and amortization (3,985) (3,864) Electric utility plant, net $ 7,693 $ 7,539 Accumulated depreciation and amortization in the table above includes accumulated amortization related to intangible assets of $417 million and $388 million as of June 30, 2021 and December 31, 2020, respectively. Amortization expense related to intangible assets was $30 million and $31 million for the six months ended June 30, 2021 and 2020, respectively and $15 million and $16 million for the three months ended June 30, 2021 and 2020, respectively. The Company’s intangible assets primarily consist of computer software development and hydro licensing costs. On June 30, 2021, PGE entered into a hydroelectric power purchase agreement (PPA) that the Company expects will be effective no later than December 31, 2021, after certain conditions precedent are met. On its effective date, the PPA is expected to modify an existing operating lease by effectively extending the term of the lease from 2024 to 2040 and increasing the capacity payments in the extension period. Upon modification, PGE anticipates the lease will be reclassified from operating to finance, and the Company will record an additional lease liability and right-of-use (ROU) asset of approximately $140 million on PGE’s condensed consolidated balance sheets, no later than December 31, 2021 if all conditions precedent are met. The energy portion of the PPA is considered variable and will not be included in the calculation of the lease liability and right-of-use asset. Any material differences between expense recognition and timing of payments will be deferred as a regulatory asset or liability in order to match what is anticipated to be recovered in customer prices for ratemaking purposes. Regulatory Assets and Liabilities Regulatory assets and liabilities consist of the following (in millions): June 30, 2021 December 31, 2020 Current Noncurrent Current Noncurrent Regulatory assets: Price risk management $ — $ 35 $ — $ 124 Pension and other postretirement plans — 229 — 240 Debt issuance costs — 24 — 25 Trojan decommissioning activities — 98 — 95 Incremental storm costs — 52 — — Other 20 105 23 85 Total regulatory assets $ 20 $ 543 $ 23 $ 569 Regulatory liabilities: Asset retirement removal costs $ — $ 1,028 $ — $ 1,016 Deferred income taxes — 219 — 239 Asset retirement obligations — 39 — 37 Price risk management 70 — 18 — Other 21 68 5 77 Total regulatory liabilities $ 91 * $ 1,354 $ 23 * $ 1,369 * Included in Accrued expenses and other current liabilities in the condensed consolidated balance sheets. Incremental storm costs represents the costs not previously included for recovery in customer prices related to major storm damage incurred during the six months ended June 30, 2021. Such costs were incurred to repair damage to PGE’s transmission and distribution systems and restore power to customers as a result of the historic storms that ultimately led Oregon’s Governor to declare a state of emergency on February 13, 2021. On February 15, 2021, the Company filed an application for authorization to defer emergency restoration costs for the February storms (Docket UM 2156). PGE does not expect an OPUC decision on the February storm deferral until later in 2021 or 2022. While the Company believes the full amount of the deferral is probable of recovery as PGE’s prudently incurred costs were in response to the unique and unprecedented nature of the storms, the OPUC has significant discretion in making the final determination of recovery which could result in a portion or all of the Company’s deferral being disallowed for recovery. Accrued Expenses and Other Current Liabilities Accrued expenses and other current liabilities consist of the following (in millions): June 30, 2021 December 31, 2020 Accrued employee compensation and benefits $ 51 $ 67 Accrued taxes payable 33 36 Accrued interest payable 27 29 Accrued dividends payable 40 38 Regulatory liabilities—current 91 23 Other 127 129 Total accrued expenses and other current liabilities $ 369 $ 322 Credit Facilities As of June 30, 2021, PGE had a $500 million revolving credit facility scheduled to expire in November 2023. The Company has the ability to expand the revolving credit facility to $600 million, if needed. Pursuant to the terms of the agreement, the revolving credit facility may be used for general corporate purposes, including as backup for commercial paper borrowings and to permit the issuance of standby letters of credit. PGE may borrow for one, two, three, or six months at a fixed interest rate established at the time of the borrowing, or at a variable interest rate for any period up to the then remaining term of the applicable credit facility. The revolving credit facility contains a provision that requires annual fees based on the Company ’ s unsecured credit ratings, and contains customary covenants and default provisions, including a requirement that limits consolidated indebtedness, as defined in the agreement, to 65% of total capitalization. As of June 30, 2021, PGE was in compliance with this covenant with a 55.3% debt-to-total capital ratio. The aggregate unused available credit capacity under the revolving credit facility was $500 million. The Company has a commercial paper program under which it may issue commercial paper for terms of up to 270 days. The Company has elected to limit its borrowings under the revolving credit facility to cover any potential need to repay any commercial paper that may be outstanding at the time. As of June 30, 2021, PGE had no commercial paper outstanding. PGE typically classifies borrowings under the revolving credit facility and outstanding commercial paper as Short-term debt on the condensed consolidated balance sheets. In addition, PGE has four letter of credit facilities that provide a total capacity of $220 million under which the Company can request letters of credit for original terms not to exceed one year. The issuance of such letters of credit is subject to the approval of the issuing institution. Under these facilities, letters of credit for a total of $69 million were outstanding as of June 30, 2021. Letters of credit issued are not reflected on the Company’s condensed consolidated balance sheets. On April 9, 2020, PGE obtained a 364-day term loan from lenders in the aggregate principal of $150 million. The term loan bore interest for the relevant interest period at LIBOR plus 1.25%. The interest rate was subject to adjustment pursuant to the terms of the loan. On March 31, 2021, this term loan was repaid in full with proceeds from the subsequent term loan described below. On March 31, 2021, PGE obtained an unsecured 364-day term loan in the aggregate principal amount of $200 million. The term loan will bear interest for the relevant interest period at LIBOR plus 0.70%, with the interest rate subject to adjustment pursuant to terms of the loan. The credit agreement expires on March 30, 2022, with any outstanding balance due and payable on such date. The Company used a portion of the proceeds to repay the prior 364-day term loan, with the remainder of the proceeds used for general corporate purposes. Pursuant to an order issued by the Federal Energy Regulatory Commission (FERC), the Company is authorized to issue short-term debt in an aggregate amount of up to $900 million through February 6, 2022. Long-term Debt On January 6, 2021, the Company made a scheduled $140 million repayment on a 2.51% Series of First Mortgage Bonds with available cash. Defined Benefit Retirement Plan Costs Components of net periodic benefit cost under the defined benefit pension plan are as follows (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Service cost $ 5 $ 4 $ 10 $ 8 Interest cost* 7 8 14 16 Expected return on plan assets* (11) (11) (22) (22) Amortization of net actuarial loss* 5 4 10 8 Net periodic benefit cost $ 6 $ 5 $ 12 $ 10 * The expense portion of non-service cost components are included in Miscellaneous income (expense), net within Other income on the Company’s condensed consolidated statements of income and comprehensive income.

Fair Value of Financial Instrum

Fair Value of Financial Instruments (Notes)	6 Months Ended
	Jun. 30, 2021
Fair Value of Financial Instruments [Abstract]
FAIR VALUE OF FINANCIAL INSTRUMENTS	FAIR VALUE OF FINANCIAL INSTRUMENTS PGE estimated the fair value of financial asset and liability instruments as of June 30, 2021 and December 31, 2020, and classified these financial instruments based on a fair value hierarchy that is applied to prioritize the inputs to the valuation techniques used to measure fair value. The three levels of the fair value hierarchy and application to the Company are: Level 1 Quoted prices are available in active markets for identical assets or liabilities as of the measurement date; Level 2 Pricing inputs include those that are directly or indirectly observable in the marketplace as of the measurement date; and Level 3 Pricing inputs include significant inputs that are unobservable for the asset or liability. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of assets and liabilities and their placement within the fair value hierarchy. Assets measured at fair value using net asset value (NAV) as a practical expedient are not categorized in the fair value hierarchy. These assets are listed in the totals of the fair value hierarchy to permit the reconciliation to amounts presented in the financial statements. Changes to market liquidity conditions, the availability of observable inputs, or changes in the economic structure of a security marketplace may require transfer of the securities between levels. The Company’s financial assets and liabilities whose values were recognized at fair value in the Company’s condensed consolidated balance sheets are as follows by level within the fair value hierarchy (in millions): As of June 30, 2021 Level 1 Level 2 Level 3 Other (2) Total Assets: Cash equivalents $ — $ — $ — $ — $ — Nuclear decommissioning trust: (1) Debt securities: Domestic government 9 8 — — 17 Corporate credit — 13 — — 13 Money market funds measured at NAV (2) — — — 13 13 Non-qualified benefit plan trust: (3) Debt securities—domestic government 1 — — — 1 Money market funds 2 — — — 2 Equity securities 8 — — — 8 Price risk management activities: (1) (4) Electricity — 33 7 — 40 Natural gas — 111 8 — 119 $ 20 $ 165 $ 15 $ 13 $ 213 Liabilities: Price risk management activities: (1) (4) Electricity $ — $ 50 $ 73 $ — $ 123 Natural gas — 1 — — 1 $ — $ 51 $ 73 $ — $ 124 (1) Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate. (2) Assets are measured at NAV as a practical expedient and not subject to hierarchy level classification disclosure. (3) Excludes insurance policies of $35 million, which are recorded at cash surrender value. (4) For further information, see Note 5, Risk Management. As of December 31, 2020 Level 1 Level 2 Level 3 Other (2) Total Assets: Cash equivalents $ 255 $ — $ — $ — $ 255 Nuclear decommissioning trust: (1) Debt securities: Domestic government 9 11 — — 20 Corporate credit — 13 — — 13 Money market funds measured at NAV (2) — — — 12 12 Non-qualified benefit plan trust: (3) Debt securities—domestic government 1 — — — 1 Money market funds 1 — — — 1 Equity securities 7 — — — 7 Price risk management activities: (1) (4) Electricity — 4 4 — 8 Natural gas — 36 1 — 37 $ 273 $ 64 $ 5 $ 12 $ 354 Liabilities: Price risk management activities: (1) (4) Electricity — 5 141 — 146 Natural gas — 4 1 — 5 $ — $ 9 $ 142 $ — $ 151 (1) Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate. (2) Assets are measured at NAV as a practical expedient and not subject to hierarchy level classification disclosure. (3) Excludes insurance policies of $33 million, which are recorded at cash surrender value. (4) For further information, see Note 5, Risk Management. Cash equivalents are highly liquid investments with maturities of three months or less at the date of acquisition and primarily consist of money market funds. Such funds seek to maintain a stable net asset value and are comprised of short-term, government funds. Policies of such funds require that the weighted average maturity of securities holdings of such funds not exceed 90 days and provide investors with the ability to redeem shares of the funds daily at their respective net asset value. Cash equivalents are classified as Level 1 in the fair value hierarchy due to the availability of quoted prices for identical assets in an active market as of the measurement date. Principal markets for money market fund prices include published exchanges such as the National Association of Securities Dealers Automated Quotations (Nasdaq) and the New York Stock Exchange (NYSE). Assets held in the Nuclear decommissioning trust (NDT) and Non-qualified benefit plan (NQBP) trusts are recorded at fair value in PGE’s condensed consolidated balance sheets and invested in securities that are exposed to interest rate, credit, and market volatility risks. These assets are classified within Level 1, 2, or 3 based on the following factors: Debt securities —PGE invests in highly-liquid United States Treasury securities to support the investment objectives of the trusts. These domestic government securities are classified as Level 1 in the fair value hierarchy due to the availability of quoted prices for identical assets in an active market as of the measurement date. Assets classified as Level 2 in the fair value hierarchy include domestic government debt securities, such as municipal debt, and corporate credit securities. Prices are determined by evaluating pricing data such as broker quotes for similar securities and adjusted for observable differences. Significant inputs used in valuation models generally include benchmark yields and issuer spreads. The external credit rating, coupon rate, and maturity of each security are considered in the valuation, as applicable. Equity securities —Equity mutual fund and common stock securities are classified as Level 1 in the fair value hierarchy due to the availability of quoted prices for identical assets in an active market as of the measurement date. Principal markets for equity prices include published exchanges such as Nasdaq and the NYSE. Money market funds —PGE invests in money market funds that seek to maintain a stable net asset value. These funds invest in high-quality, short-term, diversified money market instruments, short-term treasury bills, federal agency securities, certificates of deposits, and commercial paper. The Company believes the redemption value of these funds is likely to be the fair value, which is represented by the net asset value. Redemption is permitted daily without written notice. The NQBP trust is invested in exchange-traded government money market funds and is classified as Level 1 in the fair value hierarchy due to the availability of quoted prices in published exchanges such as Nasdaq and the NYSE. The money market fund in the NDT is valued at NAV as a practical expedient and is not included in the fair value hierarchy. Assets and liabilities from price risk management activities, recorded at fair value in PGE’s condensed consolidated balance sheets, consist of derivative instruments entered into by the Company to manage its risk exposure to commodity price and foreign currency exchange rates and reduce volatility in net variable power costs (NVPC) for the Company’s retail customers. For additional information regarding these assets and liabilities, see Note 5, Risk Management. For those assets and liabilities from price risk management activities classified as Level 2, fair value is derived using present value formulas that utilize inputs such as forward commodity prices and interest rates. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument, can be derived from observable data, or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include commodity forwards, futures, and swaps. Assets and liabilities from price risk management activities classified as Level 3 consist of instruments for which fair value is derived using one or more significant inputs that are not observable for the entire term of the instrument. These instruments consist of longer-term commodity forwards, futures, and swaps. Quantitative information regarding the significant, unobservable inputs used in the measurement of Level 3 assets and liabilities from price risk management activities is presented below: Fair Value Valuation Technique Significant Unobservable Input Price per Unit Commodity Contracts Assets Liabilities Low High Weighted Average (in millions) As of June 30, 2021 Electricity physical forwards $ 5 $ 72 Discounted cash flow Electricity forward price (per MWh) $ 18.88 $ 148.39 $ 51.68 Natural gas financial swaps 8 — Discounted cash flow Natural gas forward price (per Decatherm) 1.86 5.01 2.51 Electricity financial futures 2 1 Discounted cash flow Electricity forward price (per MWh) 21.78 96.00 47.47 $ 15 $ 73 As of December 31, 2020 Electricity physical forwards $ — $ 141 Discounted cash flow Electricity forward price (per MWh) $ 11.17 $ 51.18 $ 29.74 Natural gas financial swaps 1 1 Discounted cash flow Natural gas forward price (per Decatherm) 1.52 4.33 2.29 Electricity financial futures 4 — Discounted cash flow Electricity forward price (per MWh) 8.78 58.42 43.71 $ 5 $ 142 The significant unobservable inputs used in the Company’s fair value measurement of price risk management assets and liabilities are long-term forward prices for commodity derivatives. For certain long-term contracts, observable, liquid market transactions are not available for the duration of the delivery period. In such instances, the Company uses internally-developed long-term price curves that utilize observable data when available. When not available, regression techniques are used to estimate unobservable future prices. The Company’s Level 3 assets and liabilities from price risk management activities are sensitive to market price changes in the respective underlying commodities. The significance of the impact is dependent upon the magnitude of the price change and PGE’s position as either the buyer or seller under the contract. Sensitivity of the fair value measurements to changes in the significant unobservable inputs is as follows: Significant Unobservable Input Position Change to Input Impact on Fair Value Market price Buy Increase (decrease) Gain (loss) Market price Sell Increase (decrease) Loss (gain) Changes in the fair value of net liabilities from price risk management activities (net of assets from price risk management activities) classified as Level 3 in the fair value hierarchy were as follows (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Balance as of the beginning of the period $ 117 $ 134 $ 137 $ 97 Net realized and unrealized losses/(gains) * (62) 17 (83) 56 Transfers from Level 3 to Level 2 3 — 4 (2) Balance as of the end of the period $ 58 $ 151 $ 58 $ 151 * Both realized and unrealized losses/(gains), of which unrealized portion are offset by the effects of regulatory accounting until settlement of the underlying transactions, are recorded in Revenues, net or Purchased power and fuel expense in the condensed consolidated statements of income and comprehensive income. Includes $1 million in net realized losses and $3 million in net realized gains for the three-month periods ended June 30, 2021 and June 30, 2020, respectively. For the six-month periods ended June 30, 2021 and June 30, 2020, includes $2 million in net realized losses and $3 million in net realized gains, respectively. Transfers out of Level 3 occur when the significant inputs become more observable, such as when the time between the valuation date and the delivery term of a transaction becomes shorter. Long-term debt is recorded at amortized cost in PGE’s condensed consolidated balance sheets. The value of the Company’s First Mortgage Bonds (FMBs) and Pollution Control Revenue Bonds is classified as a Level 2 fair value measurement. As of June 30, 2021, the carrying amount of PGE’s long-term debt was $2,907 million, net of $12 million of unamortized debt expense, and its estimated aggregate fair value was $3,512 million. As of December 31, 2020, the carrying amount of PGE’s long-term debt was $3,046 million, net of $13 million of unamortized debt expense, and its estimated aggregate fair value was $3,808 million.

Risk Management (Notes)

Risk Management (Notes)	6 Months Ended
	Jun. 30, 2021
Price Risk Management [Abstract]
PRICE RISK MANAGEMENT	RISK MANAGEMENT Price Risk Management PGE participates in the wholesale marketplace to balance its supply of power, which consists of its own generation combined with wholesale market transactions, to meet the needs of its retail customers, manage risk, and administer its existing long-term wholesale contracts. Wholesale market transactions include purchases and sales of both power and fuel resulting from economic dispatch decisions for Company-owned generation resources. As a result of this ongoing business activity, PGE is exposed to commodity price risk and foreign currency exchange rate risk, from which changes in prices and/or rates may affect the Company’s financial position, results of operations, or cash flows. PGE utilizes derivative instruments to manage its exposure to commodity price risk and foreign exchange rate risk to reduce volatility in NVPC for its retail customers. Such derivative instruments, recorded at fair value on the condensed consolidated balance sheets, may include forwards, futures, swaps, and options contracts for electricity, natural gas, and foreign currency, with changes in fair value recorded in the condensed consolidated statements of income and comprehensive income. In accordance with the ratemaking and cost recovery processes authorized by the OPUC, the Company recognizes a regulatory asset or liability to defer the gains and losses from derivative activity until settlement of the associated derivative instrument. PGE may designate certain derivative instruments as cash flow hedges or may use derivative ins truments as economic hedges. The Company does not intend to engage in trading activities for non-retail purposes. PGE’s Assets and Liabilities from price risk management activities consist of the following (in millions): June 30, 2021 December 31, 2020 Current assets: Commodity contracts: Electricity $ 37 $ 4 Natural gas 88 29 Total current derivative assets (1) 125 33 Noncurrent assets: Commodity contracts: Electricity 3 4 Natural gas 31 8 Total noncurrent derivative assets (1) 34 12 Total derivative assets (2) $ 159 $ 45 Current liabilities: Commodity contracts: Electricity $ 54 $ 13 Natural gas 1 2 Total current derivative liabilities 55 15 Noncurrent liabilities: Commodity contracts: Electricity 69 133 Natural gas — 3 Total noncurrent derivative liabilities 69 136 Total derivative liabilities (2) $ 124 $ 151 (1) Total current derivative assets are included in Other current assets, and Total noncurrent derivative assets are included in Other noncurrent assets on the condensed consolidated balance sheets. (2) As of June 30, 2021 and December 31, 2020, no derivative assets or liabilities were designated as hedging instruments. PGE’s net volumes related to its Assets and Liabilities from price risk management activities resulting from its derivative transactions, which are expected to deliver or settle at various dates through 2035, were as follows (in millions): June 30, 2021 December 31, 2020 Commodity contracts: Electricity 3 MWhs 6 MWhs Natural gas 167 Decatherms 137 Decatherms Foreign currency $ 19 Canadian $ 19 Canadian PGE has elected to report positive and negative exposures resulting from derivative instruments pursuant to agreements that meet the definition of a master netting arrangement gross on the condensed consolidated balance sheets. In the case of default on, or termination of, any contract under the master netting arrangements, such agreements provide for the net settlement of all related contractual obligations with a given counterparty through a single payment. These types of transactions may include non-derivative instruments, derivatives qualifying for scope exceptions, receivables and payables arising from settled positions, and other forms of non-cash collateral, such as letters of credit. As of June 30, 2021 and December 31, 2020, gross amounts included as Price risk management liabilities subject to master netting agreements was an immaterial amount. Net realized and unrealized losses (gains) on derivative transactions not designated as hedging instruments are classified in Revenues, net or Purchased power and fuel, as applicable, in the condensed consolidated statements of income and comprehensive income and were as follows (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Commodity contracts: Electricity $ (44) $ 15 $ (67) $ 47 Natural Gas (89) (13) (114) (4) Foreign currency exchange — — — 1 Net unrealized and certain net realized losses/(gains) presented in the table above are offset within the condensed consolidated statements of income and comprehensive income by the effects of regulatory accounting. Of the net amounts recognized in Net income for the three-month periods ended June 30, 2021 and 2020, ne t gains o f $112 million and net gains of $1 million, respectively, have been offset. Net gains of $151 million and net losses of $41 million have been offset for the six-month periods ended June 30, 2021 and 2020, respectively. Assuming no changes in market prices and interest rates, the following table indicates the year in which the net unrealized loss/(gain) recorded as of June 30, 2021 related to PGE’s derivative activities would become realized as a result of the settlement of the underlying derivative instrument (in millions): 2021 2022 2023 2024 2025 Thereafter Total Commodity contracts: Electricity $ 23 $ (4) $ 5 $ 6 $ 7 $ 46 $ 83 Natural gas (61) (46) (9) (2) — — (118) Net unrealized loss/(gain) $ (38) $ (50) $ (4) $ 4 $ 7 $ 46 $ (35) PGE’s secured and unsecured debt is currently rated at investment grade by Moody’s Investors Service (Moody’s) and S&P Global Ratings (S&P). Should Moody’s or S&P reduce their rating on the Company’s unsecured debt to below investment grade, PGE could be subject to requests by certain wholesale counterparties to post additional performance assurance collateral, in the form of cash or letters of credit, based on total portfolio positions with each of those counterparties. Certain other counterparties would have the right to terminate their agreements with the Company. The aggregate fair value of derivative instruments with credit-risk-related contingent features that were in a liability position as of June 30, 2021 was $89 million, for which PGE has posted $11 million in collateral, consisting of $9 million of letters of credit and $2 million of cash. If the credit-risk-related contingent features underlying these agreements were triggered at June 30, 2021, the cash requirement to either post as collateral or settle the instruments immediately would have been $80 million. As of June 30, 2021, PGE had $41 million cash collateral posted for derivative instruments with no credit-risk-related contingent features. Cash collateral for derivative instruments is classified as Margin deposits included in Other current assets on the Company’s condensed consolidated balance sheets. As of June 30, 2021, PGE received from counterparties $18 million in collateral, consisting of $2 million of letters of credit and $16 million of cash. The obligation to return cash collateral held for derivative instruments is included in Accrued expenses and other current liabilities on the Company’s condensed consolidated balance sheets. Counterparties representing 10% or more of assets and liabilities from price risk management activities were as follows: June 30, 2021 December 31, 2020 Assets from price risk management activities: Counterparty A 10 % 12 % Counterparty B 13 17 Counterparty C 21 21 Counterparty D 11 16 55 % 66 % Liabilities from price risk management activities: Counterparty E 58 % 93 % See Note 4, Fair Value of Financial Instruments, for additional information concerning the determination of fair value for the Company’s Assets and Liabilities from price risk management activities.

Earnings Per Share (Notes)

Earnings Per Share (Notes)	6 Months Ended
	Jun. 30, 2021
Earnings Per Share [Abstract]
EARNINGS PER SHARE	EARNINGS PER SHARE Basic earnings per share are computed based on the weighted average number of common shares outstanding during the period. Diluted earnings per share are computed using the weighted average number of common shares outstanding and the effect of dilutive potential common shares outstanding during the period using the treasury stock method. Potential common shares consist of: i) employee stock purchase plan shares; and ii) contingently issuable time-based and performance-based restricted stock units, along with associated dividend equivalent rights. Unvested performance-based restricted stock units and associated dividend equivalent rights are included in dilutive potential common shares only after the performance criteria have been met. For the three and six months ended June 30, 2021, unvested performance-based restricted stock units and related dividend equivalent rights of 367 thousand shares were excluded from the dilutive calculation because the performance goals had not been met, with 303 thousand shares excluded for the three and six months ended June 30, 2020. Net income is the same for both the basic and diluted earnings per share computations. The denominators of the basic and diluted earnings per share computations are as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Weighted-average common shares outstanding—basic 89,554 89,489 89,555 89,459 Dilutive effect of potential common shares 118 136 132 143 Weighted-average common shares outstanding—diluted 89,672 89,625 89,687 89,602

Equity (Notes)

Equity (Notes)	6 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Equity	SHAREHOLDERS’ EQUITY The activity in equity during the three- and six-month periods ended June 30, 2021 and 2020 was as follows (dollars in millions, except per share amounts): Common Stock Accumulated Retained Shares Amount Total Balances as of December 31, 2020 89,537,331 $ 1,231 $ (11) $ 1,393 $ 2,613 Issuances of shares pursuant to equity-based plans 39,417 — — — — Stock-based compensation — 2 — — 2 Dividends declared ($0.4075 per share) — — — (36) (36) Net income — — — 96 96 Balances as of March 31, 2021 89,576,748 $ 1,233 $ (11) $ 1,453 $ 2,675 Issuances of shares pursuant to equity-based plans 74,974 1 — — 1 Stock-based compensation — 4 — — 4 Repurchase of common stock (250,000) (3) — (9) (12) Dividends declared ($0.4300 per share) — — — (39) (39) Net income — — — 32 32 Balances as of June 30, 2021 89,401,722 $ 1,235 $ (11) $ 1,437 $ 2,661 Balances as of December 31, 2019 89,387,124 $ 1,220 $ (10) $ 1,381 $ 2,591 Issuances of shares pursuant to equity-based plans 77,397 — — — — Other comprehensive income — — 1 — 1 Dividends declared ($0.3850 per share) — — — (35) (35) Net income — — — 81 81 Balances as of March 31, 2020 89,464,521 $ 1,220 $ (9) $ 1,427 $ 2,638 Issuances of shares pursuant to equity-based plans 42,430 1 — — 1 Stock-based compensation — 3 — — 3 Other comprehensive income — — — — — Dividends declared ($0.3850 per share) — — — (35) (35) Net income — — — 39 39 Balances as of June 30, 2020 89,506,951 $ 1,224 $ (9) $ 1,431 $ 2,646

Contingencies (Notes)

Contingencies (Notes)	6 Months Ended
	Jun. 30, 2021
Contingencies [Abstract]
CONTINGENCIES	CONTINGENCIES PGE is subject to legal, regulatory, and environmental proceedings, investigations, and claims that arise from time to time in the ordinary course of its business. Contingencies are evaluated using the best information available at the time the condensed consolidated financial statements are prepared. Costs incurred in connection with loss contingencies are expensed as incurred. The Company may seek regulatory recovery of certain costs that are incurred in connection with such matters, although there can be no assurance that such recovery would be granted. Loss contingencies are accrued, and disclosed if material, when it is probable that an asset has been impaired or a liability incurred as of the financial statement date and the amount of the loss can be reasonably estimated. If a reasonable estimate of probable loss cannot be determined, a range of loss may be established, in which case the minimum amount in the range is accrued, unless some other amount within the range appears to be a better estimate. A loss contingency will also be disclosed when it is reasonably possible that an asset has been impaired, or a liability incurred, if the estimate or range of potential loss is material. If a probable or reasonably possible loss cannot be reasonably estimated, then PGE: i) discloses an estimate of such loss or the range of such loss, if the Company is able to determine such an estimate; or ii) discloses that an estimate cannot be made and the reasons why the estimate cannot be made. If an asset has been impaired or a liability incurred after the financial statement date, but prior to the issuance of the financial statements, the loss contingency is disclosed, if material, and the amount of any estimated loss is recorded in either the current or the subsequent reporting period, depending on the nature of the underlying event. PGE evaluates, on a quarterly basis, developments in such matters that could affect the amount of any accrual, as well as the likelihood of developments that would make a loss contingency both probable and reasonably estimable. The assessment as to whether a loss is probable or reasonably possible, and as to whether such loss or a range of such loss is estimable, often involves a series of complex judgments about future events. Management is often unable to estimate a reasonably possible loss, or a range of loss, particularly in cases in which: i) the damages sought are indeterminate or the basis for the damages claimed is not clear; ii) the proceedings are in the early stages; iii) discovery is not complete; iv) the matters involve novel or unsettled legal theories; v) significant facts are in dispute; vi) a large number of parties are represented (including circumstances in which it is uncertain how liability, if any, would be shared among multiple defendants); or vii) a wide range of potential outcomes exist. In such cases, there may be considerable uncertainty regarding the timing or ultimate resolution, including any possible loss, fine, penalty, or business impact. EPA Investigation of Portland Harbor An investigation by the United States Environmental Protection Agency (EPA) of a segment of the Willamette River known as Portland Harbor that began in 1997 revealed significant contamination of river sediments. The EPA subsequently included Portland Harbor on the National Priority List pursuant to the federal Comprehensive Environmental Response, Compensation, and Liability Act as a federal Superfund site. PGE has been included among more than one hundred Potentially Responsible Parties (PRPs) as it historically owned or operated property near the river. A Portland Harbor site remedial investigation was completed pursuant to an agreement between the EPA and several PRPs known as the Lower Willamette Group (LWG), which did not include PGE. The LWG funded the remedial investigation and feasibility study and stated that it had incurred $115 million in investigation-related costs. The Company anticipates that such costs will ultimately be allocated to PRPs as a part of the allocation process for remediation costs of the EPA’s preferred remedy. The EPA finalized the feasibility study, along with the remedial investigation, and the results provided the framework for the EPA to determine a clean-up remedy for Portland Harbor that was documented in a Record of Decision (ROD) issued in 2017. The ROD outlined the EPA’s selected remediation plan for clean-up of Portland Harbor, which has an undiscounted estimated total cost of $1.7 billion, comprised of $1.2 billion related to remediation construction costs and $0.5 billion related to long-term operation and maintenance costs. Remediation construction costs were estimated to be incurred over a 13-year period, with long-term operation and maintenance costs estimated to be incurred over a 30-year period from the start of construction. Stakeholders have raised concerns that EPA’s cost estimates are understated. The EPA acknowledged the estimated costs were based on data that was outdated and that pre-remedial design sampling was necessary to gather updated baseline data to better refine the remedial design and estimated cost. A small group of PRPs performed pre-remedial design sampling to update baseline data and submitted the data in an updated evaluation report to the EPA for review. The evaluation report concluded that the conditions of Portland Harbor have improved substantially over the past ten years. In response, the EPA indicated that while it would use the data to inform implementation of the ROD, the EPA’s conclusions remained materially unchanged. With the completion of pre-remedial design sampling, Portland Harbor is now in the remedial design phase, which consists of additional technical information and data collection to be used to design the expected remedial actions. Certain PRPs, not including PGE, have entered into consent agreements to perform remedial design and the EPA has indicated it will take the initial lead to perform remedial design on the remaining areas. The EPA announced on February 12, 2021 that the entirety of Portland Harbor is under an active engineering design phase. PGE continues to participate in a voluntary process to determine an appropriate allocation of costs amongst the PRPs. Significant uncertainties remain surrounding facts and circumstances that are integral to the determination of such an allocation percentage, including remedial design, a final allocation methodology, and data with regard to property specific activities and history of ownership of sites within Portland Harbor that will inform the precise boundaries for clean-up. It is probable that PGE will share in a portion of the costs related to Portland Harbor. Based on the above facts and remaining uncertainties in the voluntary allocation process, PGE does not currently have sufficient information to reasonably estimate the amount, or range, of its potential liability or determine an allocation percentage that would represent PGE’s portion of the liability to clean-up Portland Harbor. However, the Company may obtain sufficient information, prior to the final determination of allocation percentages among PRPs, to develop a reasonable estimate, or range, of its potential liability that would require recording of the estimate, or low end of the range. The Company’s liability related to the cost of remediating Portland Harbor could be material to PGE’s financial position. In cases in which injuries to natural resources have occurred as a result of releases of hazardous substances, federal and state natural resource trustees may seek to recover for damages at such sites, which are referred to as Natural Resource Damages (NRD). The EPA does not manage NRD assessment activities but does provide claims information and coordination support to the NRD trustees. NRD assessment activities are typically conducted by a Council made up of the trustee entities for the site. The Portland Harbor NRD trustees consist of the National Oceanic and Atmospheric Administration, the U.S. Fish and Wildlife Service, the State of Oregon, the Confederated Tribes of the Grand Ronde Community of Oregon, the Confederated Tribes of Siletz Indians, the Confederated Tribes of the Umatilla Indian Reservation, the Confederated Tribes of the Warm Springs Reservation of Oregon (CTWS), and the Nez Perce Tribe. The NRD trustees may seek to negotiate legal settlements or take other legal actions against the parties responsible for the damages. Funds from such settlements must be used to restore injured resources and may also compensate the trustees for costs incurred in assessing the damages. The Company believes that PGE’s portion of NRD liabilities related to Portland Harbor will not have a material impact on its results of operations, financial position, or cash flows. The impact of costs related to EPA and NRD liabilities on the Company’s results of operations is mitigated by the Portland Harbor Environmental Remediation Account (PHERA) mechanism. As approved by the OPUC in 2017, the PHERA allows the Company to defer and recover incurred estimated liabilities and environmental expenditures related to Portland Harbor through a combination of third-party proceeds, such as insurance recoveries, and, if necessary, through customer prices. The mechanism established annual prudency reviews of environmental expenditures and third-party proceeds. Annual expenditures in excess of $6 million, excluding expenses related to contingent liabilities, are subject to an annual earnings test and would be ineligible for recovery to the extent PGE’s actual regulated return on equity exceeds its return on equity as authorized by the OPUC in PGE’s most recent general rate case. PGE’s results of operations may be impacted to the extent such expenditures are deemed imprudent by the OPUC or ineligible per the prescribed earnings test. The Company plans to seek recovery of any costs resulting from EPA’s determination of liability for Portland Harbor through application of the PHERA. At this time, PGE is not recovering any Portland Harbor cost from the PHERA through customer prices. Deschutes River Alliance Clean Water Act Claims In 2016, the Deschutes River Alliance (DRA) filed a lawsuit against the Company (Deschutes River Alliance v. Portland General Electric Company, U.S. District Court of the District of Oregon) that sought injunctive and declaratory relief under the Clean Water Act (CWA) related to alleged past and continuing violations of the CWA. Specifically, DRA claimed PGE had violated certain conditions contained in PGE’s Water Quality Certification for the Pelton/Round Butte Hydroelectric Project (Project) related to dissolved oxygen, temperature, and measures of acidity or alkalinity of the water. DRA alleged the violations were related to PGE’s operation of the Selective Water Withdrawal (SWW) facility at the Project. The SWW, located above Round Butte Dam on the Deschutes River in central Oregon, is, among other things, designed to blend water from the surface with water near the bottom of the reservoir and was constructed and placed into service in 2010, as part of the FERC license requirements, for the purpose of restoration and enhancement of native salmon and steelhead fisheries above the Project. DRA alleged that PGE’s operation of the SWW had caused the above-referenced violations of the CWA, which in turn had degraded the fish and wildlife habitat of the Deschutes River below the Project and harmed the economic and personal interests of DRA’s members and supporters. In March and April 2018, DRA and PGE filed cross-motions for summary judgment and PGE and CTWS, which co-own the Project, filed separate motions to dismiss. CTWS initially appeared as a friend of the court, but subsequently was found to be a necessary party to the lawsuit and joined as a defendant. In August 2018, the U.S. District Court of the District of Oregon (District Court) denied DRA’s motions for partial summary judgment and granted PGE’s and CTWS’s cross-motions for summary judgment, ruling in favor of PGE and CTWS. The District Court found that DRA had not shown a genuine dispute of material fact sufficient to support its contention that PGE and CTWS were operating the Project in violation of the CWA, and accordingly dismissed the case. In October 2018, DRA filed an appeal, and PGE and the CTWS filed cross-appeals, to the Ninth Circuit Court of Appeals. The appeals were fully briefed and oral argument occurred. On June 23, 2021, the Ninth Circuit Court of Appeals issued a decision to dismiss the case. Securities Case During September and October, 2020, three putative class action complaints were filed in U.S. District Court for the District of Oregon against PGE and certain of its officers, captioned Hessel v. Portland General Electric Co. , No. 20-cv-01523 ( “Hessel” ), Cannataro v. Portland General Electric Co. , No. 3:20-cv-01583 ( “Cannataro” ), and Public Employees’ Retirement System of Mississippi v. Portland General Electric Co. , No. 20-cv-01786 ( “PERS of Mississippi” ). Two of these actions were filed on behalf of purported purchasers of PGE stock between April 24, 2020, and August 24, 2020; a third action was filed on behalf of purported purchasers of PGE stock between February 13, 2020, and August 24, 2020. During the fourth quarter of 2020, the plaintiff in Hessel voluntarily dismissed his case and the court consolidated Cannataro and PERS of Mississippi into a single case captioned In re Portland General Electric Company Securities Litigation (the “Securities Action”) and appointed Public Employees’ Retirement System of Mississippi lead plaintiff (“Lead Plaintiff”). On January 11, 2021, Lead Plaintiff filed an amended complaint asserting causes of action arising under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934 for alleged misstatements and omissions regarding, among other things, PGE’s alleged lack of sufficient internal controls and risks associated with PGE's trading activity in wholesale electric markets, purportedly on behalf of purchasers of PGE stock between February 13, 2020, and August 24, 2020 (“the Amended Complaint”). The Amended Complaint demands a jury trial and seeks compensatory damages of an unspecified amount and reimbursement of plaintiffs’ costs, and attorneys’ and expert fees. On March 12, 2021, the defendants filed a motion to dismiss the Amended Complaint. On July 11, 2021, the parties entered into a Stipulation of Settlement (the "Agreement") to fully resolve the Securities Action. The Agreement, which is subject to Court approval, provides for a settlement payment of $6.75 million in exchange for the complete dismissal with prejudice and a release of all claims against the defendants in connection with the Securities Action, without any admission of fault or wrongdoing by the defendants. On July 16, 2021, the Lead Plaintiff filed an application for Court approval of the settlement, which is pending. The Company anticipates that the settlement payment will be paid by the Company’s insurance provider under its insurance policy. In light of the Agreement, the court removed the hearing on the defendants’ pending motion to dismiss from the calendar. Putative Shareholder Derivative Lawsuits On January 26, 2021, a putative shareholder derivative lawsuit was filed in Multnomah County Circuit Court, Oregon, captioned Shimberg v. Pope , No. 21- cv-02957, against one current and one former PGE executive and several members of the Company's Board of Directors (collectively, the "Individual Defendants") and naming the Company as a nominal defendant only. The plaintiff asserts a claim for alleged breaches of fiduciary duties, purportedly on behalf of PGE, arising from the energy trading losses the Company previously announced in August 2020. The plaintiff alleges that the Individual Defendants made material misstatements and omissions and allowed the Company to operate with inadequate internal controls. The complaint demands a jury trial and seeks damages to be awarded to the Company of not less than $10 million, equitable relief to remedy the alleged breaches of fiduciary duty, and an award of plaintiff’s attorneys’ fees and costs. The court has entered an order staying the action until September 15, 2021, or until further order of the court reinstating the action. On June 1, 2021, the plaintiff filed an unopposed motion to consolidate this lawsuit with Ashabraner v. Pope , 21-cv-13698, described below. Since the lawsuit is in early stages, the Company is unable to predict outcomes or estimate a range of reasonably possible loss. On March 17, 2021, a putative shareholder derivative lawsuit was filed in U.S. District Court for the District of Oregon, captioned JS Halberstam Irrevocable Grantor Trust v. Davis , No. 3:21-cv-00413-SI, against one current and one former PGE executive and certain current and former members of the Company's Board of Directors. The plaintiff asserts claims for alleged breaches of fiduciary duties, waste of corporate assets, contribution and indemnification, aiding and abetting, and gross mismanagement, purportedly on behalf of PGE, arising from the energy trading losses the Company previously announced in August 2020. The plaintiff alleges that the defendants made material misstatements and omissions and allowed the Company to operate with inadequate internal controls. The complaint demands a jury trial and seeks equitable relief to remedy and prevent future alleged breaches of fiduciary duty, and an award of plaintiff’s attorneys’ fees and costs. The court has entered an order staying the action until September 15, 2021. Since the lawsuit is in early stages, the Company is unable to predict outcomes or estimate a range of reasonably possible loss. On April 7, 2021, a putative shareholder derivative lawsuit was filed in Multnomah County Circuit Court, Oregon, captioned, Ashabraner v. Pope , 21-cv-13698, against one current and one former PGE executive and several members of the Company's Board of Directors. The plaintiff asserts a claim for alleged breaches of fiduciary duties, purportedly on behalf of PGE, arising from the energy trading losses the Company previously announced in August 2020. The plaintiff alleges that the defendants made material misstatements and omissions and allowed the Company to operate with inadequate internal controls. The complaint demands a jury trial and seeks damages to be awarded to the Company, equitable relief, and an award of plaintiff’s attorneys’ fees and costs. On April 30, 2021, the court entered an order staying the action until September 15, 2021. Since the lawsuit is in early stages, the Company is unable to predict outcomes or estimate a range of reasonably possible loss. On May 21, 2021, a putative shareholder derivative lawsuit was filed in the U.S. District Court for the District of Oregon, Portland Division captioned Berning v. Pope , No. 3:21-cv-00783-SI, against one current and one former PGE executive and several members of the Company's Board of Directors and naming the Company as a nominal defendant only. The plaintiff asserts claims for alleged breaches of fiduciary duties, purportedly on behalf of PGE, arising from the energy trading losses the Company previously announced in August 2020. The plaintiff also asserts a claim against the two executives for contribution and indemnity based on alleged violations of Sections 10(b) and 21D of the Exchange Act. The complaint demands a jury trial and seeks multiple forms of relief, including, among other things: a declaration that defendants breached and/or aided and abetted the breach of their fiduciary duties to PGE; an order directing PGE to reform and improve its corporate governance and internal procedures; restitution; and an award of attorneys’ fees, expenses, and costs. Since the lawsuit is in early stages, the Company is unable to predict outcomes or estimate a range of reasonably possible loss. Governmental Investigations In March, April and May 2021, the Division of Enforcement of the Commodity Futures Trading Commission (the "CFTC"), the Division of Enforcement of the SEC, and the Division of Enforcement of the Federal Energy Regulatory Commission ("FERC"), respectively, informed the Company they are conducting investigations arising out of the energy trading losses the Company previously announced in August 2020. The Company is cooperating with the CFTC, SEC, and FERC. Management cannot at this time predict the eventual scope or outcome of these matters. Colstrip Litigation The Company has a 20% ownership interest in the Colstrip Units 3 and 4 coal-fired generating plant (Colstrip), which is operated by one of the co-owners, Talen Montana, LLC (Talen). Various business disagreements have arisen amongst the co-owners regarding interpretation of the Ownership and Operation (O&O) Agreement and other matters, which are described below. Petition to compel arbitration— On April 12, 2021, Avista Corporation, Puget Sound Energy Inc., PacifiCorp, and Portland General Electric Company (the Petitioners) petitioned in Spokane County Superior Court, Washington. Case No. 21201000-32, against Northwestern Corporation and Talen to compel the arbitration initiated by NorthWestern Corporation to determine whether owners representing 55% or more of the ownership shares can vote to close one or both units of Colstrip, or whether unanimous consent is required. The O&O Agreement among the parties states that any dispute shall be submitted for resolution to a single arbitrator with appropriate expertise. On April 14, 2021, the Petitioners filed a petition to compel arbitration. On May 14, 2021, Talen removed the case to Federal Court (Eastern District of Washington Case No. 2:21-cv-00163-RMP). On May 21, 2021, Talen filed a motion to transfer the case to the U.S. District Court for the District of Montana, or dismiss. Petitioners filed a motion to remand on June 4, 2021. Challenge to constitutionality of Montana Senate Bills 265 and 266 (SB 265 and SB 266)— On May 4, 2021, the Petitioners filed a claim against Northwestern Corporation and Talen in U.S. District Court - Montana, Billings Division, Case No. 1:21-cv-00047-SPW-KLD, based on the passage of SB 265 in Montana, which attempts to void contractual provisions within the co-owner agreement for Colstrip if they do not provide for three arbitrators or provide for venue outside of the county where the plant is located. The passage of SB 265 was supported by Defendants and purports to void the O&O Agreement between all parties, which provides for one arbitrator and venue in Spokane, Washington. The petitioners allege that SB 265 violates the contracts clause of the U.S. Constitution and the Montana Constitution, and is preempted by the Federal Arbitration Act (FAA). The Petitioners seek declaratory relief that SB 265 is unconstitutional as applied to the O&O Agreement and the FAA preempts the enforcement of SB 265. Petitioners filed a First Amended Complaint on May 19, 2021, adding the Attorney General of Montana (Montana AG) as defendant and challenging the constitutionality of Montana Senate Bill 266 (SB 266), which purportedly gives the Montana AG authority to penalize and restrain any co-owner of Colstrip who takes steps to shut-down the plant without unanimous consent, or otherwise fails to pay the costs to maintain the plant. Defendant Northwestern filed an answer on June 2, 2021 and asked tha t the case Talen filed, as described in the “Complaint to implement SB 265 and SB 266” below, and this case be consolidated. On May 27, 2021, Petitioners filed a Motion for Preliminary Injunction, to enjoin the Attorney General from enforcing SB 266 against them. On June 17, 2021, d efendants Northwestern Corporation and Talen filed their Oppositions to Motion for Preliminary Injunction (PI) and the Montana AG filed a response taking no position on the PI, stating the State of Montana does not envision enforcing SB 266 any time soon. The Court scheduled a hearing on the Petitioners’ Motion for PI August 6, 2021. Complaint to implement SB 265 and SB 266— On May 4, 2021, Talen filed a complaint against the Petitioners and Northwestern Corporation, in the Thirteenth Judicial District Court in the State of Montana, as an attempt to implement Montana laws when determining the language of the O&O agreement based on the recent enactment of SB 265, which purports to invalidate provisions of the co-owner operating agreement regarding arbitration, and SB 266, which purports to give the Montana AG authority to prosecute and levy a $100,000 a day fine against any co-owner who takes steps to close Colstrip without unanimous consent of all co-owners. The case was subsequently removed to the U.S. District Court - Montana, Billings Division, Case No. 1:21-cv-00058-SPW-TJC. Since these lawsuit are in early stages, the Company is unable to predict outcomes or estimate a range of reasonably possible loss. Other Matters PGE is subject to other regulatory, environmental, and legal proceedings, investigations, and claims that arise from time to time in the ordinary course of business that may result in judgments against the Company. Although management currently believes that resolution of such matters, individually and in the aggregate, will not have a material impact on its financial position, results of operations, or cash flows, these matters are subject to inherent uncertainties, and management’s view of these matters may change in the future.

Guarantees (Notes)

Guarantees (Notes)	6 Months Ended
	Jun. 30, 2021
Guarantees [Abstract]
GUARANTEES	GUARANTEESPGE enters into financial agreements for, and purchase and sale agreements involving physical delivery of, both power and natural gas that include indemnification provisions relating to certain claims or liabilities that may arise relating to the transactions contemplated by these agreements. Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall maximum amount of the obligation under such indemnifications cannot be reasonably estimated. PGE periodically evaluates the likelihood of incurring costs under such indemnities based on the Company’s historical experience and the evaluation of the specific indemnities. As of June 30, 2021, management believes the likelihood is remote that PGE would be required to perform under such indemnification provisions or otherwise incur any significant losses with respect to such indemnities. The Company has not recorded any liability on the condensed consolidated balance sheets with respect to these indemnities.

Income tax Income tax (Notes)

Income tax Income tax (Notes)	6 Months Ended
	Jun. 30, 2021
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	INCOME TAXES Income tax expense for interim periods is based on the estimated annual effective tax rate, which includes tax credits, regulatory flow-through adjustments, and other items, applied to the Company’s year-to-date, pre-tax income . The significant differences between the U.S. Federal statutory tax rate and PGE’s effective tax rate are reflected in the following table: Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Federal statutory tax rate 21.0 % 21.0 % 21.0 % 21.0 % Federal tax credits * (11.7) (14.4) (9.6) (12.0) State and local taxes, net of federal tax benefit 8.3 10.9 8.7 8.5 Flow-through depreciation and cost basis differences (3.0) (2.6) (0.5) 0.3 Amortization of excess deferred income tax (3.4) (2.5) (3.3) (2.1) Local tax flow-through adjustment — — (6.1) — Other (0.1) (1.0) (1.0) 0.4 Effective tax rate 11.1 % 11.4 % 9.2 % 16.1 % * Federal tax credits primarily consist of production tax credits (PTCs) earned from Company-owned wind-powered generating facilities. PTCs are earned based on a per-kilowatt hour rate and, as a result, the annual amount of PTCs earned will vary based on weather conditions and availability of the facilities. PTCs are earned for 10 years from the in-service dates of the corresponding facilities. PGE’s wind-powered generating facilities are eligible to earn PTCs until various dates through 2030. Local tax flow-through adjustment The Company is subject to a local tax that is recovered through a supplemental tariff based on current tax expense, but for which the Company has also recognized deferred income tax expenses over time. Because it is probable that the local deferred taxes will be flowed through future customer prices in accordance with the supplemental tariff, PGE determined a corresponding regulatory asset should have been recorded. In the first quarter of 2021, PGE recognized a regulatory asset to defer previously recorded deferred income tax expenses in the amount of $9 million with a corresponding credit to Income tax expense in the condensed consolidated statements of income for the six months ended June 30, 2021. The adjustment has no impact to the three months ended June 30, 2021, and is immaterial to prior periods. Carryforwards Federal tax credit carryforwards as of June 30, 2021 and December 31, 2020 were $88 million and $77 million, respectively. These credits primarily consist of PTCs, which will expire at various dates through 2041. PGE believes that it is more likely than not that its deferred income tax assets as of June 30, 2021 will be realized; accordingly, no valuation allowance has been recorded. As of June 30, 2021, and December 31, 2020, PGE had no material unrecognized tax benefits.

Basis of Presentation (Policies

Basis of Presentation (Policies)	6 Months Ended
	Jun. 30, 2021
Basis of Presentation [Abstract]
Consolidation, Policy [Policy Text Block]	These condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the United States Securities and Exchange Commission (SEC). Certain information and note disclosures normally included in financial statements prepared in conformity with accounting principles generally accepted in the United States of America (GAAP) have been condensed or omitted pursuant to such regulations
Inventory, Policy [Policy Text Block]	PGE’s inventories, which are recorded at average cost, consist primarily of materials and supplies for use in operations, maintenance, and capital activities, as well as fuel, which includes natural gas, coal, and oil, for use in the Company’s generating plants. Periodically, PGE assesses whether inventories are recorded at the lower of average cost or net realizable value.
Debt, Policy [Policy Text Block]	PGE typically classifies borrowings under the revolving credit facility and outstanding commercial paper as Short-term debt on the condensed consolidated balance sheets. Long-term debt is recorded at amortized cost in PGE’s condensed consolidated balance sheets. The value of the Company’s First Mortgage Bonds (FMBs) and Pollution Control Revenue Bonds is classified as a Level 2 fair value measurement.
Fair Value of Financial Instruments, Policy [Policy Text Block]	Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of assets and liabilities and their placement within the fair value hierarchy. Assets measured at fair value using net asset value (NAV) as a practical expedient are not categorized in the fair value hierarchy. These assets are listed in the totals of the fair value hierarchy to permit the reconciliation to amounts presented in the financial statements.Changes to market liquidity conditions, the availability of observable inputs, or changes in the economic structure of a security marketplace may require transfer of the securities between levels.
Allocation of Financial Asset to Hierarchy Levels [Policy Text Block]	Assets held in the Nuclear decommissioning trust (NDT) and Non-qualified benefit plan (NQBP) trusts are recorded at fair value in PGE’s condensed consolidated balance sheets and invested in securities that are exposed to interest rate, credit, and market volatility risks. These assets are classified within Level 1, 2, or 3 based on the following factors: Debt securities —PGE invests in highly-liquid United States Treasury securities to support the investment objectives of the trusts. These domestic government securities are classified as Level 1 in the fair value hierarchy due to the availability of quoted prices for identical assets in an active market as of the measurement date. Assets classified as Level 2 in the fair value hierarchy include domestic government debt securities, such as municipal debt, and corporate credit securities. Prices are determined by evaluating pricing data such as broker quotes for similar securities and adjusted for observable differences. Significant inputs used in valuation models generally include benchmark yields and issuer spreads. The external credit rating, coupon rate, and maturity of each security are considered in the valuation, as applicable. Equity securities —Equity mutual fund and common stock securities are classified as Level 1 in the fair value hierarchy due to the availability of quoted prices for identical assets in an active market as of the measurement date. Principal markets for equity prices include published exchanges such as Nasdaq and the NYSE. Money market funds —PGE invests in money market funds that seek to maintain a stable net asset value. These funds invest in high-quality, short-term, diversified money market instruments, short-term treasury bills, federal agency securities, certificates of deposits, and commercial paper. The Company believes the redemption value of these funds is likely to be the fair value, which is represented by the net asset value. Redemption is permitted daily without written notice. The NQBP trust is invested in exchange-traded government money market funds and is classified as Level 1 in the fair value hierarchy due to the availability of quoted prices in published exchanges such as Nasdaq and the NYSE. The money market fund in the NDT is valued at NAV as a practical expedient and is not included in the fair value hierarchy. Assets and liabilities from price risk management activities, recorded at fair value in PGE’s condensed consolidated balance sheets, consist of derivative instruments entered into by the Company to manage its risk exposure to commodity price and foreign currency exchange rates and reduce volatility in net variable power costs (NVPC) for the Company’s retail customers. For additional information regarding these assets and liabilities, see Note 5, Risk Management. For those assets and liabilities from price risk management activities classified as Level 2, fair value is derived using present value formulas that utilize inputs such as forward commodity prices and interest rates. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument, can be derived from observable data, or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include commodity forwards, futures, and swaps. Assets and liabilities from price risk management activities classified as Level 3 consist of instruments for which fair value is derived using one or more significant inputs that are not observable for the entire term of the instrument. These instruments consist of longer-term commodity forwards, futures, and swaps.
Fair Value Transfer, Policy [Policy Text Block]	Transfers out of Level 3 occur when the significant inputs become more observable, such as when the time between the valuation date and the delivery term of a transaction becomes shorter.
Derivatives, Policy [Policy Text Block]	PGE utilizes derivative instruments to manage its exposure to commodity price risk and foreign exchange rate risk to reduce volatility in NVPC for its retail customers. Such derivative instruments, recorded at fair value on the condensed consolidated balance sheets, may include forwards, futures, swaps, and options contracts for electricity, natural gas, and foreign currency, with changes in fair value recorded in the condensed consolidated statements of income and comprehensive income. In accordance with the ratemaking and cost recovery processes authorized by the OPUC, the Company recognizes a regulatory asset or liability to defer the gains and losses from derivative activity until settlement of the associated derivative instrument. PGE may designate certain derivative instruments as cash flow hedges or may use derivative ins truments as economic hedges. The Company does not intend to engage in trading activities for non-retail purposes.
Commitments and Contingencies, Policy [Policy Text Block]	PGE is subject to legal, regulatory, and environmental proceedings, investigations, and claims that arise from time to time in the ordinary course of its business. Contingencies are evaluated using the best information available at the time the condensed consolidated financial statements are prepared. Costs incurred in connection with loss contingencies are expensed as incurred. The Company may seek regulatory recovery of certain costs that are incurred in connection with such matters, although there can be no assurance that such recovery would be granted. Loss contingencies are accrued, and disclosed if material, when it is probable that an asset has been impaired or a liability incurred as of the financial statement date and the amount of the loss can be reasonably estimated. If a reasonable estimate of probable loss cannot be determined, a range of loss may be established, in which case the minimum amount in the range is accrued, unless some other amount within the range appears to be a better estimate. A loss contingency will also be disclosed when it is reasonably possible that an asset has been impaired, or a liability incurred, if the estimate or range of potential loss is material. If a probable or reasonably possible loss cannot be reasonably estimated, then PGE: i) discloses an estimate of such loss or the range of such loss, if the Company is able to determine such an estimate; or ii) discloses that an estimate cannot be made and the reasons why the estimate cannot be made. If an asset has been impaired or a liability incurred after the financial statement date, but prior to the issuance of the financial statements, the loss contingency is disclosed, if material, and the amount of any estimated loss is recorded in either the current or the subsequent reporting period, depending on the nature of the underlying event. PGE evaluates, on a quarterly basis, developments in such matters that could affect the amount of any accrual, as well as the likelihood of developments that would make a loss contingency both probable and reasonably estimable. The assessment as to whether a loss is probable or reasonably possible, and as to whether such loss or a range of such loss is estimable, often involves a series of complex judgments about future events. Management is often unable to estimate a reasonably possible loss, or a range of loss, particularly in cases in which: i) the damages sought are indeterminate or the basis for the damages claimed is not clear; ii) the proceedings are in the early stages; iii) discovery is not complete; iv) the matters involve novel or unsettled legal theories; v) significant facts are in dispute; vi) a large number of parties are represented (including circumstances in which it is uncertain how liability, if any, would be shared among multiple defendants); or vii) a wide range of potential outcomes exist. In such cases, there may be considerable uncertainty regarding the timing or ultimate resolution, including any possible loss, fine, penalty, or business impact.
Guarantees, Indemnifications and Warranties Policies [Policy Text Block]	Generally, a maximum obligation is not explicitly stated in the indemnification provisions and, therefore, the overall maximum amount of the obligation under such indemnifications cannot be reasonably estimated. PGE periodically evaluates the likelihood of incurring costs under such indemnities based on the Company’s historical experience and the evaluation of the specific indemnities.

Revenue Recognition (Tables)

Revenue Recognition (Tables)	6 Months Ended
	Jun. 30, 2021
Revenue Recognition and Deferred Revenue [Abstract]
Disaggregation of Revenue [Table Text Block]	The following table presents PGE’s revenue, disaggregated by customer type (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Retail: Residential $ 249 $ 223 $ 559 $ 502 Commercial 170 140 332 299 Industrial 62 53 122 104 Direct access customers 13 12 24 23 Subtotal 494 428 1,037 928 Alternative revenue programs, net of amortization (8) — (11) 9 Other accrued revenues, net (2) 1 11 6 Total retail revenues 484 429 1,037 943 Wholesale revenues * 41 27 74 74 Other operating revenues 12 13 35 25 Total revenues $ 537 $ 469 $ 1,146 $ 1,042

Balance Sheet Components (Table

Balance Sheet Components (Tables)	6 Months Ended
	Jun. 30, 2021
Balance Sheet Components [Abstract]
Allowance for Credit Losses [Text Block]	The following summarizes activity in the allowance for credit losses (in millions): Three Months Ended June 30, Six Months Ended 2021 2021 Balance as of beginning of period $ 20 $ 16 Increase in provision 8 15 Amounts written off (8) (12) Recoveries 2 3 Balance as of end of period $ 22 $ 22
Schedule of Other Current Assets [Table Text Block]	Other current assets consist of the following (in millions): June 30, 2021 December 31, 2020 Prepaid expenses $ 51 $ 57 Assets from price risk management activities 125 33 Margin deposits 43 8 Other current assets $ 219 $ 98
Schedule of Public Utility Property, Plant, and Equipment [Table Text Block]	Electric utility plant, net consists of the following (in millions): June 30, 2021 December 31, 2020 Electric utility plant $ 11,168 $ 10,974 Construction work-in-progress 510 429 Total cost 11,678 11,403 Less: accumulated depreciation and amortization (3,985) (3,864) Electric utility plant, net $ 7,693 $ 7,539
Schedule of Regulatory Assets and Liabilities [Text Block]	Regulatory assets and liabilities consist of the following (in millions): June 30, 2021 December 31, 2020 Current Noncurrent Current Noncurrent Regulatory assets: Price risk management $ — $ 35 $ — $ 124 Pension and other postretirement plans — 229 — 240 Debt issuance costs — 24 — 25 Trojan decommissioning activities — 98 — 95 Incremental storm costs — 52 — — Other 20 105 23 85 Total regulatory assets $ 20 $ 543 $ 23 $ 569 Regulatory liabilities: Asset retirement removal costs $ — $ 1,028 $ — $ 1,016 Deferred income taxes — 219 — 239 Asset retirement obligations — 39 — 37 Price risk management 70 — 18 — Other 21 68 5 77 Total regulatory liabilities $ 91 * $ 1,354 $ 23 * $ 1,369
Other Liabilities Disclosure [Text Block]	Accrued expenses and other current liabilities consist of the following (in millions): June 30, 2021 December 31, 2020 Accrued employee compensation and benefits $ 51 $ 67 Accrued taxes payable 33 36 Accrued interest payable 27 29 Accrued dividends payable 40 38 Regulatory liabilities—current 91 23 Other 127 129 Total accrued expenses and other current liabilities $ 369 $ 322
Pension and Other Postretirement Benefits Disclosure [Text Block]	Components of net periodic benefit cost under the defined benefit pension plan are as follows (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Service cost $ 5 $ 4 $ 10 $ 8 Interest cost* 7 8 14 16 Expected return on plan assets* (11) (11) (22) (22) Amortization of net actuarial loss* 5 4 10 8 Net periodic benefit cost $ 6 $ 5 $ 12 $ 10 * The expense portion of non-service cost components are included in Miscellaneous income (expense), net within Other income on the Company’s condensed consolidated statements of income and comprehensive income.

Fair Value of Financial Instr_2

Fair Value of Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2021
Fair Value of Financial Instruments [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The Company’s financial assets and liabilities whose values were recognized at fair value in the Company’s condensed consolidated balance sheets are as follows by level within the fair value hierarchy (in millions): As of June 30, 2021 Level 1 Level 2 Level 3 Other (2) Total Assets: Cash equivalents $ — $ — $ — $ — $ — Nuclear decommissioning trust: (1) Debt securities: Domestic government 9 8 — — 17 Corporate credit — 13 — — 13 Money market funds measured at NAV (2) — — — 13 13 Non-qualified benefit plan trust: (3) Debt securities—domestic government 1 — — — 1 Money market funds 2 — — — 2 Equity securities 8 — — — 8 Price risk management activities: (1) (4) Electricity — 33 7 — 40 Natural gas — 111 8 — 119 $ 20 $ 165 $ 15 $ 13 $ 213 Liabilities: Price risk management activities: (1) (4) Electricity $ — $ 50 $ 73 $ — $ 123 Natural gas — 1 — — 1 $ — $ 51 $ 73 $ — $ 124 (1) Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate. (2) Assets are measured at NAV as a practical expedient and not subject to hierarchy level classification disclosure. (3) Excludes insurance policies of $35 million, which are recorded at cash surrender value. (4) For further information, see Note 5, Risk Management. As of December 31, 2020 Level 1 Level 2 Level 3 Other (2) Total Assets: Cash equivalents $ 255 $ — $ — $ — $ 255 Nuclear decommissioning trust: (1) Debt securities: Domestic government 9 11 — — 20 Corporate credit — 13 — — 13 Money market funds measured at NAV (2) — — — 12 12 Non-qualified benefit plan trust: (3) Debt securities—domestic government 1 — — — 1 Money market funds 1 — — — 1 Equity securities 7 — — — 7 Price risk management activities: (1) (4) Electricity — 4 4 — 8 Natural gas — 36 1 — 37 $ 273 $ 64 $ 5 $ 12 $ 354 Liabilities: Price risk management activities: (1) (4) Electricity — 5 141 — 146 Natural gas — 4 1 — 5 $ — $ 9 $ 142 $ — $ 151 (1) Activities are subject to regulation, with certain gains and losses deferred pursuant to regulatory accounting and included in Regulatory assets or Regulatory liabilities as appropriate. (2) Assets are measured at NAV as a practical expedient and not subject to hierarchy level classification disclosure. (3) Excludes insurance policies of $33 million, which are recorded at cash surrender value. (4) For further information, see Note 5, Risk Management.
Fair Value Option, Disclosures [Table Text Block]	Quantitative information regarding the significant, unobservable inputs used in the measurement of Level 3 assets and liabilities from price risk management activities is presented below: Fair Value Valuation Technique Significant Unobservable Input Price per Unit Commodity Contracts Assets Liabilities Low High Weighted Average (in millions) As of June 30, 2021 Electricity physical forwards $ 5 $ 72 Discounted cash flow Electricity forward price (per MWh) $ 18.88 $ 148.39 $ 51.68 Natural gas financial swaps 8 — Discounted cash flow Natural gas forward price (per Decatherm) 1.86 5.01 2.51 Electricity financial futures 2 1 Discounted cash flow Electricity forward price (per MWh) 21.78 96.00 47.47 $ 15 $ 73 As of December 31, 2020 Electricity physical forwards $ — $ 141 Discounted cash flow Electricity forward price (per MWh) $ 11.17 $ 51.18 $ 29.74 Natural gas financial swaps 1 1 Discounted cash flow Natural gas forward price (per Decatherm) 1.52 4.33 2.29 Electricity financial futures 4 — Discounted cash flow Electricity forward price (per MWh) 8.78 58.42 43.71 $ 5 $ 142
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	Changes in the fair value of net liabilities from price risk management activities (net of assets from price risk management activities) classified as Level 3 in the fair value hierarchy were as follows (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Balance as of the beginning of the period $ 117 $ 134 $ 137 $ 97 Net realized and unrealized losses/(gains) * (62) 17 (83) 56 Transfers from Level 3 to Level 2 3 — 4 (2) Balance as of the end of the period $ 58 $ 151 $ 58 $ 151

Price Risk Management (Tables)

Price Risk Management (Tables)	6 Months Ended
	Jun. 30, 2021
Derivative [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	PGE’s Assets and Liabilities from price risk management activities consist of the following (in millions): June 30, 2021 December 31, 2020 Current assets: Commodity contracts: Electricity $ 37 $ 4 Natural gas 88 29 Total current derivative assets (1) 125 33 Noncurrent assets: Commodity contracts: Electricity 3 4 Natural gas 31 8 Total noncurrent derivative assets (1) 34 12 Total derivative assets (2) $ 159 $ 45 Current liabilities: Commodity contracts: Electricity $ 54 $ 13 Natural gas 1 2 Total current derivative liabilities 55 15 Noncurrent liabilities: Commodity contracts: Electricity 69 133 Natural gas — 3 Total noncurrent derivative liabilities 69 136 Total derivative liabilities (2) $ 124 $ 151 (1) Total current derivative assets are included in Other current assets, and Total noncurrent derivative assets are included in Other noncurrent assets on the condensed consolidated balance sheets. (2) As of June 30, 2021 and December 31, 2020, no derivative assets or liabilities were designated as hedging instruments.
Schedule of Derivative Instruments [Table Text Block]	PGE’s net volumes related to its Assets and Liabilities from price risk management activities resulting from its derivative transactions, which are expected to deliver or settle at various dates through 2035, were as follows (in millions): June 30, 2021 December 31, 2020 Commodity contracts: Electricity 3 MWhs 6 MWhs Natural gas 167 Decatherms 137 Decatherms Foreign currency $ 19 Canadian $ 19 Canadian
Derivatives Not Designated as Hedging Instruments [Table Text Block]	Net realized and unrealized losses (gains) on derivative transactions not designated as hedging instruments are classified in Revenues, net or Purchased power and fuel, as applicable, in the condensed consolidated statements of income and comprehensive income and were as follows (in millions): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Commodity contracts: Electricity $ (44) $ 15 $ (67) $ 47 Natural Gas (89) (13) (114) (4) Foreign currency exchange — — — 1
Schedule of Price Risk Derivatives [Table Text Block]	Assuming no changes in market prices and interest rates, the following table indicates the year in which the net unrealized loss/(gain) recorded as of June 30, 2021 related to PGE’s derivative activities would become realized as a result of the settlement of the underlying derivative instrument (in millions): 2021 2022 2023 2024 2025 Thereafter Total Commodity contracts: Electricity $ 23 $ (4) $ 5 $ 6 $ 7 $ 46 $ 83 Natural gas (61) (46) (9) (2) — — (118) Net unrealized loss/(gain) $ (38) $ (50) $ (4) $ 4 $ 7 $ 46 $ (35)
Schedule of Concentration of Risk, by Counterparty [Table Text Block]	Counterparties representing 10% or more of assets and liabilities from price risk management activities were as follows: June 30, 2021 December 31, 2020 Assets from price risk management activities: Counterparty A 10 % 12 % Counterparty B 13 17 Counterparty C 21 21 Counterparty D 11 16 55 % 66 % Liabilities from price risk management activities: Counterparty E 58 % 93 %

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2021
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]	The denominators of the basic and diluted earnings per share computations are as follows (in thousands): Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Weighted-average common shares outstanding—basic 89,554 89,489 89,555 89,459 Dilutive effect of potential common shares 118 136 132 143 Weighted-average common shares outstanding—diluted 89,672 89,625 89,687 89,602

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2021
Equity [Abstract]
Schedule of Stockholders Equity [Table Text Block]	The activity in equity during the three- and six-month periods ended June 30, 2021 and 2020 was as follows (dollars in millions, except per share amounts): Common Stock Accumulated Retained Shares Amount Total Balances as of December 31, 2020 89,537,331 $ 1,231 $ (11) $ 1,393 $ 2,613 Issuances of shares pursuant to equity-based plans 39,417 — — — — Stock-based compensation — 2 — — 2 Dividends declared ($0.4075 per share) — — — (36) (36) Net income — — — 96 96 Balances as of March 31, 2021 89,576,748 $ 1,233 $ (11) $ 1,453 $ 2,675 Issuances of shares pursuant to equity-based plans 74,974 1 — — 1 Stock-based compensation — 4 — — 4 Repurchase of common stock (250,000) (3) — (9) (12) Dividends declared ($0.4300 per share) — — — (39) (39) Net income — — — 32 32 Balances as of June 30, 2021 89,401,722 $ 1,235 $ (11) $ 1,437 $ 2,661 Balances as of December 31, 2019 89,387,124 $ 1,220 $ (10) $ 1,381 $ 2,591 Issuances of shares pursuant to equity-based plans 77,397 — — — — Other comprehensive income — — 1 — 1 Dividends declared ($0.3850 per share) — — — (35) (35) Net income — — — 81 81 Balances as of March 31, 2020 89,464,521 $ 1,220 $ (9) $ 1,427 $ 2,638 Issuances of shares pursuant to equity-based plans 42,430 1 — — 1 Stock-based compensation — 3 — — 3 Other comprehensive income — — — — — Dividends declared ($0.3850 per share) — — — (35) (35) Net income — — — 39 39 Balances as of June 30, 2020 89,506,951 $ 1,224 $ (9) $ 1,431 $ 2,646

Income tax Income tax (Tables)

Income tax Income tax (Tables)	6 Months Ended
	Jun. 30, 2021
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The significant differences between the U.S. Federal statutory tax rate and PGE’s effective tax rate are reflected in the following table: Three Months Ended June 30, Six Months Ended June 30, 2021 2020 2021 2020 Federal statutory tax rate 21.0 % 21.0 % 21.0 % 21.0 % Federal tax credits * (11.7) (14.4) (9.6) (12.0) State and local taxes, net of federal tax benefit 8.3 10.9 8.7 8.5 Flow-through depreciation and cost basis differences (3.0) (2.6) (0.5) 0.3 Amortization of excess deferred income tax (3.4) (2.5) (3.3) (2.1) Local tax flow-through adjustment — — (6.1) — Other (0.1) (1.0) (1.0) 0.4 Effective tax rate 11.1 % 11.4 % 9.2 % 16.1 % * Federal tax credits primarily consist of production tax credits (PTCs) earned from Company-owned wind-powered generating facilities. PTCs are earned based on a per-kilowatt hour rate and, as a result, the annual amount of PTCs earned will vary based on weather conditions and availability of the facilities. PTCs are earned for 10 years from the in-service dates of the corresponding facilities. PGE’s wind-powered generating facilities are eligible to earn PTCs until various dates through 2030.

Basis of Presentation (Details)

Basis of Presentation (Details) retail_customers in Thousands, mi² in Thousands	Jun. 30, 2021mi²retail_customers
Basis of Presentation [Abstract]
Service Area Sq Miles | mi²	4
Incorporated Cities	51
Number of Retail Customers | retail_customers	912

Revenue Recognition (Details)

Revenue Recognition (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Disaggregation of Revenue [Line Items]
Subtotal	$ 494	$ 428	$ 1,037	$ 928
Alternative revenue programs, net of amortization	(8)	0	(11)	9
Other accrued (deferred) revenues, net		(1)	(11)	(6)
Total retail revenues	484	429	1,037	943
Wholesale revenues	41	27	74	74
Other operating revenue	12	13	35	25
Total revenues	537	469	1,146	1,042
Gain on Derivative Instruments, Pretax	4	8	9	24
Other Cost of Operating Revenue	2
Residential [Member]
Disaggregation of Revenue [Line Items]
Subtotal	249	223	559	502
Commercial [Member]
Disaggregation of Revenue [Line Items]
Subtotal	170	140	332	299
Industrial [Member]
Disaggregation of Revenue [Line Items]
Subtotal	62	53	122	104
Direct Access customers [Member]
Disaggregation of Revenue [Line Items]
Subtotal	$ 13	$ 12	$ 24	$ 23

Balance Sheet Components Allowa

Balance Sheet Components Allowance for Credit Losses (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2021	Jun. 30, 2021
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss	$ 20	$ 16
Accounts Receivable, Allowance for Credit Loss, Period Increase (Decrease)	8	15
Accounts Receivable, Allowance for Credit Loss, Writeoff	(8)	(12)
Accounts Receivable, Allowance for Credit Loss, Recovery	2	3
Accounts Receivable, Allowance for Credit Loss	$ 22	$ 22

Balance Sheet Components Other

Balance Sheet Components Other Current Assets (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Other Current Assets [Line Items]
Prepaid expenses	$ 51	$ 57
Assets from price risk management activities	125	33
Margin deposits	43	8
Other current assets	$ 219	$ 98

Balance Sheet Components Electr

Balance Sheet Components Electric Utility Plant, Net (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Electric utility plant	$ 11,168	$ 10,974
Construction work-in-progress	510	429
Total cost	11,678	11,403
Less: accumulated depreciation and amortization	(3,985)	(3,864)
Electric utility plant, net	$ 7,693	$ 7,539

Balance Sheet Components Regula

Balance Sheet Components Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	$ 20		$ 20		$ 23
Regulatory assets - noncurrent	543		543		569
Regulatory Liability, Current	91		91		23
Regulatory liabilities-noncurrent	1,354		1,354		1,369
Purchased power and fuel	185	$ 109	354	$ 262
Removal Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	0		0		0
Regulatory liabilities-noncurrent	1,028		1,028		1,016
Deferred Income Tax Charge [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	0		0		0
Regulatory liabilities-noncurrent	219		219		239
Asset Retirement Obligation Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	0		0		0
Regulatory liabilities-noncurrent	39		39		37
Revenue Subject to Refund [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory liabilities-noncurrent	0		0		0
Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	21		21		5
Regulatory liabilities-noncurrent	68		68		77
Regulatory Clause Revenues, under-recovered
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	70		70		18
Deferred Derivative Gain (Loss) [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0		0		0
Regulatory assets - noncurrent	35		35		124
Pension and Other Postretirement Plans Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0		0		0
Regulatory assets - noncurrent	229		229		240
Loss on Reacquired Debt [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0		0		0
Regulatory assets - noncurrent	24		24		25
Environmental Restoration Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0		0		0
Regulatory assets - noncurrent	98		98		95
Other Regulatory Assets (Liabilities) [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	20		20		23
Regulatory assets - noncurrent	105		105		$ 85
Storm Costs
Regulatory Assets and Liabilities [Line Items]
Increase (Decrease) in Accounts Payable and Other Operating Liabilities	$ 52		$ 52

Balance Sheet Components Othe_2

Balance Sheet Components Other Current Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Accrued employee compensation and benefits	$ 51	$ 67
Accrued taxes payable	33	36
Accrued interest payable	27	29
Accrued dividends payable	40	38
Regulatory liabilities—current	91	23
Other	127	129
Total accrued expenses and other current liabilities	$ 369	$ 322

Balance Sheet Components Pensio

Balance Sheet Components Pension and Other Postretirement Benefits (Details) - Pension Plan [Member] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 5	$ 4	$ 10	$ 8
Interest cost	7	8	14	16
Expected return on plan assets	(11)	(11)	(22)	(22)
Amortization of net actuarial loss	5	4	10	8
Net periodic benefit cost	$ 6	$ 5	$ 12	$ 10

Balance Sheet Components (Detai

Balance Sheet Components (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021USD ($)	Jun. 30, 2020USD ($)	Jun. 30, 2021USD ($)	Jun. 30, 2020USD ($)	Mar. 31, 2021USD ($)	Dec. 31, 2020USD ($)	Apr. 09, 2020USD ($)
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Accounts Receivable, Allowance for Credit Loss	$ 22		$ 22		$ 20	$ 16
Unbilled Receivables, Current	99		99			97
Finite-Lived Intangible Assets, Accumulated Amortization	417		417			388
Amortization of Intangible Assets	15	$ 16	30	$ 31
Line of Credit Facility, Maximum Borrowing Capacity	$ 600		$ 600
Debt Instrument, Covenant Description			65.00%
Ratio of Indebtedness to Net Capital	0.553		0.553
Short-term debt	$ 200		$ 200			150	$ 150
Line of Credit Facility, Remaining Borrowing Capacity	500		500
Line of Credit Facility, Current Borrowing Capacity	220	500	220	500
Letters of credit issued	69		69
Authorized Short-Term Debt	900		900
Long-term Debt, Current Maturities	20		20			$ 160
Proceeds from Issuance of Long-term Debt			0	319
Purchased power and fuel	185	$ 109	354	262
Repayments of Long-term Debt			140	$ 98
Letter of Credit [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Short-term debt	$ 0		$ 0

Fair Value of Financial Instr_3

Fair Value of Financial Instruments Financial Assets and Liabilities Recognized at Fair Value (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Assets:
Cash equivalents	$ 0	$ 255
Debt securities:
Domestic government	17	20
Corporate credit	13	13
Money market funds measured at NAV (2)	13	12
Non-qualified benefit plan trust: (2)
Money market funds	2	1
Equity securities - domestic	8	7
Debt securities—domestic government	1	1
Assets from price risk management activities: (1) (3)
Electricity	40	8
Natural gas	119	37
Total	13	12
Assets, Fair Value Disclosure	213	354
Liabilities from price risk management activities: (1) (3)
Electricity	123	146
Natural gas	1	5
Total	124	151
Fair Value, Inputs, Level 1 [Member]
Assets:
Cash equivalents	0	255
Debt securities:
Domestic government	9	9
Corporate credit	0	0
Non-qualified benefit plan trust: (2)
Money market funds	2	1
Equity securities - domestic	8	7
Debt securities—domestic government	1	1
Assets from price risk management activities: (1) (3)
Electricity	0	0
Natural gas	0	0
Total	20	273
Liabilities from price risk management activities: (1) (3)
Electricity	0	0
Natural gas	0	0
Total	0	0
Fair Value, Inputs, Level 2 [Member]
Assets:
Cash equivalents	0	0
Debt securities:
Domestic government	8	11
Corporate credit	13	13
Non-qualified benefit plan trust: (2)
Money market funds	0	0
Equity securities - domestic	0	0
Debt securities—domestic government	0	0
Assets from price risk management activities: (1) (3)
Electricity	33	4
Natural gas	111	36
Total	165	64
Liabilities from price risk management activities: (1) (3)
Electricity	50	5
Natural gas	1	4
Total	51	9
Fair Value, Inputs, Level 3 [Member]
Assets:
Cash equivalents	0	0
Debt securities:
Domestic government	0	0
Corporate credit	0	0
Non-qualified benefit plan trust: (2)
Money market funds	0	0
Equity securities - domestic	0	0
Debt securities—domestic government	0	0
Assets from price risk management activities: (1) (3)
Electricity	7	4
Natural gas	8	1
Total	15	5
Liabilities from price risk management activities: (1) (3)
Electricity	73	141
Natural gas	0	1
Total	$ 73	$ 142

Fair Value of Financial Instr_4

Fair Value of Financial Instruments Fair Value Options Quantitative Disclosure (Details) - USD ($)	Jun. 30, 2021	Dec. 31, 2020
Low [Member]
Commodity Contracts
Electricity physical forwards	$ 18.88	$ 11.17
Natural gas financial swaps	1.86	1.52
Financial swaps - electricity	21.78	8.78
High [Member]
Commodity Contracts
Electricity physical forwards	148.39	51.18
Natural gas financial swaps	5.01	4.33
Financial swaps - electricity	96	58.42
Weighted Average [Member]
Commodity Contracts
Electricity physical forwards	51.68	29.74
Natural gas financial swaps	2.51	2.29
Financial swaps - electricity	47.47	43.71
Assets [Member]
Commodity Contracts
Electricity physical forwards	5,000,000	0
Natural gas financial swaps	8,000,000	1,000,000
Financial swaps - electricity	2,000,000	4,000,000
Total commodity contracts	15,000,000	5,000,000
Liabilities [Member]
Commodity Contracts
Electricity physical forwards	72,000,000	141,000,000
Natural gas financial swaps	0	1,000,000
Financial swaps - electricity	1,000,000	0
Total commodity contracts	$ 73,000,000	$ 142,000,000

Fair Value of Financial Instr_5

Fair Value of Financial Instruments Unobservable Input Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Balance as of the beginning of the period	$ 117	$ 134	$ 137	$ 97
Net realized and unrealized (gains)/losses	(62)	17	(83)	56
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers Into Level 3	3
Transfers out of Level 3 to Level 2		0	4	2
Balance as of the end of the period	$ 58	$ 151	$ 58	$ 151

Fair Value of Financial Instr_6

Fair Value of Financial Instruments Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Surrender Value, Fair Value Disclosure	$ 35		$ 35	$ 33
Long-term Debt	2,907		2,907	3,046
Unamortized Debt Issuance Expense	12		12	13
Long-term Debt, Fair Value	3,512		3,512	$ 3,808
Net gain or loss recognized in the statement of income offset by regulatory accounting	$ (112)	$ (1)	$ (41)

Risk Management Fair values of

Risk Management Fair values of price risk management assets and liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2021	Dec. 31, 2020
Current Assets, Commodity Contracts:
Electricity	$ 37	$ 4
Natural gas	88	29
Total current derivative assets	125	33
Noncurrent Assets, Commodity Contracts: [Abstract]
Commodity Contract Asset, Noncurrent, Electricity	3	4
Commodity Contract Asset, Noncurrent, Natural Gas	31	8
Derivative Asset, Noncurrent	34	12
Total derivative assets	159	45
Current Liabilities, Commodity Contracts: [Abstract]
Electricity	54	13
Natural gas	1	2
Total current derivative liabilities	55	15
Noncurrent Liabilities, Commodity Contracts: [Abstract]
Electricity	69	133
Natural gas	0	3
Total noncurrent derivative liabilities	69	136
Total derivative liabilities	$ 124	$ 151

Risk Management Net volumes rel

Risk Management Net volumes related to price risk management activities (Details) MWh in Millions, MMBTU in Millions, $ in Millions	Jun. 30, 2021CAD ($)MWhMMBTU	Dec. 31, 2020CAD ($)MWhMMBTU
Commodity contracts:
Electricity | MWh	3	6
Natural gas | MMBTU	167	137
Foreign currency | $	$ 19	$ 19

Risk Management Net realized an

Risk Management Net realized and unrealized gains and losses on derivative transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Commodity contracts:
Electricity	$ (44)	$ 15	$ (67)	$ 47
Natural Gas	(89)	(13)	(114)	(4)
Foreign currency exchange	$ 0	$ 0	$ 0	$ 1

Risk Management Future Year Net

Risk Management Future Year Net Unrealized Gain/Loss Recorded at Balance Sheet Date Expected to Become Realized (Details) $ in Millions	Jun. 30, 2021USD ($)
Electricity [Member]
Commodity contracts:
2020	$ 23
2021	(4)
2022	(5)
2023	(6)
2024	7
Thereafter	46
Total	(83)
Natural Gas [Member]
Commodity contracts:
2020	61
2021	(46)
2022	(9)
2023	(2)
2024	0
Thereafter	0
Total	(118)
Net Unrealized Loss [Member]
Commodity contracts:
2020	38
2021	(50)
2022	(4)
2023	(4)
2024	7
Thereafter	46
Total	$ (35)

Risk Management Counterparties

Risk Management Counterparties Representing 10% or More of Assets and Liabilities from price risk management activities (Details)	Jun. 30, 2021	Dec. 31, 2020
Assets from price risk management activities:
Counterparty A	10.00%	12.00%
Counterparty B	13.00%	17.00%
Counterparty C	21.00%	21.00%
Counterparty D	11.00%	16.00%
Concentration of Risk, Derivative Instruments, Assets	55.00%	66.00%
Liabilities from price risk management activities:
Counterparty E	58.00%	93.00%

Risk Management (Details)

Risk Management (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Net gain or (loss) recognized in the statement of income offset by regulatory accounting	$ 112	$ 1	$ 41
Derivative, Net Liability Position, Aggregate Fair Value	89		89
Collateral Already Posted, Aggregate Fair Value	11		11
Collateral cash requirement	80		80
Deposit Assets	41		41
Purchased power and fuel	$ 185	$ 109	$ 354	$ 262
Deposit Liabilities, Description			18 million
Proceeds from Deposits from Customers			$ 16

Earnings Per Share Components o

Earnings Per Share Components of Earnings Per Share (Details) - shares shares in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Earnings Per Share [Abstract]
Weighted Average Number of Shares Outstanding, Basic	89,554	89,489	89,555	89,459
Dilutive effect of potential common shares	118	136	132	143
Weighted Average Number of Shares Outstanding, Diluted	89,672	89,625	89,687	89,602

Earnings Per Share Earnings Per

Earnings Per Share Earnings Per Share (Details) - shares shares in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Earnings Per Share [Abstract]
Incremental Common Shares Attributable to Dilutive Effect of Contingently Issuable Shares	367	303	367	303

Schedule of Stockholders Equity

Schedule of Stockholders Equity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2021	Mar. 31, 2021	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2021	Jun. 30, 2020
Common Stock, Shares, Outstanding beginning of period		89,537,331			89,537,331
Issuance of shares pursuant to equity-based plans	$ 1	$ 0	$ 1	$ 0
Stockholders' Equity	2,675	2,613	2,638	2,591	$ 2,613	$ 2,591
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			0	1
Dividends declared	(39)	(36)	(35)	(35)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ 32	96	39	81	$ 128	120
Common Stock, Shares, Outstanding end of period	89,401,722				89,401,722
Stockholders' Equity	$ 2,661	$ 2,675	$ 2,646	$ 2,638	$ 2,661	$ 2,646
Common Stock, Dividends, Per Share, Declared	$ 0.4300	$ 0.4075	$ 0.3850	$ 0.3850
Shares Granted, Value, Share-based Payment Arrangement, after Forfeiture	$ 4	$ 2	$ 3
Other					$ (12)
Common Stock [Member]
Common Stock, Shares, Outstanding beginning of period	89,576,748	89,537,331	89,464,521	89,387,124	89,537,331	89,387,124
Issuances of shares pursuant to equity-based plans	74,974	39,417	42,430	77,397
Common Stock, Shares, Outstanding end of period	89,401,722	89,576,748	89,506,951	89,464,521	89,401,722	89,506,951
Common Stock Including Additional Paid in Capital [Member]
Issuance of shares pursuant to equity-based plans	$ 1	$ 0	$ 1	$ 0
Stockholders' Equity	1,233	1,231	1,220	1,220	$ 1,231	$ 1,220
Dividends declared	0	0	0	0
Stockholders' Equity	1,235	1,233	1,224	1,220	1,235	1,224
Shares Granted, Value, Share-based Payment Arrangement, after Forfeiture	4	2	3
Other					(3)
AOCI Attributable to Parent [Member]
Stockholders' Equity	(11)	(11)	(9)	(10)	(11)	(10)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent			0	1
Dividends declared	0	0	0	0
Stockholders' Equity	(11)	(11)	(9)	(9)	(11)	(9)
Other					0
Retained Earnings [Member]
Stockholders' Equity	1,453	1,393	1,427	1,381	1,393	1,381
Dividends declared	39	36	35	35
Stockholders' Equity	$ 1,437	$ 1,453	$ 1,431	$ 1,427	1,437	$ 1,431
Other					$ (9)

Contingencies (Details)

Contingencies (Details) $ in Millions	6 Months Ended
	Jun. 30, 2021USD ($)party
Loss Contingencies [Line Items]
Site Contingency, Names of Other Potentially Responsible Parties | party	100
Litigation Settlement, Expense	$ 115
Loss Contingency, Estimate of Possible Loss	1,700
Loss Contingency, Damages Sought, Value	1,200
Loss Contingency, Range of Possible Loss, Portion Not Accrued	500
Environmental Remediation Expense	6
amount authorized to levy	$ 0.1

Income tax Effective Income Tax

Income tax Effective Income Tax Rate Reconcilitation (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Income Tax Disclosure [Abstract]
Federal statutory tax rate	21.00%	21.00%	21.00%	21.00%
Federal tax credits	(11.70%)	(14.40%)	(9.60%)	(12.00%)
State and local taxes, net of federal tax benefit	8.30%	10.90%	8.70%	8.50%
Flow through depreciation and cost basis differences	(3.00%)	(2.60%)	(0.50%)	0.30%
Excess deferred tax amortization	(3.40%)	(2.50%)	(3.30%)	(2.10%)
Other	0.00%	0.00%	(6.10%)	0.00%
Effective tax rate	11.10%	11.40%	9.20%	16.10%
Effective Income Tax Rate Reconciliation,Other Reconciling Items, Percent	(0.10%)	(1.00%)	(1.00%)	0.40%

Income tax Income tax (Details)

Income tax Income tax (Details) - USD ($)	Jun. 30, 2021	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Deferred Tax Assets, Operating Loss Carryforwards, Domestic	$ 88,000,000	$ 77,000,000
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	0
Deferred Tax Assets, Other Tax Carryforwards	$ 9,000,000