0001193125-26-436451 | 10-Q | XBRL Viewer | Portland General Electric CO OR

Risk Management - Schedule of Net Realized and Unrealized Losses (Gains) on Derivative Transactions Not Designated as Hedging Instruments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Price Risk Management [Abstract]
Electricity	$ 6	$ (39)	$ (32)	$ (32)
Natural Gas	(3)	101	100	146
Foreign currency exchange	$ 0	$ 0	$ 0	$ (1)

Contingencies	9 Months Ended
Sep. 30, 2026
Contingencies [Abstract]
Contingencies	NOTE 8: 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. Legal 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) that began in 1997 of a segment of the Willamette River known as Portland Harbor 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 a 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 that had 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 the EPA’s cost estimates are understated, and PGE estimates undiscounted total remediation costs for Portland Harbor per the ROD could range from $2.9 billion to $5.5 billion. 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 with the passage of time. 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 Company anticipates that remedial design costs will ultimately be allocated to PRPs as a part of the allocation process for remediation costs of the EPA’s preferred remedy. The entirety of Portland Harbor continues under an active engineering design phase. In 2024, the EPA issued a Special Notice Letter (SNL) to 60 entities, including PGE, with requirements and deadlines that may ultimately lead to litigation. Formal negotiations are in process and are likely to continue for several years. PGE continues to participate in a confidential voluntary process to determine an appropriate allocation of costs among the PRPs and believes it is probable that it will share in a portion of the costs related to Portland Harbor. Based on information developed through this process in the second quarter of 2026, PGE's allocation share became reasonably estimable across project areas related to PGE. PGE concluded that sufficient information existed to reasonably estimate the low end of its share of cleanup costs for certain Project Areas and, in Q2 2026 recorded a $20 million liability, which was deferred in the Portland Harbor Environmental Remediation Account (PHERA). In Q3 2026, cost estimates became available for the remaining Project Areas as well as updates to certain previously available cost estimates. Based on this additional information, PGE refined its estimate of its share of cleanup costs and recorded an additional $22 million liability, which was also deferred in the PHERA. As of September 30, 2026, PGE's $42 million recorded liability represents the low end of the reasonably estimable range of its share of Portland Harbor cleanup costs. Significant uncertainties remain regarding PGE's ultimate share of Portland Harbor cleanup costs, as settlement among the PRPs has not been reached and remedial design activities necessary to establish cost ranges for all Project Areas are ongoing. PGE's estimated liability may change as allocation percentages are finalized and remediation cost estimates are further developed and refined. Due to these uncertainties, PGE cannot reasonably estimate the high end of the range of its potential liability. The Company’s ultimate liability for Portland Harbor remediation could be material to PGE’s financial position and cash flows. A portion of cleanup costs are attributable to identified PRPs that cannot be located or are insolvent. The liability associated with these parties is considered an “orphan share” pool that must ultimately be reallocated. Solvent, remaining PRPs may be responsible for the orphan shares, however, there is no single mandated approach to reallocation. Significant uncertainties remain regarding the treatment of the orphan shares and PGE does not currently have sufficient information to reasonably estimate the amount of orphan shares it will be responsible for. The Company’s final liability related to orphan shares could be material to PGE’s financial position. The impact of costs related to EPA liabilities on the Company’s results of operations is mitigated by the PHERA mechanism. For more information on the PHERA, see "Regulatory Assets and Liabilities" in Note 3, Balance Sheet Components. Wrongful Death Claims In September 2025, PGE received a complaint filed in Multnomah County Circuit Court on behalf of the estates of three members of the public and their relatives, with regard to three fatalities that occurred during the January 2024 storm and severe winter weather event. The claim seeks a total of $375 million related to their deaths and surviving family members’ claims. Business entities that own and operate an apartment complex, along with a nearby property owner, are also named as defendants. At this time, as the case is in its early stages, PGE is unable to estimate a range of any reasonably possible loss. The Company denies liability and continues to defend its case. Pearson et al v. Port of Morrow et al In February 2024, a proposed class action was filed in the U.S. District Court for the District of Oregon, Pendleton Division, Case No. 2:24-cv-00362, against the Port of Morrow and other defendants, not including PGE. The plaintiffs alleged they have suffered adverse effects from the defendants’ discharge of nitrogen-laden wastewater. In December 2025, a related action was filed against PGE, which was subsequently dismissed and PGE was added as an additional defendant in the original 2024 lawsuit, concerning wastewater from its Coyote Springs generation facility. Plaintiffs are primarily seeking injunctive relief, medical monitoring, and unspecified monetary damages. The trial date is currently scheduled for September 2027, however, in September 2026, the plaintiffs filed a “Notice of Global Mediation Session” for November 2026. The Company is unable to predict the outcome or estimate a range of any reasonably possible loss in this matter. The Company denies liability and is defending its case. 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 known 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.

Contingencies

9 Months Ended

Sep. 30, 2026

Contingencies [Abstract]

Contingencies

NOTE 8: 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. Legal 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) that began in 1997 of a segment of the Willamette River known as Portland Harbor 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 a 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 that had 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 the EPA’s cost estimates are understated, and PGE estimates undiscounted total remediation costs for Portland Harbor per the ROD could range from $2.9 billion to $5.5 billion.

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 with the passage of time. 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 Company anticipates that remedial design costs will ultimately be allocated to PRPs as a part of the allocation process for remediation costs of the EPA’s preferred remedy. The entirety of Portland Harbor continues under an active engineering design phase.

In 2024, the EPA issued a Special Notice Letter (SNL) to 60 entities, including PGE, with requirements and deadlines that may ultimately lead to litigation. Formal negotiations are in process and are likely to continue for several years.

PGE continues to participate in a confidential voluntary process to determine an appropriate allocation of costs among the PRPs and believes it is probable that it will share in a portion of the costs related to Portland Harbor. Based on information developed through this process in the second quarter of 2026, PGE's allocation share became reasonably estimable across project areas related to PGE. PGE concluded that sufficient information existed to reasonably estimate

the low end of its share of cleanup costs for certain Project Areas and, in Q2 2026 recorded a $20 million liability, which was deferred in the Portland Harbor Environmental Remediation Account (PHERA). In Q3 2026, cost estimates became available for the remaining Project Areas as well as updates to certain previously available cost estimates. Based on this additional information, PGE refined its estimate of its share of cleanup costs and recorded an additional $22 million liability, which was also deferred in the PHERA. As of September 30, 2026, PGE's $42 million recorded liability represents the low end of the reasonably estimable range of its share of Portland Harbor cleanup costs. Significant uncertainties remain regarding PGE's ultimate share of Portland Harbor cleanup costs, as settlement among the PRPs has not been reached and remedial design activities necessary to establish cost ranges for all Project Areas are ongoing. PGE's estimated liability may change as allocation percentages are finalized and remediation cost estimates are further developed and refined. Due to these uncertainties, PGE cannot reasonably estimate the high end of the range of its potential liability. The Company’s ultimate liability for Portland Harbor remediation could be material to PGE’s financial position and cash flows.

A portion of cleanup costs are attributable to identified PRPs that cannot be located or are insolvent. The liability associated with these parties is considered an “orphan share” pool that must ultimately be reallocated. Solvent, remaining PRPs may be responsible for the orphan shares, however, there is no single mandated approach to reallocation. Significant uncertainties remain regarding the treatment of the orphan shares and PGE does not currently have sufficient information to reasonably estimate the amount of orphan shares it will be responsible for. The Company’s final liability related to orphan shares could be material to PGE’s financial position.

The impact of costs related to EPA liabilities on the Company’s results of operations is mitigated by the PHERA mechanism. For more information on the PHERA, see "Regulatory Assets and Liabilities" in Note 3, Balance Sheet Components.

Wrongful Death Claims

In September 2025, PGE received a complaint filed in Multnomah County Circuit Court on behalf of the estates of three members of the public and their relatives, with regard to three fatalities that occurred during the January 2024 storm and severe winter weather event. The claim seeks a total of $375 million related to their deaths and surviving family members’ claims. Business entities that own and operate an apartment complex, along with a nearby property owner, are also named as defendants. At this time, as the case is in its early stages, PGE is unable to estimate a range of any reasonably possible loss. The Company denies liability and continues to defend its case.

Pearson et al v. Port of Morrow et al

In February 2024, a proposed class action was filed in the U.S. District Court for the District of Oregon, Pendleton Division, Case No. 2:24-cv-00362, against the Port of Morrow and other defendants, not including PGE. The plaintiffs alleged they have suffered adverse effects from the defendants’ discharge of nitrogen-laden wastewater. In December 2025, a related action was filed against PGE, which was subsequently dismissed and PGE was added as an additional defendant in the original 2024 lawsuit, concerning wastewater from its Coyote Springs generation facility. Plaintiffs are primarily seeking injunctive relief, medical monitoring, and unspecified monetary damages. The trial date is currently scheduled for September 2027, however, in September 2026, the plaintiffs filed a “Notice of Global Mediation Session” for November 2026. The Company is unable to predict the outcome or estimate a range of any reasonably possible loss in this matter. The Company denies liability and is defending its case.

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 known 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.

- Definition

The entire disclosure for loss and gain contingencies. Describes any existing condition, situation, or set of circumstances involving uncertainty as of the balance sheet date (or prior to issuance of the financial statements) as to a probable or reasonably possible loss incurred by an entity that will ultimately be resolved when one or more future events occur or fail to occur, and typically discloses the amount of loss recorded or a range of possible loss, or an assertion that no reasonable estimate can be made.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 942
-SubTopic 235
-Name Accounting Standards Codification
-Section S99
-Paragraph 2
-Subparagraph (SX 210.9-06)
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
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-Section S50
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 4: http://www.xbrl.org/2009/role/commonPracticeRef
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-Paragraph 1
-Subparagraph (a)
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-URI https://asc.fasb.org/1943274/2147482804/825-20-50-1

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483359/720-20-50-1

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
-SubTopic 20
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SAB Topic 5.Y.Q4)
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
-SubTopic 20
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
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-Paragraph 1
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-URI https://asc.fasb.org/1943274/2147483076/450-20-50-1

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
-SubTopic 20
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org/450-20/tableOfContent

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
-SubTopic 20
-Name Accounting Standards Codification
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-Paragraph 4
-Subparagraph (a)
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Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
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-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483076/450-20-50-9

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
-SubTopic 30
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org/450-30/tableOfContent

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 450
-SubTopic 30
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483049/450-30-50-1

+ Details

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Disaggregation of Revenue [Line Items]
Subtotal	$ 813	$ 789	$ 2,340	$ 2,279
Alternative revenue programs, net of amortization	2	6	21	11
Other accrued revenues, net	(6)	(1)	(11)	9
Total retail revenues	809	794	2,350	2,299
Wholesale revenues	143	136	245	324
Other operating revenue	19	22	69	64
Total revenues	971	952	2,664	2,687
Gain on Derivative Instruments, Pretax	49	74	109	154
Residential [Member]
Disaggregation of Revenue [Line Items]
Subtotal	362	375	1,090	1,115
Commercial [Member]
Disaggregation of Revenue [Line Items]
Subtotal	261	262	744	738
Industrial [Member]
Disaggregation of Revenue [Line Items]
Subtotal	177	141	472	396
Direct Access customers [Member]
Disaggregation of Revenue [Line Items]
Subtotal	$ 13	$ 11	$ 34	$ 30

Shareholders' Equity - Schedule of Shareholders' Equity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2026	Jun. 30, 2026	Mar. 31, 2026	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Sep. 30, 2026	Sep. 30, 2025
Subsidiary, Sale of Stock [Line Items]
Balances	$ 4,123	$ 4,120	$ 4,133	$ 3,852	$ 3,844	$ 3,794	$ 4,133	$ 3,794
Balances, shares			115,559,079				115,559,079
Issuance of shares pursuant to equity-based plans		1			1
Issuance costs pursuant to equity agreements			$ (1)
Issuances of shares pursuant to equity agreements	152			49
Deferred equity issuance costs			(8)
Stock-based compensation	3	(2)	13	3	3	5
Other comprehensive income	1			1
Dividends declared	(66)	(64)	(62)	(58)	(58)	(55)
Net income	$ 119	68	45	103	62	100	$ 232	265
Balances, shares	118,907,598						118,907,598
Balances	$ 4,332	$ 4,123	$ 4,120	$ 3,950	$ 3,852	$ 3,844	$ 4,332	3,950
Common Stock, Dividends, Per Share, Declared	$ 0.525	$ 0.55125	$ 0.525	$ 0.525	$ 0.525	$ 0.5
Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Balances	$ 2,385	$ 2,386	$ 2,382	$ 2,127	$ 2,123	$ 2,118	$ 2,382	$ 2,118
Balances, shares	115,758,254	115,729,030	115,559,079	109,561,888	109,503,325	109,342,251	115,559,079	109,342,251
Issuances of shares pursuant to equity-based plans	31,803	29,224	169,951	47,997	58,563	161,074
Issuance of shares pursuant to equity-based plans		$ 1			$ 1
Issuance costs pursuant to equity agreements			$ (1)
Issuances of shares pursuant to equity agreements	$ 152			$ 49
Issuances of shares pursuant to equity agreements, shares	3,117,541			1,114,529
Deferred equity issuance costs			(8)
Stock-based compensation	$ 3	$ (2)	$ 13	$ 3	$ 3	$ 5
Balances, shares	118,907,598	115,758,254	115,729,030	110,724,414	109,561,888	109,503,325	118,907,598	110,724,414
Balances	$ 2,540	$ 2,385	$ 2,386	$ 2,179	$ 2,127	$ 2,123	$ 2,540	$ 2,179
Accumulated Other Comprehensive Loss [Member]
Subsidiary, Sale of Stock [Line Items]
Balances	(4)	(4)	(4)	(4)	(4)	(4)	(4)	(4)
Other comprehensive income	1			1
Balances	(3)	(4)	(4)	(3)	(4)	(4)	(3)	(3)
Retained Earnings [Member]
Subsidiary, Sale of Stock [Line Items]
Balances	1,742	1,738	1,755	1,729	1,725	1,680	1,755	1,680
Dividends declared	(66)	(64)	(62)	(58)	(58)	(55)
Net income	119	68	45	103	62	100
Balances	$ 1,795	$ 1,742	$ 1,738	$ 1,774	$ 1,729	$ 1,725	$ 1,795	$ 1,774

Segment Reporting

9 Months Ended

Sep. 30, 2026

Segment Reporting [Abstract]

Segment Information

NOTE 11: SEGMENT INFORMATION

PGE is a vertically-integrated electric utility engaged in the generation, transmission, distribution, and retail sale of electricity. The Company participates in wholesale markets by purchasing and selling electricity and natural gas in an effort to meet the needs of, and obtain reasonably-priced power for its retail customers, manage risk, and administer its long-term wholesale contracts. The Company generates revenues and cash flows primarily from the sale and distribution of electricity to retail customers in its service territory in the State.

The Company has identified one operating and reportable segment and defines its segment on the basis of the way in which internally reported financial information is regularly reviewed by the chief operating decision maker (CODM) to analyze financial performance, make decisions, and allocate resources. The Company’s CODM is the President and Chief Executive Officer.

The Company’s CODM assesses the segment’s performance by using Consolidated Net Income. The CODM uses Consolidated Net Income predominantly as a key input to earnings per share and return on equity, which is an important metric for investors and regulators and is also tied to employee compensation.

The table below provides information about the Company’s single business segment, including significant segment expenses, and includes reconciliation to Consolidated Net Income (dollars in millions):


	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Total revenues	$	971		$	952		$	2,664		$	2,687
Operating expenses:
Purchased power and fuel		383			372			1,040			1,034
Operating and maintenance expense:
Generation, transmission and distribution		115			112			337			336
Administrative and other		86			99			282			291
Total operating and maintenance expense		201			211			619			627
Depreciation and amortization		146			148			433			427
Taxes other than income taxes		54			47			157			139
Total operating expenses		784			778			2,249			2,227
Income from operations		187			174			415			460
Interest expense, net:
Interest expense		67			62			193			182
Allowance for borrowed funds used during construction		(5	)		(2	)		(10	)		(9	)
Total interest expense, net		62			60			183			173
Other income, net:		13			9			40			32
Income before income taxes		138			123			272			319
Income tax expense		19			20			40			54
Net income	$	119		$	103		$	232		$	265

Certain additional financial information relating to the Company’s single business segment was as follows (dollars in millions):


	September 30, 2026		December 31, 2025
Total assets	$	13,815	$	13,230
Equity method investments		22		19


	Nine Months Ended September 30,
	2026			2025
Capital expenditures		(1,085	)		(899	)

- Definition

The entire disclosure for segment reporting.

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Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025	Dec. 31, 2025
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Net realized gains	$ 2	$ 0	$ 6	$ 4
Unamortized Debt Issuance Expense	19		19		$ 17
Long-term Debt, Fair Value	4,354		4,354		4,311
Notes Payable to Banks [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt	$ 5,010		$ 5,010		$ 4,662

- Definition

Amount, after deduction of unamortized premium (discount) and debt issuance cost, of long-term debt. Excludes lease obligation.

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Earnings Per Share (Details) - shares shares in Thousands	3 Months Ended		9 Months Ended
Earnings Per Share (Details) - shares shares in Thousands	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Earnings Per Share [Abstract]
Incremental Common Shares Attributable to Dilutive Effect of Contingently Issuable Shares	652	640	652	640

- Definition

Additional shares included in the calculation of diluted EPS as a result of the potentially dilutive effect of contingently issuable shares. Contingently issuable shares are those shares that are issuable for little or no cash contingent on certain conditions being met.

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Fair Value of Financial Instruments Fair Value Options Quantitative Disclosure (Details) $ in Millions	Sep. 30, 2026 USD ($) Decatherm MWh	Dec. 31, 2025 USD ($) Decatherm MWh
Minimum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Electricity physical forward purchase, price per unit \| MWh	24.78	22.99
Natural gas financial swaps, price per unit \| Decatherm	1.6	1.67
Electricity financial futures, price per unit \| MWh	27	31
Maximum [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Electricity physical forward purchase, price per unit \| MWh	93.51	94.65
Natural gas financial swaps, price per unit \| Decatherm	3.61	2.76
Electricity financial futures, price per unit \| MWh	88	84
Weighted Average [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Electricity physical forward purchase, price per unit \| MWh	57.26	59.28
Natural gas financial swaps, price per unit \| Decatherm	2.08	2.15
Electricity financial futures, price per unit \| MWh	63.76	52.13
Assets [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Electricity physical forward purchase	$ 0	$ 0
Natural gas financial swaps	1	0
Financial swaps - electricity	1	1
Total commodity contracts	2	1
Liabilities [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Electricity physical forward purchase	34	37
Natural gas financial swaps	10	4
Financial swaps - electricity	0	0
Total commodity contracts	$ 44	$ 41

Income Taxes

9 Months Ended

Sep. 30, 2026

Income Tax Disclosure [Abstract]

Income Taxes

NOTE 10: INCOME TAXES

The effective tax rates were 13.8% and 16.3% for the three months ended September 30, 2026 and 2025, respectively. For the nine months ended September 30, 2026 and 2025, the effective tax rates were 14.7% and 16.9%, respectively. PGE’s effective tax rate is below the federal statutory rate of 21% for 2026 and 2025 primarily due to the effect of energy-related tax credits.

- Definition

The entire disclosure for income tax.

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+ Details

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - $ / shares	Sep. 30, 2026	Dec. 31, 2025
Statement of Financial Position [Abstract]
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	118,907,598	115,559,079
Common stock, shares outstanding	118,907,598	115,559,079

- Definition

Number of shares of common stock outstanding. Common stock represent the ownership interest in a corporation.

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- Definition

The maximum number of nonredeemable preferred shares (or preferred stock redeemable solely at the option of the issuer) permitted to be issued by an entity's charter and bylaws.

+ References + Details

- Definition

Number of shares issued for nonredeemable preferred shares and preferred shares redeemable solely at option of issuer. Includes, but is not limited to, preferred shares issued, repurchased, and held as treasury shares. Excludes preferred shares classified as debt.

+ References + Details

- Definition

Aggregate share number for all nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer) held by stockholders. Does not include preferred shares that have been repurchased.

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Balance Sheet Components - Schedule of Allowance for Uncollectible Accounts Activity (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2026	Sep. 30, 2026
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Balance as of beginning of period	$ 14	$ 13
Increase in provision	3	9
Amounts written off	(5)	(14)
Recoveries	2	6
Balance as of end of period	$ 14	$ 14

Segment Information - Certain Additional Financial Information Relating to Single Business Segment (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Dec. 31, 2025
Segment Reporting [Abstract]
Assets	$ 13,815		$ 13,230
Equity Method Investments	22		$ 19
Capital expenditures	$ (1,085)	$ (899)

- Definition

Amount of asset recognized for present right to economic benefit.

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+ Details

- Definition

This item represents the carrying amount on the entity's balance sheet of its investment in common stock of an equity method investee. This is not an indicator of the fair value of the investment, rather it is the initial cost adjusted for the entity's share of earnings and losses of the investee, adjusted for any distributions (dividends) and other than temporary impairment (OTTI) losses recognized.

+ References + Details

Segment Information (Details)	9 Months Ended
Segment Information (Details)	Sep. 30, 2026 Segment
Segment Reporting [Abstract]
Number of operating segments	1
Number of reportable segments	1
Segment Reporting, CODM, Individual Title and Position or Group Name [Extensible Enumeration]	srt:ChiefExecutiveOfficerMember, srt:PresidentMember
Segment Reporting, CODM, Profit (Loss) Measure, How Used, Description	The Company’s CODM assesses the segment’s performance by using Consolidated Net Income. The CODM uses Consolidated Net Income predominantly as a key input to earnings per share and return on equity, which is an important metric for investors and regulators and is also tied to employee compensation.

Risk Management

9 Months Ended

Sep. 30, 2026

Price Risk Management [Abstract]

Risk Management

NOTE 5: 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 the Company’s long-term wholesale contracts. Wholesale market transactions include purchases and sales of both power and fuel resulting from economic dispatch decisions with respect to Company-owned generation resources. The Company also performs wholesale market services for third parties in the region and purchases and sells environmental credits in the wholesale marketplace. 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 in order 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 ratemaking and cost recovery processes authorized by the OPUC, PGE recognizes a regulatory asset or liability to defer the gains and losses from derivative activity until settlement of the associated derivative instrument. The Company may designate certain derivative instruments as cash flow hedges or may use derivative instruments as economic hedges. PGE 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):


	September 30, 2026		December 31, 2025
Current assets:
Commodity contracts:
Electricity	$	3	$	29
Natural gas		1		3
Total current derivative assets (1)		4		32
Noncurrent assets:
Commodity contracts:
Electricity		1		1
Natural gas		2		—
Total noncurrent derivative assets (1)		3		1
Total derivative assets (2)	$	7	$	33
Current liabilities:
Commodity contracts:
Electricity	$	12	$	19
Natural gas		101		139
Total current derivative liabilities		113		158
Noncurrent liabilities:
Commodity contracts:
Electricity		29		31
Natural gas		20		25
Total noncurrent derivative liabilities		49		56
Total derivative liabilities (2)	$	162	$	214

(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 September 30, 2026 and December 31, 2025, no commodity derivative assets or liabilities were designated as hedging instruments.

PGE’s net purchase (sales) 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):


	September 30, 2026				December 31, 2025
Commodity contracts:
Electricity		(1	)	MWhs		1	MWhs
Natural gas		244		Decatherms		224	Decatherms
Foreign currency	$	22		Canadian	$	9	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 September 30, 2026, gross amounts included as Price risk management liabilities subject to master netting agreements were $32 million, entirely for natural gas, for which PGE has posted $13 million collateral. As of December 31, 2025, gross amounts included as Price risk management liabilities subject to master netting agreements were $41 million, all of which was for natural gas, for which PGE had posted $14 million collateral.

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 September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Commodity contracts:
Electricity	$	6		$	(39	)	$	(32	)	$	(32	)
Natural Gas		(3	)		101			100			146
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 September 30, 2026 and 2025, no net gains and $37 million of net losses, respectively, have been offset. Net gains of $14 million and $25 million have been offset for the nine-month periods ended September 30, 2026 and 2025, respectively.

Assuming no changes in market prices and interest rates, the following table indicates the year in which the net unrealized loss recorded as of September 30, 2026 related to PGE’s derivative activities would become realized as a result of the settlement of the underlying derivative instrument (in millions):


	2026		2027		2028		2029		2030		Thereafter		Total
Commodity contracts:
Electricity	$	3	$	5	$	4	$	4	$	4	$	17	$	37
Natural gas		35		73		7		3		—		—		118
Net unrealized loss	$	38	$	78	$	11	$	7	$	4	$	17	$	155

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 September 30, 2026 was $157 million, for which PGE has posted $54 million in collateral, consisting of $22 million of letters of credit and $32 million of cash. If the credit-risk-related contingent features underlying these agreements were triggered at September 30, 2026, the cash requirement to either post as collateral or settle the instruments immediately would have been $123 million. As of September 30, 2026, PGE had $12 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 September 30, 2026, PGE held from counterparties $10 million in collateral, consisting $8 million of letters of credit and $2 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.

PGE is exposed to credit risk in its commodity price risk management activities related to potential nonperformance by counterparties. Credit risk may be concentrated to the extent the Company’s counterparties have similar economic, industry or other characteristics and due to direct or indirect relationships among the counterparties. PGE manages the risk of counterparty default according to its credit policies by performing financial credit reviews, setting limits and monitoring exposures, and requiring collateral (in the form of cash, letters of credit, and guarantees) when needed. The Company also uses standardized enabling agreements and, in certain cases, master netting agreements, which allow for the netting of positive and negative exposures under multiple agreements with counterparties.

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.

- Definition

The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
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-Name Accounting Standards Codification
-Section 50
-Paragraph 18
-Subparagraph (d)
-Publisher FASB
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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-Subparagraph (b)
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 14: http://www.xbrl.org/2003/role/disclosureRef
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Reference 28: http://www.xbrl.org/2003/role/disclosureRef
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+ Details

Revenue Recognition (Tables)

9 Months Ended

Sep. 30, 2026

Revenue Recognition [Abstract]

Disaggregation of Revenue

The following table presents PGE’s revenue, disaggregated by customer type (in millions):


	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Retail:
Residential	$	362		$	375		$	1,090		$	1,115
Commercial		261			262			744			738
Industrial		177			141			472			396
Direct access customers		13			11			34			30
Subtotal		813			789			2,340			2,279
Alternative revenue programs, net of amortization		2			6			21			11
Other accrued revenues, net		(6	)		(1	)		(11	)		9
Total retail revenues		809			794			2,350			2,299
Wholesale revenues*		143			136			245			324
Other operating revenues		19			22			69			64
Total revenues	$	971		$	952		$	2,664		$	2,687

* Wholesale revenues include $49 million and $74 million related to electricity commodity contract derivative settlements for the three months ended September 30, 2026 and 2025, respectively, and $109 million and $154 million for the nine months ended

September 30, 2026 and 2025, 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.

Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2026

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

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 September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025
Weighted-average common shares outstanding—basic		118,199		110,170		116,534		109,708
Dilutive effect of potential common shares		472		246		551		250
Weighted-average common shares outstanding—diluted		118,671		110,416		117,085		109,958

Fair Value of Financial Instruments Fair Value Unobservable Input Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]
Balance as of the beginning of the period	$ 49	$ 31	$ 40	$ 34
Net realized and unrealized losses/(gains)	(6)	(1)	2	3
Transfers from Level 3 to Level 2	(1)		0	(2)
Transfers from Level 3 to Level 2		5
Balance as of the end of the period	$ 42	$ 35	$ 42	$ 35

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

+ References + Details

Balance Sheet Components - Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2026	Dec. 31, 2025
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	$ 257	$ 168
Regulatory assets - noncurrent	513	619
Regulatory Liability, Current	65	74
Regulatory liabilities-noncurrent	1,524	1,490
Removal Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	0	0
Regulatory liabilities-noncurrent	1,279	1,245
Deferred Income Tax Charge [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	0	0
Regulatory liabilities-noncurrent	215	228
Other Regulatory Liabilities [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	59	53
Regulatory liabilities-noncurrent	30	16
us-gaap_revenuerefund
Regulatory Assets and Liabilities [Line Items]
Regulatory Liability, Current	6	21
Regulatory liabilities-noncurrent	0	1
Deferred Derivative Gain (Loss) [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	109	127
Regulatory assets - noncurrent	46	54
Pension and Other Postretirement Plans Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0	0
Regulatory assets - noncurrent	64	64
Environmental Restoration Costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0	0
Regulatory assets - noncurrent	168	161
Other Regulatory Assets [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	29	14
Regulatory assets - noncurrent	95	98
Storm Costs
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	12	13
Regulatory assets - noncurrent	27	33
Fire
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	5	5
Regulatory assets - noncurrent	11	14
wildfire
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	35	9
Regulatory assets - noncurrent	3	33
Portland Harbor Environmental Remediation Account
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	0	0
Regulatory assets - noncurrent	65	24
StormCosts - RCE
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	43	0
Regulatory assets - noncurrent	22	90
StormCosts - Jan 2024
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets, Current	24	0
Regulatory assets - noncurrent	$ 12	$ 48

Shareholders' Equity (Tables)

9 Months Ended

Sep. 30, 2026

Equity [Abstract]

Schedule of Shareholders' Equity

The activity in equity during the three and nine-month periods ended September 30, 2026 and 2025 was as follows (dollars in millions, except per share amounts):


	Common Stock					Accumulated Other
	Shares		Amount			Comprehensive Loss			Retained Earnings			Total
Balances as of December 31, 2025		115,559,079	$	2,382		$	(4	)	$	1,755		$	4,133
Issuances of shares pursuant to equity-based plans		169,951		—			—			—			—
Issuance costs pursuant to equity agreements		—		(1	)		—			—			(1	)
Deferred equity issuance costs		—		(8	)		—			—			(8	)
Stock-based compensation		—		13			—			—			13
Dividends declared ($0.525 per share)		—		—			—			(62	)		(62	)
Net income		—		—			—			45			45
Balances as of March 31, 2026		115,729,030		2,386			(4	)		1,738			4,120
Issuances of shares pursuant to equity-based plans		29,224		1			—			—			1
Stock-based compensation		—		(2	)		—			—			(2	)
Dividends declared ($0.55125 per share)		—		—			—			(64	)		(64	)
Net income		—		—			—			68			68
Balances as of June 30, 2026		115,758,254		2,385			(4	)		1,742			4,123
Issuances of shares pursuant to equity-based plans		31,803		—			—			—			—
Issuances of shares pursuant to equity agreements		3,117,541		152			—			—			152
Stock-based compensation		—		3			—			—			3
Other comprehensive income		—		—			1			—			1
Dividends declared ($0.5250 per share)		—		—			—			(66	)		(66	)
Net income		—		—			—			119			119
Balances as of September 30, 2026		118,907,598	$	2,540		$	(3	)	$	1,795		$	4,332


	Common Stock				Accumulated Other
	Shares		Amount		Comprehensive Loss			Retained Earnings			Total
Balances as of December 31, 2024		109,342,251	$	2,118	$	(4	)	$	1,680		$	3,794
Issuances of shares pursuant to equity-based plans		161,074		—		—			—			—
Stock-based compensation		—		5		—			—			5
Dividends declared ($0.500 per share)		—		—		—			(55	)		(55	)
Net income		—		—		—			100			100
Balances as of March 31, 2025		109,503,325		2,123		(4	)		1,725			3,844
Issuances of shares pursuant to equity-based plans		58,563		1		—			—			1
Stock-based compensation		—		3		—			—			3
Dividends declared ($0.525 per share)		—		—		—			(58	)		(58	)
Net income		—		—		—			62			62
Balances as of June 30, 2025		109,561,888		2,127		(4	)		1,729			3,852
Issuances of shares pursuant to equity-based plans		47,997		—		—			—			—
Issuances of shares pursuant to equity agreements		1,114,529		49		—			—			49
Stock-based compensation		—		3		—			—			3
Other comprehensive income		—		—		1			—			1
Dividends declared ($0.5250 per share)		—		—		—			(58	)		(58	)
Net income		—		—		—			103			103
Balances as of September 30, 2025		110,724,414	$	2,179	$	(3	)	$	1,774		$	3,950

Basis of Presentation (Details) mi² in Thousands, RetailCustomers in Thousands, Population in Millions, $ in Millions		3 Months Ended		9 Months Ended
	Feb. 15, 2026 USD ($) Customers	Sep. 30, 2026 USD ($) mi² RetailCustomers Population	Sep. 30, 2025 USD ($)	Sep. 30, 2026 USD ($) mi² RetailCustomers Population	Sep. 30, 2025 USD ($)	Mar. 23, 2026 USD ($)
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items]
Service area sq miles \| mi²		4		4
Incorporated cities		51		51
Number of retail customers \| RetailCustomers		963		963
Service area population \| Population		2		2
Interest income from regulatory assets		$ 3	$ 3	$ 15	$ 12
Remaining amount in realized and unrealized gains		1	2	7	5
Immaterial amount		1	$ 1	1	$ 1
Bridge facility amount		$ 850		$ 850		$ 1,300
Delay draw term loan amount						$ 700
PacifiCorp
Collaborative Arrangement and Arrangement Other than Collaborative [Line Items]
Asset acquisition, date of agreement	Feb. 15, 2026
Number of customers acquired \| Customers	140,000
Purchase price	$ 1,900
Bridge facility from bank	1,900
Expects equity commitments to finance acquisition	600
Termination fee	$ 35

Basis of Presentation

9 Months Ended

Sep. 30, 2026

Basis of Presentation [Abstract]

Basis of Presentation

NOTE 1: BASIS OF PRESENTATION

Nature of Business

Portland General Electric Company (PGE or the Company) is a single, vertically-integrated electric utility engaged in the generation, purchase, transmission, distribution, and retail sale of electricity in the State of Oregon (State). The Company also participates in the wholesale market by purchasing and selling electricity, natural gas, and environmental credits in an effort to meet the needs of, and obtain reasonably-priced power for, its retail customers, manage risk, and administer its long-term wholesale contracts. The Company develops products and service offerings for the benefit of retail and wholesale 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 owns unregulated, non-utility real estate comprised primarily of PGE’s corporate headquarters. The Company’s corporate headquarters is located in Portland, Oregon and its approximately 4,000 square mile, State-approved service area, entirely within the State, encompasses 51 incorporated cities. As of September 30, 2026, PGE served 963,000 retail customers within a service area of approximately 2 million residents.

PGE is subject to the jurisdiction of the Public Utility Commission of Oregon (OPUC) with respect to retail prices, utility services, accounting policies and practices, issuances of securities, and certain other matters. Retail prices are based on the Company’s cost to serve customers, including an opportunity to earn a reasonable rate of return, as determined by the OPUC. The Company is also subject to regulation by the Federal Energy Regulatory Commission (FERC) in matters related to wholesale energy transactions, transmission services, reliability standards, natural gas pipelines, hydroelectric project licensing, accounting policies and practices, short-term debt issuances, and certain other matters.

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 nine months ended September 30, 2026 and 2025 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 a normal recurring nature, unless otherwise noted. The financial information as of December 31, 2025 is derived from the Company’s audited consolidated financial statements and notes thereto for the year ended December 31, 2025, included in Item 8 of PGE’s Annual Report on Form 10-K, filed with the SEC on February 17, 2026, 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 nine months ended September 30, 2026 and 2025.

Miscellaneous Income, Net

Miscellaneous income, net includes $3 million in interest income from regulatory assets for both of the three months ended September 30, 2026 and 2025. The remaining activity is comprised of $1 million and $2 million in realized and unrealized gains on the non-qualified benefit plan (NQBP) trust assets and $1 million and an immaterial amount in other miscellaneous income in 2026 and 2025, respectively.

For the nine months ended September 30, 2026 and 2025, respectively, Miscellaneous income, net includes $15 million and $12 million in interest income from regulatory assets and $7 million and $5 million in realized and unrealized gains on the NQBP trust assets. The remaining activity is comprised of $1 million and an immaterial amount in other miscellaneous income in 2026 and 2025, respectively.

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. Certain costs are estimated for the full year and allocated to interim periods based on estimates of operating time expired, benefit received, or activity associated with the interim period; accordingly, such costs may not be reflective of amounts to be recognized for a full year. Due to seasonal fluctuations in electricity sales, as well as the price of wholesale electricity and natural gas, interim financial results do not necessarily represent those to be expected for the year.

Recent Accounting Pronouncements

In November 2024, the FASB issued Accounting Standards Update (ASU) 2024-03 Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses. ASU 2024-03 requires additional disclosure, in the notes to financial statements, of specified information about certain costs and expenses. For calendar year-end entities, the update will be effective for annual periods beginning on January 1, 2027, and interim reporting periods beginning on January 1, 2028. Early adoption is permitted. PGE is assessing the impact of adoption on the consolidated financial statements and does not plan to early adopt the standard.

In December 2025, the FASB issued ASU 2025-10 Government Grants (Topic 832): Accounting for Government Grants Received by Business Entities. ASU 2025-10 adds guidance to Accounting Standards Codification (ASC) 832 on the recognition, measurement, and presentation of government grants. For calendar year-end entities, the update will be effective for annual periods beginning on January 1, 2029. Early adoption is permitted. PGE is assessing the impact of adoption on the consolidated financial statements and does not plan to early adopt the standard.

In May 2026, the FASB issued ASU 2026-02 Environmental Credits and Environmental Credit Obligations (Topic 818). ASU 2026-02 provides specific guidance for accounting for environmental credits and environmental credit obligations. For calendar year-end entities, the update will be effective for annual periods beginning on January 1, 2028. Early adoption is permitted. PGE is assessing the impact of adoption on the consolidated financial statements and does not plan to early adopt the standard.

Pending Acquisition

On February 15, 2026, PGE, through a newly formed, wholly owned subsidiary, entered into an Asset Purchase and Service Area Transfer Agreement (the “Agreement”) with PacifiCorp, an indirect subsidiary of Berkshire Hathaway Energy Company, to acquire select portions of PacifiCorp’s Washington state regulated utility retail business. Under the Agreement, PGE would acquire certain assets and liabilities related to generation, transmission, and distribution business to serve the related service area comprised of approximately 140,000 customers. The stated purchase price is $1.9 billion in cash, subject to customary adjustments, including adjustments for net working capital, regulatory assets and liabilities, assumed liabilities, and capital expenditures at closing.

Upon execution of the Agreement, the acquisition was supported by a fully committed bridge facility with Barclays Bank PLC and JPMorgan Chase Bank, N.A. for $1.9 billion. On March 23, 2026, the bridge facility was amended to an amount of approximately $1.3 billion and at the same time, the Company entered into a 364-day Delay Draw Term Loan in the amount of approximately $700 million. Borrowings under the Delayed Draw Term Loan bear interest at a rate equal to either (i) Term SOFR Rate, or (ii) the Alternate Base Rate in each case, plus an applicable margin determined by reference to the Company’s long-term debt securities credit ratings. The Company expects to permanently finance the transaction through a balanced mix of debt, equity, and its minority investment partner, Manulife Infrastructure Fund III L.P. and its affiliates including John Hancock Life Insurance Company (USA) (“Manulife”). In connection with the financing plan, PGE expects equity commitments from Manulife to finance up to $600 million of the purchase. Assuming the closing of the transactions contemplated by the Agreement and the consummation of the financing transactions, Manulife will be the Company's joint venture partner in the business. PGE would remain majority owner and sole operator.

The Agreement also provides for certain termination rights, and under certain specified circumstances, the Company may be required to pay PacifiCorp a termination fee of $35 million. The transaction is expected to consummate approximately twelve months after submission of regulatory filings, subject to customary closing conditions and regulatory approvals, including under the Hart-Scott-Rodino Act, Section 203 of the Federal Power Act from the FERC, the Washington Utilities and Transportation Commission (“WUTC”), the OPUC, the Idaho Public Utilities Commission, the Public Service Commission of Utah, the Public Utilities Commission of the State of California, the Public Service Commission of Wyoming, and certain other federal and state regulatory approvals. PGE submitted regulatory applications related to the Acquisition with the WUTC and the OPUC on March 30, 2026 and April 2, 2026, respectively. On July 15, 2026, the Company, jointly with other parties, submitted an application to the FERC seeking approval of the transaction, requesting a decision by December 15, 2026.

The transaction is expected to be accounted for as a business combination pursuant to ASC 805, Business Combinations, using the acquisition method of accounting and in which PGE would record the fair value of the assets acquired and liabilities assumed as of the acquisition date. To the extent that the consideration transferred is greater than the fair value of the net assets acquired, goodwill will be recorded.

Segment Information (Tables)

9 Months Ended

Sep. 30, 2026

Single Reporting Segment [Member]

Segment Reporting [Line Items]

Schedule of Segment Reporting Information, by Segment


	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Total revenues	$	971		$	952		$	2,664		$	2,687
Operating expenses:
Purchased power and fuel		383			372			1,040			1,034
Operating and maintenance expense:
Generation, transmission and distribution		115			112			337			336
Administrative and other		86			99			282			291
Total operating and maintenance expense		201			211			619			627
Depreciation and amortization		146			148			433			427
Taxes other than income taxes		54			47			157			139
Total operating expenses		784			778			2,249			2,227
Income from operations		187			174			415			460
Interest expense, net:
Interest expense		67			62			193			182
Allowance for borrowed funds used during construction		(5	)		(2	)		(10	)		(9	)
Total interest expense, net		62			60			183			173
Other income, net:		13			9			40			32
Income before income taxes		138			123			272			319
Income tax expense		19			20			40			54
Net income	$	119		$	103		$	232		$	265

Certain additional financial information relating to the Company’s single business segment was as follows (dollars in millions):


	September 30, 2026		December 31, 2025
Total assets	$	13,815	$	13,230
Equity method investments		22		19


	Nine Months Ended September 30,
	2026			2025
Capital expenditures		(1,085	)		(899	)

- Definition

Tabular disclosure of segment reporting. Includes, but is not limited to, reconciliation of reportable segment amount to corresponding consolidated total.

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- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

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+ Details

Revenue Recognition

9 Months Ended

Sep. 30, 2026

Revenue Recognition [Abstract]

Revenue Recognition

NOTE 2: REVENUE RECOGNITION

Disaggregated Revenue

The following table presents PGE’s revenue, disaggregated by customer type (in millions):


	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Retail:
Residential	$	362		$	375		$	1,090		$	1,115
Commercial		261			262			744			738
Industrial		177			141			472			396
Direct access customers		13			11			34			30
Subtotal		813			789			2,340			2,279
Alternative revenue programs, net of amortization		2			6			21			11
Other accrued revenues, net		(6	)		(1	)		(11	)		9
Total retail revenues		809			794			2,350			2,299
Wholesale revenues*		143			136			245			324
Other operating revenues		19			22			69			64
Total revenues	$	971		$	952		$	2,664		$	2,687

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 consist of non-residential customers who 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 and include data centers, which, with recent OPUC approval, now have a separate tariff. Demand from industrial customers is primarily driven by economic conditions, with weather having a less significant 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 (GRC) proceedings and various tariff filings with the 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 and records the revenue earned from energy deliveries that have not yet been billed to customers. This amount, which is classified as unbilled revenues and 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. PGE 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, PGE 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 PGE’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 do not appear in Revenues, net within the condensed consolidated statements of income and comprehensive income.

Alternative Revenues programs—Revenues related to PGE’s Renewable Adjustment Clause (RAC) are considered earned under alternative revenue programs, as these amounts represent contracts with the regulator and not with customers. Such revenues are presented separately from revenues from contracts with customers and classified as Alternative revenue programs, net of amortization on the condensed consolidated statements of income and comprehensive income. The activity within this line item is comprised of current period deferral adjustments, which can either be a collection from or a refund to customers, and is net of any related amortization. When amounts related to alternative revenue programs are ultimately included in prices and customer bills, the amounts are included within Revenues, net, with an equal and offsetting amount of amortization recorded on the Alternative revenue programs, net of amortization line item. Under the RAC, in 2024 and through February 28, 2025, the Company deferred amounts related to the Clearwater Wind Development (Clearwater). For further information, see “Clearwater RAC” in the Regulatory Assets and Liabilities section of Note 3, Balance Sheet Components.

Wholesale Revenues

PGE participates in the wholesale electricity marketplace in order to balance its supply of power to meet the needs of, and secure reasonably-priced power for, its retail customers, manage risk, and administer its current long-term wholesale contracts. In addition, the Company performs wholesale market services for third parties in the region and sells environmental credits in the wholesale marketplace. Interconnected transmission systems in the western United States serve utilities with diverse load requirements and allow PGE to purchase and sell electricity within the region depending upon: i) the relative price and availability of power; ii) hydro, solar, and wind conditions; and iii) daily and seasonal retail demand.

PGE’s Wholesale revenues consist primarily of 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 nets 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, excess fuel sales, utility pole attachment revenues, and other electric 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.

- Definition

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

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-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-13

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Name Accounting Standards Codification
-Topic 606
-Publisher FASB
-URI https://asc.fasb.org/606/tableOfContent

+ Details

Contingencies (Details) $ in Millions	1 Months Ended	9 Months Ended
Contingencies (Details) $ in Millions	Sep. 30, 2025 USD ($)	Sep. 30, 2026 USD ($) Party	Jun. 30, 2026 USD ($)
Loss Contingencies [Line Items]
Number of potentially responsible parties \| Party		100
Investigation-related costs		$ 115
Undiscounted estimated total cost		1,700
Long-term operation and maintenance costs		500
lower range of costs		2,900
upper range of costs		5,500
Estimated low end of share of liability		22	$ 20
EPA Investigation of Portland Harbor [Member]
Loss Contingencies [Line Items]
Remediation construction costs		1,200
Estimated low end of share of liability		$ 42
Loss from Catastrophes [Member]
Loss Contingencies [Line Items]
Remediation construction costs	$ 375

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025
Cash flows from operating activities:
Net income	$ 232	$ 265
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	433	427
Deferred income taxes	22	39
Allowance for equity funds used during construction	(17)	(15)
Alternative revenue programs	(21)	(11)
Regulatory assets	20	(6)
Regulatory liabilities	16	(21)
Tax credit sales	23	153
Other non-cash income and expenses, net	78	69
Changes in working capital:
Accounts receivable, net	10	(9)
Inventories	(3)	(10)
Margin deposits	63	66
Accounts payable and accrued liabilities	20	43
Margin deposits from wholesale counterparties	(19)	0
Other working capital items, net	20	37
Other, net	(66)	(57)
Net cash provided by operating activities	811	970
Cash flows from investing activities:
Capital expenditures	(1,085)	(899)
Sales of Nuclear decommissioning trust securities	3	4
Purchases of Nuclear decommissioning trust securities	(3)	(9)
Other, net	(18)	(12)
Net cash used in investing activities	(1,103)	(916)
Cash flows from financing activities:
Proceeds from issuance of common stock	156	49
Proceeds from Issuance of long-term debt	350	310
Payments on long-term debt	0	(102)
Dividends paid	(184)	(167)
Other	(37)	(19)
Net cash provided by financing activities	285	71
Change in cash and cash equivalents	(7)	125
Cash and cash equivalents, beginning of period	76	12
Cash and cash equivalents, end of period	69	137
Supplemental cash flow information is as follows:
Cash paid for interest, net of amounts capitalized	155	146
Cash received for income taxes, net	$ (3)	$ (137)

Fair Value of Financial Instruments Schedule of Fair Value (Details) - USD ($) $ in Millions	Sep. 30, 2026	Dec. 31, 2025
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	$ 57	$ 59
Domestic government, Debt securities	14	25
Corporate debt securities held in decommissioning trust assets	22	10
Money market funds	8	7
Debt securities - domestic government	5	1
Money market funds	1
Electricity	4	30
Natural gas	3	3
Financial Instruments, Owned, at Fair Value	15	14
Assets, Fair Value Disclosure	121	142
Liabilities from price risk management activities: [Abstract]
Electricity	41	50
Natural gas	121	164
Liabilities, Fair Value Disclosure	162	214
Portion at Other than Fair Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	7	7
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	57	59
Domestic government, Debt securities	8	14
Corporate debt securities held in decommissioning trust assets	0	0
Money market funds	0	0
Debt securities - domestic government	5	1
Money market funds	0
Electricity	0	0
Natural gas	0	0
Financial Instruments, Owned, at Fair Value	70	74
Liabilities from price risk management activities: [Abstract]
Electricity	0	0
Natural gas	0	0
Liabilities, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] \| Portion at Other than Fair Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Domestic government, Debt securities	6	11
Corporate debt securities held in decommissioning trust assets	22	10
Money market funds	0	0
Debt securities - domestic government	0	0
Money market funds	1
Electricity	3	29
Natural gas	2	3
Financial Instruments, Owned, at Fair Value	34	53
Liabilities from price risk management activities: [Abstract]
Electricity	7	13
Natural gas	111	160
Liabilities, Fair Value Disclosure	118	173
Fair Value, Inputs, Level 2 [Member] \| Portion at Other than Fair Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Domestic government, Debt securities	0	0
Corporate debt securities held in decommissioning trust assets	0	0
Money market funds	0	0
Debt securities - domestic government	0	0
Money market funds	0
Electricity	1	1
Natural gas	1	0
Financial Instruments, Owned, at Fair Value	2	1
Liabilities from price risk management activities: [Abstract]
Electricity	34	37
Natural gas	10	4
Liabilities, Fair Value Disclosure	44	41
Fair Value, Inputs, Level 3 [Member] \| Portion at Other than Fair Value Measurement
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Money market funds	0	0
Non Qualified Benefit Plans [Member]
Liabilities from price risk management activities: [Abstract]
Insurance contracts, at cash surrender value	$ 32	$ 35

Income Taxes (Details)	3 Months Ended		9 Months Ended
Income Taxes (Details)	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Income Tax Disclosure [Abstract]
Effective tax rate	13.80%	16.30%	14.70%	16.90%
Federal statutory tax rate			21.00%	21.00%

SEC Schedule, Article 12-09, Valuation and Qualifying Accounts (Policies)	9 Months Ended
	Sep. 30, 2026
SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]
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.

- Definition

Disclosure of inventory accounting policy for inventory classes, including, but not limited to, basis for determining inventory amounts, methods by which amounts are added and removed from inventory classes, loss recognition on impairment of inventories, and situations in which inventories are stated above cost.

+ References + Details

Balance Sheet Components (Details)				3 Months Ended		9 Months Ended		12 Months Ended
Balance Sheet Components (Details)	Jul. 02, 2026 USD ($)	Mar. 23, 2026 USD ($) Loans	Mar. 18, 2026 USD ($)	Sep. 30, 2026 USD ($)	Sep. 30, 2025 USD ($)	Sep. 30, 2026 USD ($)	Sep. 30, 2025 USD ($)	Dec. 31, 2025 USD ($)	Dec. 31, 2024 USD ($)	Jun. 30, 2026 USD ($)	Mar. 31, 2026 USD ($)	Feb. 15, 2026 USD ($)	Jan. 09, 2026 USD ($)
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Unbilled Receivables, Current				$ 158,000,000		$ 158,000,000		$ 180,000,000
Accounts Receivable, Allowance for Credit Loss				14,000,000		14,000,000		13,000,000		$ 14,000,000
Finite-Lived Intangible Assets, Accumulated Amortization				670,000,000		670,000,000		622,000,000
Amortization of Intangible Assets				23,000,000	$ 19,000,000	64,000,000	$ 57,000,000
Line of Credit Facility, Current Borrowing Capacity				750,000,000		750,000,000
Line of Credit Facility, Maximum Borrowing Capacity		$ 1,300,000,000		$ 850,000,000		$ 850,000,000
Debt Instrument, Covenant Description						65.00%
Percentage of authorized return on equity						9.34%
Ratio of Indebtedness to Net Capital				0.536		0.536
Commercial paper, maximum term						270 days
Short-term debt				$ 0		$ 0
Line of Credit Facility, Remaining Borrowing Capacity				750,000,000		750,000,000
Authorized Short-Term Debt				900,000,000		900,000,000
Proceeds from Issuance of long-term debt						350,000,000	310,000,000
Long term debt, face amount		$ 700,000,000
Number of loans from the Lenders \| Loans		4
Payments on long-term debt						0	$ 102,000,000
Letters of Credit Outstanding, Amount				136,000,000		136,000,000
Line of Credit, Current				320,000,000		320,000,000
Line of credit facility, amount outstanding				0		0
Regulatory assets - noncurrent				513,000,000		$ 513,000,000		619,000,000
Percentage of prudently incurred reliability contingency events cost						80.00%
Earnings test triggering basis points						0.20%
Allowed return on equity percentage on deferred storm costs						9.50%
Earnings test resulted reduction of previously deferred amounts						$ 3,000,000
Remaining percentage of flowing through operating expenses						20.00%
Regulatory assets-current				257,000,000		$ 257,000,000		168,000,000
RCE deferred								2,000,000	$ 63,000,000
RCE mechanism docket approved recovery amount in deferred costs			$ 70,000,000
RCE mechanism docket approved deferred costs shared at a level of percentage			90.00%
Reduction in deferred cost due to recovery request			$ 8,000,000
Disallowance of previously deferred costs			2,000,000
Reduction in previously deferred costs			10,000,000
Equity method investments				22,000,000		22,000,000		19,000,000
Recovery of O&M Expense						14,000,000
Capital Related Revenue Requirement						21,000,000
Deferred regulatory asset in balancing account				7,000,000		7,000,000
PPA [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Lease term, purchased power agreement												30 years	20 years
Operating Lease, Liability, Related to Power Purchase Agreements												$ 331,000,000	$ 612,000,000
PPA [Member] \| OPUC [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Lease term, purchased power agreement												20 years
Operating Lease, Liability, Related to Power Purchase Agreements												$ 636,000,000
Revolving Credit Facility and Commercial Paper Program [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Commercial paper				0		0
Clearwater RAC [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Deferred regulatory liability in balancing account				6,000,000		6,000,000
Regulatory Liabilities									$ 40,000,000
Additional net regulatory liability								13,000,000
Fire
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Regulatory assets - noncurrent				11,000,000		11,000,000		14,000,000
Regulatory assets-current				5,000,000		5,000,000		5,000,000
wildfire
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Regulatory assets - noncurrent				3,000,000		3,000,000		33,000,000
Regulatory assets-current				35,000,000		35,000,000		9,000,000
Regulatory assets				38,000,000		38,000,000		42,000,000
Wildfire Mitigation [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Operations and maintenance expense						28,000,000
Deferred regulatory asset				14,000,000		14,000,000
Deferred regulatory asset in balancing account				17,000,000		17,000,000
StormCosts - Jan 2024
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Regulatory assets - noncurrent				12,000,000		12,000,000		48,000,000
Regulatory assets-current				24,000,000		24,000,000		0
Regulatory assets				36,000,000		36,000,000					$ 44,000,000
StormCosts - RCE
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Regulatory assets - noncurrent				65,000,000		65,000,000
Storm Recovery Docket \| OPUC [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Disallowance for operating and maintenance costs			$ 1,000,000
Portland Harbor Environmental Remediation Account
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Regulatory assets - noncurrent				65,000,000		65,000,000		24,000,000
Regulatory assets-current				0		0		0
Environmental Remediation Expense						6,000,000
Deferred regulatory asset in balancing account				$ 65,000,000		$ 65,000,000
Reclassification of amounts from other net to environmental remediation								$ 24,000,000
Term Loan [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Proceeds from Issuance of long-term debt	$ 80,000,000
Long term debt, face amount		$ 350,000,000
SOFR adjustment rate of basis points applicable margin		1.10%

Shareholders' Equity

9 Months Ended

Sep. 30, 2026

Equity [Abstract]

Shareholders' Equity

NOTE 7: SHAREHOLDERS’ EQUITY

The activity in equity during the three and nine-month periods ended September 30, 2026 and 2025 was as follows (dollars in millions, except per share amounts):


	Common Stock					Accumulated Other
	Shares		Amount			Comprehensive Loss			Retained Earnings			Total
Balances as of December 31, 2025		115,559,079	$	2,382		$	(4	)	$	1,755		$	4,133
Issuances of shares pursuant to equity-based plans		169,951		—			—			—			—
Issuance costs pursuant to equity agreements		—		(1	)		—			—			(1	)
Deferred equity issuance costs		—		(8	)		—			—			(8	)
Stock-based compensation		—		13			—			—			13
Dividends declared ($0.525 per share)		—		—			—			(62	)		(62	)
Net income		—		—			—			45			45
Balances as of March 31, 2026		115,729,030		2,386			(4	)		1,738			4,120
Issuances of shares pursuant to equity-based plans		29,224		1			—			—			1
Stock-based compensation		—		(2	)		—			—			(2	)
Dividends declared ($0.55125 per share)		—		—			—			(64	)		(64	)
Net income		—		—			—			68			68
Balances as of June 30, 2026		115,758,254		2,385			(4	)		1,742			4,123
Issuances of shares pursuant to equity-based plans		31,803		—			—			—			—
Issuances of shares pursuant to equity agreements		3,117,541		152			—			—			152
Stock-based compensation		—		3			—			—			3
Other comprehensive income		—		—			1			—			1
Dividends declared ($0.5250 per share)		—		—			—			(66	)		(66	)
Net income		—		—			—			119			119
Balances as of September 30, 2026		118,907,598	$	2,540		$	(3	)	$	1,795		$	4,332


	Common Stock				Accumulated Other
	Shares		Amount		Comprehensive Loss			Retained Earnings			Total
Balances as of December 31, 2024		109,342,251	$	2,118	$	(4	)	$	1,680		$	3,794
Issuances of shares pursuant to equity-based plans		161,074		—		—			—			—
Stock-based compensation		—		5		—			—			5
Dividends declared ($0.500 per share)		—		—		—			(55	)		(55	)
Net income		—		—		—			100			100
Balances as of March 31, 2025		109,503,325		2,123		(4	)		1,725			3,844
Issuances of shares pursuant to equity-based plans		58,563		1		—			—			1
Stock-based compensation		—		3		—			—			3
Dividends declared ($0.525 per share)		—		—		—			(58	)		(58	)
Net income		—		—		—			62			62
Balances as of June 30, 2025		109,561,888		2,127		(4	)		1,729			3,852
Issuances of shares pursuant to equity-based plans		47,997		—		—			—			—
Issuances of shares pursuant to equity agreements		1,114,529		49		—			—			49
Stock-based compensation		—		3		—			—			3
Other comprehensive income		—		—		1			—			1
Dividends declared ($0.5250 per share)		—		—		—			(58	)		(58	)
Net income		—		—		—			103			103
Balances as of September 30, 2025		110,724,414	$	2,179	$	(3	)	$	1,774		$	3,950

At-the-Market Offering Program—In July 2024, PGE entered into an equity distribution agreement under which it could sell up to $400 million of its common stock through an ATM program. Pursuant to the 2024 ATM program, the Company entered into forward sale agreements for 1,420,049 shares and 5,756,432 shares in 2024 and 2025, respectively. The Company issued 1,066,549 shares and received net proceeds of $50 million in 2024, and issued 5,919,618 shares and received net proceeds of $250 million in 2025. As of September 30, 2026, the Company could have physically settled the remaining amount by delivering 190,314 shares in exchange for cash of $8 million.

On October 22, 2026, the Company issued 190,314 shares pursuant to the 2024 ATM program, settling the 2024 ATM transaction, and received net proceeds of $8 million.

In February 2026, PGE entered into an additional agreement under which it could sell up to $500 million of its common stock through the ATM program. No forward sale agreements were entered into pursuant to the 2026 ATM program as of September 30, 2026. Any proceeds from the issuances of common stock will be used for general corporate purposes and investments in renewables and non-emitting dispatchable capacity.

Equity Forward Sale Agreement—In February 2026, PGE entered into an EFSA in connection with a public offering of 9,467,455 shares of its common stock. Pursuant to the terms of the EFSA, the forward counterparties borrowed 10,848,125 shares of PGE's common stock, including 1,380,670 shares in connection with the underwriters' exercise of their option to purchase additional shares, from third parties in the open market and sold the shares to a group of underwriters for $50.70 per share, less an underwriting discount equal to $1.4576 per share. PGE will not receive any proceeds from the sale of common stock until the EFSA is settled, and at that time PGE will record the proceeds, if any, in equity. In July 2026, the Company issued 3,117,541 shares pursuant to the EFSA and received net proceeds of $152 million.

Under the terms of the EFSA, PGE may elect to settle the equity forward transactions by means of physical, cash or net share settlement, in whole or in part, at any time on or prior to February 22, 2028, except in specified circumstances or events that would require physical settlement. To the extent that the transactions are physically settled, PGE would be required to issue and deliver shares of PGE common stock to the forward counterparty at the then applicable forward sale price. The forward sale price was initially determined to be $50.70 per share at the time the EFSA was entered into, and the amount of cash to be received by PGE upon physical settlement of the EFSA is subject to certain adjustments in accordance with the terms of the EFSA.

PGE concluded that the EFSA was an equity instrument and that it qualified for an exception from derivative accounting because the EFSA was indexed to its own stock. PGE anticipates settling the EFSA through physical settlement on or before February 22, 2028.

As of September 30, 2026, the Company could have physically settled the EFSA by delivering 7,730,584 shares in exchange for cash for $375 million.

Prior to settlement, the potentially issuable shares pursuant to the ATM and EFSA agreements may be reflected in PGE’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of shares of PGE’s common stock used in calculating diluted earnings per share for a reporting period would be increased by the number of shares, if any, that would be issued upon physical settlement of the agreements less the number of shares that could be purchased by PGE in the market with the proceeds received from issuance (based on the average market price during that reporting period). Share dilution occurs when the average market price of PGE’s stock during the reporting period is higher than the average forward sale price during the reporting period. For the three and nine months ended September 30, 2026, 179,391 and 283,060 shares were included in the calculation of diluted EPS related to the securities under the agreements, respectively. For additional information concerning the Company’s diluted earnings per share, see Note 6, Earnings Per Share.

- Definition

The entire disclosure for equity.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 20
-Name Accounting Standards Codification
-Section S50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479951/505-20-S50-1

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 20
-Name Accounting Standards Codification
-Section S25
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479982/505-20-S25-1

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480008/505-10-S99-1

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section S50
-Paragraph 1
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480070/505-10-S50-1

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 3
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481112/505-10-50-3

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section S45
-Paragraph 3
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480100/505-10-S45-3

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section S45
-Paragraph 2
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480100/505-10-S45-2

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 13
-Subparagraph (g)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481112/505-10-50-13

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 20
-Name Accounting Standards Codification
-Section S50
-Paragraph 2
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479951/505-20-S50-2

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 20
-Name Accounting Standards Codification
-Section S25
-Paragraph 2
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479982/505-20-S25-2

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 4
-Subparagraph (SAB Topic 4.C)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480008/505-10-S99-4

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 505
-SubTopic 30
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
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+ Details

Risk Management (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
Risk Management (Details) - USD ($) $ in Millions	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025	Dec. 31, 2025
Derivative [Line Items]
Net gain or (loss) recognized in the statement of income offset by regulatory accounting	$ 0	$ (37)	$ 14	$ 25
Gross amounts included as price risk management liabilities	32		32		$ 41
Right to reclaim cash collateral	13		13		14
Margin deposit assets	12		12
Aggregate fair value of derivative instruments	157		157
Aggregate fair value in collateral	54		54
Aggregate fair value in cash	32		32
Aggregate fair value in letters of credit	22		22
Collateral aggregate fair value	123		123
Letters of credit	8		8
Cash	2		2		$ 21
Letters of Credit Outstanding, Amount	136		136
Derivative asset amount offset against collateral	$ 10		$ 10

Balance Sheet Components - Schedule of Other Current Assets (Details) - USD ($) $ in Millions	Sep. 30, 2026	Dec. 31, 2025
Other Current Assets [Line Items]
Prepaid expenses	$ 93	$ 96
Margin deposits	53	116
Assets from price risk management activities	4	32
Other current assets	$ 150	$ 244

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Sep. 30, 2026	Dec. 31, 2025
Current assets:
Cash and cash equivalents	$ 69	$ 76
Accounts receivable, net	442	460
Inventories	127	124
Regulatory assets-current	257	168
Other current assets	150	244
Total current assets	1,045	1,072
Electric utility plant, net	11,712	10,993
Regulatory assets-noncurrent	513	619
Nuclear decommissioning trust	44	42
Non-qualified benefit plan trust	38	36
Other noncurrent assets	463	468
Total assets	13,815	13,230
Current liabilities:
Accounts payable	310	330
Liabilities from price risk management activities-current	113	158
Current portion of finance lease obligation	27	27
Accrued expenses and other current liabilities	462	478
Total current liabilities	912	993
Long-term debt, net of current portion	5,010	4,662
Regulatory liabilities-noncurrent	1,524	1,490
Deferred income taxes	668	601
Deferred investment tax credits	187	194
Unfunded status of pension and postretirement plans	89	107
Liabilities from price risk management activities-noncurrent	49	56
Asset retirement obligations	302	299
Non-qualified benefit plan liabilities	66	70
Finance lease obligations, net of current portion	253	263
Other noncurrent liabilities	423	362
Total liabilities	9,483	9,097
Commitments and contingencies (see notes)
Shareholders' Equity:
Preferred stock, no par value, 30,000,000 shares authorized; none issued and outstanding as of September 30, 2026 and December 31, 2025	0	0
Common stock, no par value, 160,000,000 shares authorized; 118,907,598 and 115,559,079 shares issued and outstanding as of September 30, 2026 and December 31, 2025, respectively	2,540	2,382
Accumulated other comprehensive loss	(3)	(4)
Retained earnings	1,795	1,755
Total shareholders' equity	4,332	4,133
Total liabilities and shareholders' equity	$ 13,815	$ 13,230

Balance Sheet Components - Schedule of Other Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Millions	Sep. 30, 2026	Dec. 31, 2025
Accrued employee compensation and benefits	$ 65	$ 87
Accrued taxes payable	67	38
Accrued interest payable	55	53
Accrued dividends payable	69	63
Regulatory liabilities - current	65	73
Margin deposits from wholesale counterparties	2	21
Other	139	143
Total accrued expenses and other current liabilities	$ 462	$ 478

- Definition

Amount of obligation to return cash collateral under master netting arrangements that have not been offset against derivative assets.

+ References + Details

Balance Sheet Components Pension and Other Postretirement Benefits (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 3	$ 2	$ 7	$ 7
Interest cost	8	8	24	24
Expected return on plan assets	(10)	(9)	(28)	(27)
Net periodic benefit cost	$ 1	$ 1	$ 3	$ 4

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

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+ Details

Earnings Per Share - Schedule of Earnings Per Share, Basic and Diluted (Details) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Earnings Per Share [Abstract]
Weighted Average Number of Shares Outstanding, Basic	118,199	110,170	116,534	109,708
Dilutive effect of potential common shares	472	246	551	250
Weighted Average Number of Shares Outstanding, Diluted	118,671	110,416	117,085	109,958

Insider Trading Arrangements

3 Months Ended

Sep. 30, 2026

Trading Arrangements, by Individual

Material Terms of Trading Arrangement

Rule 10b5-1 Trading Arrangements

During the three months ended September 30, 2026, the following directors (as defined in Rule 16a-1(f) of the Exchange Act) adopted a “Rule 10b5-1 trading agreement,” as the term is defined in Item 408(c) of Regulation S-K:


Name (Title)	Action Taken (Date of Action)	Type of Trading Arrangement	Duration of Trading Arrangement	Aggregate Number of Securities to be Purchased or Sold
Benjamin F. Felton (Executive Vice President Chief Operating Officer)	Adoption (August 5, 2026)	Rule 10b5-1 trading arrangement	Until August 5, 2027, or such earlier date upon which all transactions are completed or expire without execution	Up to 37,306 shares of common stock

Name

Benjamin F. Felton

Title

Executive Vice President Chief Operating Officer

Rule 10b5-1 Arrangement Adopted

true

Adoption Date

August 5, 2026

Expiration Date

August 5, 2027

Aggregate Available

37,306

Risk Management - Schedule of PGE's Assets and Liabilities from Price Risk Management Activities (Details) - USD ($) $ in Millions	Sep. 30, 2026	Dec. 31, 2025
Current Assets, Commodity Contracts:
Electricity	$ 3	$ 29
Natural gas	1	3
Total current derivative assets	4	32
Noncurrent Assets, Commodity Contracts: [Abstract]
Electricity	1	1
Natural Gas	2	0
Total noncurrent derivative assets	3	1
Total derivative assets	7	33
Current Liabilities, Commodity Contracts: [Abstract]
Electricity	12	19
Natural gas	101	139
Total current derivative liabilities	113	158
Noncurrent Liabilities, Commodity Contracts: [Abstract]
Electricity	29	31
Natural gas	20	25
Total noncurrent derivative liabilities	49	56
Total derivative liabilities	$ 162	$ 214

Balance Sheet Components - Schedule of Electric Utility Plant, Net (Details) - USD ($) $ in Millions	Sep. 30, 2026	Dec. 31, 2025
Property, Plant and Equipment [Line Items]
Electric utility plant in-service	$ 16,469	$ 15,996
Construction work-in-progress	954	416
Total cost	17,423	16,412
Less: accumulated depreciation and amortization	(5,711)	(5,419)
Electric utility plant, net	$ 11,712	$ 10,993

- Definition

Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table.

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+ Details

Cover Page - shares	9 Months Ended
Cover Page - shares	Sep. 30, 2026	Oct. 22, 2026
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2026
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
Title of 12(b) Security	Common Stock, no par value
Trading Symbol	POR
Security Exchange Name	NYSE
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		119,102,096
Entity Central Index Key	0000784977
Amendment Flag	false
Document Fiscal Year Focus	2026
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31

Balance Sheet Components

9 Months Ended

Sep. 30, 2026

Balance Sheet Components [Abstract]

Balance Sheet Components

NOTE 3: BALANCE SHEET COMPONENTS

Accounts Receivable, Net

Accounts receivable, net includes $158 million and $180 million of unbilled revenues as of September 30, 2026 and December 31, 2025, respectively. Accounts receivable, net includes an allowance for uncollectible accounts. The following summarizes activity during 2026 in the allowance for credit losses (in millions):


	Three Months Ended September 30,			Nine Months Ended September 30,
Balance as of beginning of period	$	14		$	13
Increase in provision		3			9
Amounts written off		(5	)		(14	)
Recoveries		2			6
Balance as of end of period	$	14		$	14

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.

Other Current Assets

Other current assets consist of the following (in millions):


	September 30, 2026		December 31, 2025
Prepaid expenses	$	93	$	96
Margin deposits		53		116
Assets from price risk management activities		4		32
Other current assets	$	150	$	244

Electric Utility Plant, Net

Electric utility plant, net consists of the following (in millions):


	September 30, 2026			December 31, 2025
Electric utility plant in-service	$	16,469		$	15,996
Construction work-in-progress		954			416
Total cost		17,423			16,412
Less: accumulated depreciation and amortization		(5,711	)		(5,419	)
Electric utility plant, net	$	11,712		$	10,993

Accumulated depreciation and amortization in the table above includes accumulated amortization related to intangible assets of $670 million and $622 million as of September 30, 2026 and December 31, 2025, respectively. Amortization expense related to intangible assets was $23 million and $19 million for the three months ended September 30, 2026 and 2025, respectively, and $64 million and $57 million for the nine months ended September 30, 2026 and 2025, respectively. The Company’s intangible assets primarily consist of computer software development and hydro licensing costs.

Battery storage agreements—PGE has entered into three battery storage PPAs that are expected to be accounted for as leases upon commencement. These projects are summarized as follows:

•

on January 9, 2026 PGE entered into an agreement with an expected lease commencement date in December 2027 and a term of 20 years. The expected total fixed contract consideration will approximate $612 million over the lease term;

•

on February 15, 2026, PGE entered into an agreement with an expected lease commencement date in December 2027 and a term of 30 years. The expected total fixed contract consideration will approximate $331 million over the lease term; and

•

on February 15, 2026, PGE entered into an agreement with an expected lease commencement date in June 2028 and a term of 20 years. The expected total fixed contract consideration will approximate $636 million over the lease term.

Regulatory Assets and Liabilities

Regulatory assets and liabilities consist of the following (in millions):


	September 30, 2026					December 31, 2025
	Current			Noncurrent		Current			Noncurrent
Regulatory assets:
Price risk management	$	109		$	46	$	127		$	54
Pension and other postretirement plans		—			64		—			64
Trojan decommissioning activities		—			168		—			161
February 2021 ice storm and damage		12			27		13			33
January 2024 storm and damage		24			12		—			48
Reliability contingency events		43			22		—			90
2020 Labor Day wildfire		5			11		5			14
Wildfire mitigation		35			3		9			33
Portland Harbor environmental remediation account		—			65		—			24
Other		29			95		14			98
Total regulatory assets	$	257		$	513	$	168		$	619
Regulatory liabilities:
Asset retirement removal costs	$	—		$	1,279	$	—		$	1,245
Deferred income taxes		—			215		—			228
Clearwater RAC		6			—		21			1
Other		59			30		53			16
Total regulatory liabilities	$	65	*	$	1,524	$	74	*	$	1,490

* Included in Accrued expenses and other current liabilities in the condensed consolidated balance sheets.

January 2024 storm and damage—Beginning January 13, 2024, the Company’s service territory encountered a severe winter weather event that included snow, ice, and high winds over several days that caused catastrophic damage to physical assets and resulted in widespread customer power outages. As a result of the historic winter storm, Oregon’s Governor declared a state of emergency on January 18, 2024, which allows PGE to seek recovery of incremental storm expenses through the OPUC pre-authorized emergency deferral mechanism, subject to the application of an earnings test. On February 9, 2024, PGE filed a Notice of Deferral with the OPUC, under Docket UM 2190, related to the emergency restoration costs for the January storm. On March 18, 2026, PGE received the OPUC's final order for the storm recovery docket which included a disallowance for some operating and maintenance costs of $1 million and application of an earnings test. The OPUC ordered the application of an earnings test at 20 basis points below the Company's 2024 allowed return on equity of 9.5% on the deferred storm costs. The application of the earnings test resulted in an additional $3 million reduction of the previously deferred amounts. After application of adjustments per the final order, PGE’s deferred balance as of March 31, 2026 was $44 million, including interest, which began amortizing on April 1, 2026 over a two year period. The deferred balance as of September 30, 2026 was $36 million.

Reliability contingency events—As approved by the OPUC in PGE’s 2024 GRC, the Reliability Contingency Event (RCE) mechanism allows PGE to defer and recover 80% of prudent costs for RCEs above amounts forecasted in the Company’s Annual Power Cost Update Tariff, without application of an earnings test, with the remaining 20% flowing through operating expenses and subject to the existing power cost adjustment mechanism (PCAM). Results of the PCAM are filed annually with the OPUC no later than July 1, initiating a regulatory review process that typically results in a final determination and order from the OPUC by the end of the year of filing, with any resulting refund or collection impacting customer prices effective in the following year. RCE costs incurred and deferred are included in each years' respective PCAM filing. On March 18, 2026, the OPUC issued its final order in the 2024 RCE mechanism docket which resulted in the approval for recovery of $70 million in deferred costs, before consideration of interest, after determining that costs should be shared at a level of 90%, resulting in a reduction of $8 million to the recovery request. In addition, the OPUC

disagreed with PGE's method of estimating the impacts related to wind generating resources in the day ahead forecasts of $2 million, resulting in a total reduction of $10 million in previously deferred costs. The OPUC also declined to extend the sunset date for the RCE mechanism. After application of adjustments per the final order, PGE’s deferred balance as of September 30, 2026, related to RCEs was $65 million, which included $63 million related to RCEs deferred in 2024 and $2 million related to RCEs deferred in 2025. The 2024 deferred balance began amortizing into customer prices on April 1, 2026 and is to be collected over a two-year period. On July 1, 2026, under the Company's PCAM, Advice 26-26 was submitted to the OPUC seeking recovery to begin on April 1, 2027 of $2 million in costs deferred during RCEs in 2025. The 2025 PCAM docket was settled as filed in September 2026 and the final order is expected in the fourth quarter of 2026.

Wildfire Mitigation—Wildfire Mitigation represents incremental costs and investments made by PGE related to efforts on its system to mitigate the risk of wildfire and improve resiliency to wildfire damage under Oregon Senate Bill 762, enacted in 2021. These efforts include enhanced tree and brush clearing, hardening and undergrounding equipment, and making emergency plans in close partnership with various land and emergency management agencies to further expand the use of a public safety power shutoff, when the risk warrants. On June 25, 2026 PGE's 2026-2028 risk-based Wildfire Mitigation Plan was approved by the OPUC. The plan includes annual updates as part of the ongoing regulatory process.

As of September 30, 2026 and December 31, 2025, PGE’s deferred balance related to incremental wildfire mitigation operating expenses was $38 million and $42 million, respectively. The 2026 balance is comprised of:

•

2024 Automatic Adjustment Clause (AAC)—As of September 30, 2026, there was $14 million deferred as a regulatory asset in the balancing account related to 2024. On March 18, 2026, PGE received approval to recover this remaining O&M expense beginning May 1, 2026 with a twelve-month amortization period.

•

2025 AAC— As of September 30, 2026, there was $7 million deferred as a regulatory asset in the balancing account related to 2025. On May 26, 2026, PGE received approval to recover this remaining O&M expense beginning June 1, 2026 with a twelve-month amortization period.

•

2026 AAC—In conjunction with PGE’s filed 2026-2028 Wildfire Mitigation Plan, PGE submitted an advice filing for the first phase of 2026 with the intent of recovering $28 million related to O&M, which was approved and effective on April 1, 2026 with a twelve-month amortization period. On October 13, 2026, PGE received an OPUC order approving the second phase, effective October 15, 2026, with a 12-month amortization period. The order authorizes recovery of an additional $14 million of 2026 O&M expense, while bringing the total capital-related revenue requirement to $21 million. Although the OPUC has not approved all of PGE’s 2026 wildfire mitigation O&M, PGE does not believe it is precluded from deferring such costs. Any differences between actual expense and customer collections will be recorded as regulatory assets or liabilities within the AAC balancing account, which will be subject to a prudence review, but will not be subject to an earnings test. As of September 30, 2026, there was $17 million deferred as a regulatory asset in the balancing account related to 2026. The OPUC has significant discretion in making the final determination of recovery. The OPUC’s conclusion of overall prudence could result in a portion, or all, of PGE’s deferrals being disallowed for recovery. Such disallowance would be recognized as a charge to earnings.

Portland Harbor Environmental Remediation Account—The impact of costs related to EPA liabilities on the Company’s results of operations is mitigated by the Portland Harbor Environmental Remediation Account (PHERA) mechanism. As approved by the OPUC, the PHERA allows the Company to defer estimated liabilities and recover prudently incurred environmental expenditures related to Portland Harbor through a combination of third-party proceeds, including but not limited to 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 GRC. 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 the EPA’s determination of liability for Portland Harbor through application of the PHERA. For more information on the

determination of PGE's share of liability, see "EPA Investigation of Portland Harbor" in Note 8, Contingencies. At this time, PGE is not collecting any Portland Harbor cost from the PHERA through customer prices. As of September 30, 2026, there was $65 million of eligible costs deferred as a regulatory asset. To conform with current year presentation, the Company has reclassified $24 million as of December 31, 2025 from Other to Portland Harbor environmental remediation account in the Regulatory assets section of the table above.

Clearwater RAC—The Clearwater RAC represents all costs and benefits associated with Clearwater. Under the RAC, during 2023, the Company submitted a filing for Clearwater proposing to defer the revenue requirement, net of net variable power cost (NVPC) benefits, from the in-service date of January 2024 until Clearwater was reflected in customer prices, which was March 1, 2025. For the year ended December 31, 2024, PGE deferred the revenue requirement, net of NVPC benefits resulting in a net regulatory liability of $40 million, which amortized as a refund to customers over a twelve-month period beginning on March 1, 2025 as approved in OPUC Order 25-075 issued February 21, 2025. For the period of January 1, 2025 through December 31, 2025, PGE deferred an additional net $13 million regulatory liability, which was approved and began amortizing on April 1, 2026 over a twelve-month period. As of September 30, 2026, there was $6 million deferred as a regulatory liability in the balancing account.

Revenue Subject to Refund—Revenue collected under the Seaside Battery Energy Storage System (BESS) and Distribution System Plan (DSP) Alternative Recovery Mechanisms are subject to earnings tests that require amounts earned in excess of PGE's authorized return on equity of 9.34% to be refunded to customers. The Company has contested the applicability of an earnings test, which would be for the twelve-month period ended October 31, 2026 for the Seaside BESS and the twelve-month period ended March 31, 2027 for the DSP recovery mechanism. As of September 30, 2026, no amounts have been accrued for refund under the Seaside BESS, as PGE does not forecast to over earn for the period covered by the test. Additionally, the Company has not accrued any probable and reasonably estimable refunds for the DSP recovery mechanism. Such refunds would be recognized as a charge to earnings.

Other Investments

PGE has investments in non-marketable equity securities for which the Company does not have controlling financial interest however, based on PGE’s ownership interest, are accounted for under the equity method of accounting. These investments are accounted for at cost, adjusted for the Company’s proportionate share of the investee’s earnings or losses, distributions received, and impairments, if any.

As of September 30, 2026 and December 31, 2025, equity method investments were $22 million and $19 million, respectively, recorded in Other noncurrent assets on the Company’s condensed consolidated balance sheets. For the three and nine months ended September 30, 2026, and 2025, the Company's share of net earnings or losses from equity method investments were immaterial. PGE’s share of earnings or losses are recorded as Miscellaneous income, net within Other income, net on the Company’s condensed consolidated statements of income.

Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities consist of the following (in millions):


	September 30, 2026		December 31, 2025
Accrued employee compensation and benefits	$	65	$	87
Accrued taxes payable		67		38
Accrued interest payable		55		53
Accrued dividends payable		69		63
Regulatory liabilities—current		65		73
Margin deposits from wholesale counterparties		2		21
Other		139		143
Total accrued expenses and other current liabilities	$	462	$	478

Credit Facilities

On September 10, 2025, PGE entered into an amendment of its existing revolving credit facility that extended the scheduled expiration into September 2030. As of September 30, 2026, PGE had a $750 million revolving credit facility that provides the Company the ability to expand to $850 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, 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 September 30, 2026, PGE was in compliance with this covenant with a 53.6% debt-to-total capital ratio.

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 in order to allow for coverage of any potential need to repay commercial paper that may be outstanding at the time. As of September 30, 2026, PGE had no commercial paper outstanding.

Under the revolving credit facility and commercial paper program, as of September 30, 2026, PGE had no borrowings outstanding and there were no letters of credit issued. As a result, the aggregate unused available credit capacity under the revolving credit facility was $750 million.

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 $320 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 $136 million were outstanding as of September 30, 2026. Letters of credit issued are not reflected on the Company’s condensed consolidated balance sheets.

Pursuant to an order issued by the FERC, the Company is authorized to issue short-term debt in an aggregate amount of up to $900 million through February 6, 2028.

Long-term Debt

On March 23, 2026, PGE entered into a 24-month credit agreement with lenders in the aggregate principal amount of $350 million. PGE drew four loans from the Lenders in the aggregate principal amount of $350 million. The final loan, in the amount of $80 million, occurred on July 2, 2026. The loans bear interest for the relevant interest period at the Term Secured Overnight Financing Rate (SOFR) plus an Applicable Margin of 110.0 basis points.

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 September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Service cost	$	3		$	2		$	7		$	7
Interest cost*		8			8			24			24
Expected return on plan assets*		(10	)		(9	)		(28	)		(27	)
Net periodic benefit cost	$	1		$	1		$	3		$	4

* The net expense portion of non-service cost components are included in Miscellaneous income, net within Other income on the Company’s condensed consolidated statements of income and comprehensive income.

Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2026

Fair Value of Financial Instruments [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

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 September 30, 2026
	Level 1		Level 2		Level 3		Other (2)		Total
Assets:
Cash equivalents	$	57	$	—	$	—	$	—	$	57
Nuclear decommissioning trust: (1)
Debt securities:
Domestic government		8		6		—		—		14
Corporate credit		—		22		—		—		22
Money market funds		—		—		—		8		8
Non-qualified benefit plan trust: (3)
Debt securities—domestic government		5		—		—		—		5
Money market funds		—		1		—				1
Paid Leave Oregon Trust
Money market funds		—		—		—		7		7
Price risk management activities: (1) (4)
Electricity		—		3		1		—		4
Natural gas		—		2		1		—		3
	$	70	$	34	$	2	$	15	$	121
Liabilities:
Price risk management activities: (1) (4)
Electricity	$	—	$	7	$	34	$	—	$	41
Natural gas		—		111		10		—		121
	$	—	$	118	$	44	$	—	$	162

(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 $32 million, which are recorded at cash surrender value.

(4) For further information, see Note 5, Risk Management.


	As of December 31, 2025
	Level 1		Level 2		Level 3		Other (2)		Total
Assets:
Cash equivalents	$	59	$	—	$	—	$	—	$	59
Nuclear decommissioning trust: (1)
Debt securities:
Domestic government		14		11		—		—		25
Corporate credit		—		10		—		—		10
Money market funds		—		—		—		7		7
Non-qualified benefit plan trust: (3)
Debt securities—domestic government		1		—		—		—		1
Paid Leave Oregon Trust:
Money market funds		—		—		—		7		7
Price risk management activities: (1) (4)
Electricity		—		29		1		—		30
Natural gas		—		3		—		—		3
	$	74	$	53	$	1	$	14	$	142
Liabilities:
Price risk management activities: (1) (4)
Electricity	$	—	$	13	$	37	$	—	$	50
Natural gas		—		160		4		—		164
	$	—	$	173	$	41	$	—	$	214

(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.

Schedule of Quantitative Information Regarding the Significant Unobservable Inputs Used in Measurement of Level 3 Assets and Liabilities from Price Risk Management Activities

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						Price per Unit
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
	(in millions)
As of September 30, 2026
Electricity physical forwards	$	—	$	34	Discounted cash flow	Electricity forward price (per megawatt hour (MWh))	$	24.78	$	93.51	$	57.26
Natural gas financial swaps		1		10	Discounted cash flow	Natural gas forward price (per Decatherm)		1.60		3.61		2.08
Electricity financial futures		1		—	Discounted cash flow	Electricity forward price (per MWh)		27.00		88.00		63.76
	$	2	$	44
As of December 31, 2025
Electricity physical forwards	$	—	$	37	Discounted cash flow	Electricity forward price (per MWh)	$	22.99	$	94.65	$	59.28
Natural gas financial swaps		—		4	Discounted cash flow	Natural gas forward price (per Decatherm)		1.67		2.76		2.15
Electricity financial futures		1		—	Discounted cash flow	Electricity forward price (per MWh)		31.00		84.00		52.13
	$	1	$	41

Schedule of Changes in Fair Value of Net Liabilities from Price Risk Management Activities

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 September 30,						Nine Months Ended September 30,
	2026			2025			2026		2025
Balance as of the beginning of the period	$	49		$	31		$	40	$	34
Net realized and unrealized losses/(gains)*		(6	)		(1	)		2		3
Transfers from Level 3 to Level 2		(1	)		5			—		(2	)
Balance as of the end of the period	$	42		$	35		$	42	$	35

* Both realized and unrealized losses/(gains), of which the unrealized portions 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. Amounts include $2 million in net realized gains for the three-month period ended September 30, 2026 and none for the same period in 2025. For the nine months ended September 30, 2026 and 2025, amounts include $6 million and $4 million in net realized gains, respectively.

- Definition

Tabular disclosure of the fair value measurement of assets using significant unobservable inputs (Level 3), a reconciliation of the beginning and ending balances, separately presenting changes during the period attributable to the following: (1) total gains or losses for the period (realized and unrealized), segregating those gains or losses included in earnings (or changes in net assets) and gains or losses recognized in other comprehensive income (loss), and a description of where those gains or losses included in earnings (or changes in net assets) are reported in the statement of income (or activities); (2) purchases, sales, issues, and settlements (each type disclosed separately); and (3) transfers in and transfers out of Level 3 (for example, transfers due to changes in the observability of significant inputs), by class of asset.

+ References + Details

Guarantees

9 Months Ended

Sep. 30, 2026

Guarantees [Abstract]

Guarantees

NOTE 9: GUARANTEES

PGE 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 September 30, 2026, 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.

- Definition

The entire disclosure for each guarantee obligation, or each group of similar guarantee obligations, including (a) the nature of the guarantee, including its term, how it arose, and the events or circumstances that would require the guarantor to perform under the guarantee; (b) the maximum potential amount of future payments (undiscounted) the guarantor could be required to make under the guarantee; (c) the current carrying amount of the liability, if any, for the guarantor's obligations under the guarantee; and (d) the nature of any recourse provisions under the guarantee, and any assets held either as collateral or by third parties, and any relevant related party disclosure. Excludes disclosures about product warranties.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 942
-SubTopic 235
-Name Accounting Standards Codification
-Section S99
-Paragraph 2
-Subparagraph (SX 210.9-06)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147477314/942-235-S99-2

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S50
-Paragraph 4
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480738/235-10-S50-4

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 3
-Subparagraph (SX 210.12-04(a))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480678/235-10-S99-3

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Subparagraph (a)(4)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482425/460-10-50-4

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Subparagraph (a)(5)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482425/460-10-50-4

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482425/460-10-50-4

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482425/460-10-50-4

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Subparagraph (a)(2)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482425/460-10-50-4

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Subparagraph (a)(3)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482425/460-10-50-4

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-Name Accounting Standards Codification
-Publisher FASB
-URI https://asc.fasb.org/460/tableOfContent

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 460
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 4
-Subparagraph (b)(3)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482425/460-10-50-4

+ Details

Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2026

Fair Value of Financial Instruments Note [Abstract]

Fair Value of FInancial Instruments

NOTE 4: FAIR VALUE OF FINANCIAL INSTRUMENTS

PGE estimated the fair value of financial asset and liability instruments as of September 30, 2026 and December 31, 2025, 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, 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.


	As of September 30, 2026
	Level 1		Level 2		Level 3		Other (2)		Total
Assets:
Cash equivalents	$	57	$	—	$	—	$	—	$	57
Nuclear decommissioning trust: (1)
Debt securities:
Domestic government		8		6		—		—		14
Corporate credit		—		22		—		—		22
Money market funds		—		—		—		8		8
Non-qualified benefit plan trust: (3)
Debt securities—domestic government		5		—		—		—		5
Money market funds		—		1		—				1
Paid Leave Oregon Trust
Money market funds		—		—		—		7		7
Price risk management activities: (1) (4)
Electricity		—		3		1		—		4
Natural gas		—		2		1		—		3
	$	70	$	34	$	2	$	15	$	121
Liabilities:
Price risk management activities: (1) (4)
Electricity	$	—	$	7	$	34	$	—	$	41
Natural gas		—		111		10		—		121
	$	—	$	118	$	44	$	—	$	162

(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 $32 million, which are recorded at cash surrender value.

(4) For further information, see Note 5, Risk Management.


	As of December 31, 2025
	Level 1		Level 2		Level 3		Other (2)		Total
Assets:
Cash equivalents	$	59	$	—	$	—	$	—	$	59
Nuclear decommissioning trust: (1)
Debt securities:
Domestic government		14		11		—		—		25
Corporate credit		—		10		—		—		10
Money market funds		—		—		—		7		7
Non-qualified benefit plan trust: (3)
Debt securities—domestic government		1		—		—		—		1
Paid Leave Oregon Trust:
Money market funds		—		—		—		7		7
Price risk management activities: (1) (4)
Electricity		—		29		1		—		30
Natural gas		—		3		—		—		3
	$	74	$	53	$	1	$	14	$	142
Liabilities:
Price risk management activities: (1) (4)
Electricity	$	—	$	13	$	37	$	—	$	50
Natural gas		—		160		4		—		164
	$	—	$	173	$	41	$	—	$	214

(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.

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 NAV 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 NAV. 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), Non-qualified benefit plan (NQBP) trust, and Paid Leave Oregon trust 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.

Money market funds—PGE invests in money market funds that seek to maintain a stable NAV. 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 NAV. Redemption is permitted daily without written notice.

The NQBP trust is invested in a money market fund that is invested in domestic debt securities such as government debt securities, corporate securities and municipal debt and is classified as Level 2 in the fair value hierarchy due to the availability of the underlying assets being 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 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 longer-term commodity forwards, futures, swaps, and options for which fair value is derived using one or more significant inputs that are not observable for the entire term of the instrument, such as tenor of observable market quotes.

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						Price per Unit
Commodity Contracts	Assets		Liabilities		Valuation Technique	Significant Unobservable Input	Low		High		Weighted Average
	(in millions)
As of September 30, 2026
Electricity physical forwards	$	—	$	34	Discounted cash flow	Electricity forward price (per megawatt hour (MWh))	$	24.78	$	93.51	$	57.26
Natural gas financial swaps		1		10	Discounted cash flow	Natural gas forward price (per Decatherm)		1.60		3.61		2.08
Electricity financial futures		1		—	Discounted cash flow	Electricity forward price (per MWh)		27.00		88.00		63.76
	$	2	$	44
As of December 31, 2025
Electricity physical forwards	$	—	$	37	Discounted cash flow	Electricity forward price (per MWh)	$	22.99	$	94.65	$	59.28
Natural gas financial swaps		—		4	Discounted cash flow	Natural gas forward price (per Decatherm)		1.67		2.76		2.15
Electricity financial futures		1		—	Discounted cash flow	Electricity forward price (per MWh)		31.00		84.00		52.13
	$	1	$	41

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)


	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026		2025
Balance as of the beginning of the period	$	49		$	31		$	40	$	34
Net realized and unrealized losses/(gains)*		(6	)		(1	)		2		3
Transfers from Level 3 to Level 2		(1	)		5			—		(2	)
Balance as of the end of the period	$	42		$	35		$	42	$	35

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 Long-term debt is classified as a Level 2 fair value measurement.

As of September 30, 2026, the carrying amount of PGE’s long-term debt was $5,010 million, net of $19 million of unamortized debt expense, and its estimated aggregate fair value was $4,354 million. As of December 31, 2025, the carrying amount of PGE’s long-term debt was $4,662 million, net of $17 million of unamortized debt expense, and its estimated aggregate fair value was $4,311 million.

- Definition

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
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-Name Accounting Standards Codification
-Section 50
-Paragraph 2
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Reference 2: http://www.xbrl.org/2003/role/exampleRef
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Reference 3: http://www.xbrl.org/2003/role/exampleRef
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-URI https://asc.fasb.org/1943274/2147482078/820-10-55-100

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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-URI https://asc.fasb.org/1943274/2147482106/820-10-50-2

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-Topic 820
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-Section 50
-Paragraph 6A
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-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482106/820-10-50-6A

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
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-URI https://asc.fasb.org/1943274/2147482106/820-10-50-2E

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-Topic 820
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 6A
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
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-Name Accounting Standards Codification
-Section 50
-Paragraph 6A
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
-SubTopic 10
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-Section 50
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-Subparagraph (e)
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-URI https://asc.fasb.org/1943274/2147482106/820-10-50-6A

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
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-Name Accounting Standards Codification
-Section 50
-Paragraph 6A
-Subparagraph (d)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482106/820-10-50-6A

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (h)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482106/820-10-50-2

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Topic 820
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (g)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482106/820-10-50-2

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 940
-SubTopic 820
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147478119/940-820-50-1

+ Details

Earnings Per Share

9 Months Ended

Sep. 30, 2026

Earnings Per Share [Abstract]

Earnings Per Share

NOTE 6: 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; ii) contingently issuable time-based and performance-based restricted stock units, along with associated dividend equivalent rights; and iii) shares issuable pursuant to the equity forward sale agreement (EFSA) and at-the-market offering (ATM) programs. See Note 7, Shareholders’ Equity, for additional information on the EFSA and ATM programs and the resulting impact on earnings per share. 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. Anti-dilutive stock awards are excluded from the calculation of diluted earnings per common share.

For the three and nine months ended September 30, 2026, unvested performance-based restricted stock units and related dividend equivalent rights of 652 thousand shares were excluded from the dilutive calculation because the performance goals had not been met, with 640 thousand shares excluded for the three and nine months ended September 30, 2025.

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 September 30,				Nine Months Ended September 30,
	2026		2025		2026		2025
Weighted-average common shares outstanding—basic		118,199		110,170		116,534		109,708
Dilutive effect of potential common shares		472		246		551		250
Weighted-average common shares outstanding—diluted		118,671		110,416		117,085		109,958

Basis of Presentation (Policies)	9 Months Ended
Basis of Presentation (Policies)	Sep. 30, 2026
Basis of Presentation [Abstract]
Condensed Consolidated Financial Statements	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 nine months ended September 30, 2026 and 2025 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 a normal recurring nature, unless otherwise noted. The financial information as of December 31, 2025 is derived from the Company’s audited consolidated financial statements and notes thereto for the year ended December 31, 2025, included in Item 8 of PGE’s Annual Report on Form 10-K, filed with the SEC on February 17, 2026, which should be read in conjunction with the interim unaudited Financial Statements.
Comprehensive Income	Comprehensive Income No material change occurred in Other comprehensive income in the three and nine months ended September 30, 2026 and 2025.
Miscellaneous Income, Net	Miscellaneous Income, Net Miscellaneous income, net includes $3 million in interest income from regulatory assets for both of the three months ended September 30, 2026 and 2025. The remaining activity is comprised of $1 million and $2 million in realized and unrealized gains on the non-qualified benefit plan (NQBP) trust assets and $1 million and an immaterial amount in other miscellaneous income in 2026 and 2025, respectively. For the nine months ended September 30, 2026 and 2025, respectively, Miscellaneous income, net includes $15 million and $12 million in interest income from regulatory assets and $7 million and $5 million in realized and unrealized gains on the NQBP trust assets. The remaining activity is comprised of $1 million and an immaterial amount in other miscellaneous income in 2026 and 2025, respectively.
Use of Estimates	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. Certain costs are estimated for the full year and allocated to interim periods based on estimates of operating time expired, benefit received, or activity associated with the interim period; accordingly, such costs may not be reflective of amounts to be recognized for a full year. Due to seasonal fluctuations in electricity sales, as well as the price of wholesale electricity and natural gas, interim financial results do not necessarily represent those to be expected for the year.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In November 2024, the FASB issued Accounting Standards Update (ASU) 2024-03 Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses. ASU 2024-03 requires additional disclosure, in the notes to financial statements, of specified information about certain costs and expenses. For calendar year-end entities, the update will be effective for annual periods beginning on January 1, 2027, and interim reporting periods beginning on January 1, 2028. Early adoption is permitted. PGE is assessing the impact of adoption on the consolidated financial statements and does not plan to early adopt the standard. In December 2025, the FASB issued ASU 2025-10 Government Grants (Topic 832): Accounting for Government Grants Received by Business Entities. ASU 2025-10 adds guidance to Accounting Standards Codification (ASC) 832 on the recognition, measurement, and presentation of government grants. For calendar year-end entities, the update will be effective for annual periods beginning on January 1, 2029. Early adoption is permitted. PGE is assessing the impact of adoption on the consolidated financial statements and does not plan to early adopt the standard. In May 2026, the FASB issued ASU 2026-02 Environmental Credits and Environmental Credit Obligations (Topic 818). ASU 2026-02 provides specific guidance for accounting for environmental credits and environmental credit obligations. For calendar year-end entities, the update will be effective for annual periods beginning on January 1, 2028. Early adoption is permitted. PGE is assessing the impact of adoption on the consolidated financial statements and does not plan to early adopt the standard.
Pending Acquisition	Pending Acquisition On February 15, 2026, PGE, through a newly formed, wholly owned subsidiary, entered into an Asset Purchase and Service Area Transfer Agreement (the “Agreement”) with PacifiCorp, an indirect subsidiary of Berkshire Hathaway Energy Company, to acquire select portions of PacifiCorp’s Washington state regulated utility retail business. Under the Agreement, PGE would acquire certain assets and liabilities related to generation, transmission, and distribution business to serve the related service area comprised of approximately 140,000 customers. The stated purchase price is $1.9 billion in cash, subject to customary adjustments, including adjustments for net working capital, regulatory assets and liabilities, assumed liabilities, and capital expenditures at closing. Upon execution of the Agreement, the acquisition was supported by a fully committed bridge facility with Barclays Bank PLC and JPMorgan Chase Bank, N.A. for $1.9 billion. On March 23, 2026, the bridge facility was amended to an amount of approximately $1.3 billion and at the same time, the Company entered into a 364-day Delay Draw Term Loan in the amount of approximately $700 million. Borrowings under the Delayed Draw Term Loan bear interest at a rate equal to either (i) Term SOFR Rate, or (ii) the Alternate Base Rate in each case, plus an applicable margin determined by reference to the Company’s long-term debt securities credit ratings. The Company expects to permanently finance the transaction through a balanced mix of debt, equity, and its minority investment partner, Manulife Infrastructure Fund III L.P. and its affiliates including John Hancock Life Insurance Company (USA) (“Manulife”). In connection with the financing plan, PGE expects equity commitments from Manulife to finance up to $600 million of the purchase. Assuming the closing of the transactions contemplated by the Agreement and the consummation of the financing transactions, Manulife will be the Company's joint venture partner in the business. PGE would remain majority owner and sole operator. The Agreement also provides for certain termination rights, and under certain specified circumstances, the Company may be required to pay PacifiCorp a termination fee of $35 million. The transaction is expected to consummate approximately twelve months after submission of regulatory filings, subject to customary closing conditions and regulatory approvals, including under the Hart-Scott-Rodino Act, Section 203 of the Federal Power Act from the FERC, the Washington Utilities and Transportation Commission (“WUTC”), the OPUC, the Idaho Public Utilities Commission, the Public Service Commission of Utah, the Public Utilities Commission of the State of California, the Public Service Commission of Wyoming, and certain other federal and state regulatory approvals. PGE submitted regulatory applications related to the Acquisition with the WUTC and the OPUC on March 30, 2026 and April 2, 2026, respectively. On July 15, 2026, the Company, jointly with other parties, submitted an application to the FERC seeking approval of the transaction, requesting a decision by December 15, 2026. The transaction is expected to be accounted for as a business combination pursuant to ASC 805, Business Combinations, using the acquisition method of accounting and in which PGE would record the fair value of the assets acquired and liabilities assumed as of the acquisition date. To the extent that the consideration transferred is greater than the fair value of the net assets acquired, goodwill will be recorded.
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.
Long-term debt	Long-term debt is recorded at amortized cost in PGE’s condensed consolidated balance sheets. The value of the Company’s Long-term debt is classified as a Level 2 fair value measurement.
Fair Value of Financial Instruments	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, 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.
Gross Reporting of Positive and Negative Exposures Related to Derivative Instruments	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.
Allocation of Financial Asset to Hierarchy Levels	Assets held in the Nuclear decommissioning trust (NDT), Non-qualified benefit plan (NQBP) trust, and Paid Leave Oregon trust 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. Money market funds—PGE invests in money market funds that seek to maintain a stable NAV. 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 NAV. Redemption is permitted daily without written notice. The NQBP trust is invested in a money market fund that is invested in domestic debt securities such as government debt securities, corporate securities and municipal debt and is classified as Level 2 in the fair value hierarchy due to the availability of the underlying assets being 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 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 longer-term commodity forwards, futures, swaps, and options for which fair value is derived using one or more significant inputs that are not observable for the entire term of the instrument, such as tenor of observable market quotes.
Fair Value Transfer	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.
Commitments and 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. Legal 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	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

Risk Management (Tables)

9 Months Ended

Sep. 30, 2026

Price Risk Management [Abstract]

Schedule of PGE's Assets and Liabilities from Price Risk Management Activities

PGE’s Assets and Liabilities from price risk management activities consist of the following (in millions):


	September 30, 2026		December 31, 2025
Current assets:
Commodity contracts:
Electricity	$	3	$	29
Natural gas		1		3
Total current derivative assets (1)		4		32
Noncurrent assets:
Commodity contracts:
Electricity		1		1
Natural gas		2		—
Total noncurrent derivative assets (1)		3		1
Total derivative assets (2)	$	7	$	33
Current liabilities:
Commodity contracts:
Electricity	$	12	$	19
Natural gas		101		139
Total current derivative liabilities		113		158
Noncurrent liabilities:
Commodity contracts:
Electricity		29		31
Natural gas		20		25
Total noncurrent derivative liabilities		49		56
Total derivative liabilities (2)	$	162	$	214

(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 September 30, 2026 and December 31, 2025, no commodity derivative assets or liabilities were designated as hedging instruments.

Schedule of PGE's Net Volumes related to Assets and Liabilities from Price Risk Management Activities


	September 30, 2026				December 31, 2025
Commodity contracts:
Electricity		(1	)	MWhs		1	MWhs
Natural gas		244		Decatherms		224	Decatherms
Foreign currency	$	22		Canadian	$	9	Canadian

Schedule of Net Realized and Unrealized Losses (Gains) on Derivative Transactions Not Designated as Hedging Instruments


	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Commodity contracts:
Electricity	$	6		$	(39	)	$	(32	)	$	(32	)
Natural Gas		(3	)		101			100			146
Foreign currency exchange		—			—			—			(1	)

Schedule of Future Year Net Unrealized Losses related to PGE's Derivative Activities


	2026		2027		2028		2029		2030		Thereafter		Total
Commodity contracts:
Electricity	$	3	$	5	$	4	$	4	$	4	$	17	$	37
Natural gas		35		73		7		3		—		—		118
Net unrealized loss	$	38	$	78	$	11	$	7	$	4	$	17	$	155

Condensed Consolidated Statements of Income and Comprehensive Income (Unaudited) - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2026	Sep. 30, 2025	Sep. 30, 2026	Sep. 30, 2025
Revenues, net	$ 969	$ 946	$ 2,643	$ 2,676
Alternative revenue programs, net of amortization	2	6	21	11
Total revenues	971	952	2,664	2,687
Operating expenses:
Purchased power and fuel	383	372	1,040	1,034
Generation, transmission and distribution	115	112	337	336
Administrative and other	86	99	282	291
Depreciation and amortization	146	148	433	427
Taxes other than income taxes	54	47	157	139
Total operating expenses	784	778	2,249	2,227
Income from operations	187	174	415	460
Interest expense, net	62	60	183	173
Other income:
Allowance for equity funds used during construction	8	4	17	15
Miscellaneous income, net	5	5	23	17
Other income, net	13	9	40	32
Income before income tax expense	138	123	272	319
Income tax expense	19	20	40	54
Net income	119	103	232	265
Other comprehensive income	1	1	1	1
Comprehensive income	$ 120	$ 104	$ 233	$ 266
Weighted-average common shares outstanding (in thousands):
Basic	118,199	110,170	116,534	109,708
Diluted	118,671	110,416	117,085	109,958
Earnings per share:
Basic	$ 1.01	$ 0.94	$ 1.99	$ 2.42
Diluted	$ 1	$ 0.94	$ 1.98	$ 2.41

Risk Management - Schedule of Future Year Net Unrealized Losses related to PGE's Derivative Activities (Details) $ in Millions	Sep. 30, 2026 USD ($)
Commodity contracts:
2026	$ 38
2027	78
2028	11
2029	7
2030	4
Thereafter	17
Total	155
Electricity [Member]
Commodity contracts:
2026	3
2027	5
2028	4
2029	4
2030	4
Thereafter	17
Total	37
Natural Gas [Member]
Commodity contracts:
2026	35
2027	73
2028	7
2029	3
2030	0
Thereafter	0
Total	$ 118

Shareholders' Equity (Details) - USD ($)		1 Months Ended			3 Months Ended	9 Months Ended	12 Months Ended
Shareholders' Equity (Details) - USD ($)	Oct. 22, 2026	Jul. 30, 2026	Feb. 28, 2026	Jul. 31, 2024	Sep. 30, 2026	Sep. 30, 2026	Dec. 31, 2025	Dec. 31, 2024
Subsidiary, Sale of Stock [Line Items]
Maximum value of shares to be issued under ATM program			$ 500,000,000	$ 400,000,000
Shares included in the calculation of diluted EPS					179,391	283,060
Equity Forward Sale Agreement
Subsidiary, Sale of Stock [Line Items]
Net proceeds received		$ 152,000,000
Stock settlement amount					$ 375,000,000	$ 375,000,000
New issues		3,117,541	9,467,455			7,730,584
Shares borrowed by forward counterparties			10,848,125
Number of shares in connection with underwriters exercise of option to purchase additional shares			1,380,670
Share price per share			$ 50.7
Underwriting discount equal price per share			1.4576
Forward sale price per share			$ 50.7
Issuances of shares pursuant to equity agreements		3,117,541	9,467,455			7,730,584
At-the-Market Offering Program
Subsidiary, Sale of Stock [Line Items]
Shares issued							5,919,618	1,066,549
Net proceeds received							$ 250,000,000	$ 50,000,000
Stock settlement amount					$ 8,000,000	$ 8,000,000
New issues						190,314
Issuances of shares pursuant to equity agreements						190,314
At-the-Market Offering Program \| Subsequent Events
Subsidiary, Sale of Stock [Line Items]
New issues	190,314
Issuances of shares pursuant to equity agreements	190,314
At-the-Market Offering Program \| Forward Sale Agreement
Subsidiary, Sale of Stock [Line Items]
Shares issued							5,756,432	1,420,049

Segment Information - Schedule of Segment Reporting Information, by Segment (Details) - USD ($) $ in Millions	3 Months Ended						9 Months Ended
	Sep. 30, 2026	Jun. 30, 2026	Mar. 31, 2026	Sep. 30, 2025	Jun. 30, 2025	Mar. 31, 2025	Sep. 30, 2026	Sep. 30, 2025
Segment Reporting [Line Items]
Revenues	$ 971			$ 952			$ 2,664	$ 2,687
Operating expenses:
Purchased power and fuel	383			372			1,040	1,034
Operating and maintenance expense:
Generation, transmission and distribution	115			112			337	336
Administrative and other	86			99			282	291
Total operating and maintenance expense	201			211			619	627
Depreciation and amortization	146			148			433	427
Taxes other than income taxes	54			47			157	139
Total operating expenses	784			778			2,249	2,227
Income from operations	187			174			415	460
Interest expense, net:
Interest expense	67			62			193	182
Allowance for borrowed funds used during construction	(5)			(2)			(10)	(9)
Total interest expense, net	62			60			183	173
Other income, net:
Other income, net	13			9			40	32
Income before income tax expense	138			123			272	319
Income tax expense	19			20			40	54
Net income	$ 119	$ 68	$ 45	$ 103	$ 62	$ 100	$ 232	$ 265

Risk Management - Schedule of PGE's Net Volumes related to Assets and Liabilities from Price Risk Management Activities (Details) MWh in Millions, MMBTU in Millions, $ in Millions	Sep. 30, 2026 USD ($) MMBTU MWh	Dec. 31, 2025 USD ($) MMBTU MWh
Price Risk Management Note [Abstract]
Electricity \| MWh	(1)	1
Natural gas \| MMBTU	244	224
Foreign currency \| $	$ 22	$ 9

Balance Sheet Components (Tables)

9 Months Ended

Sep. 30, 2026

Balance Sheet Components [Abstract]

Schedule of Allowance for Uncollectible Accounts Activity

The following summarizes activity during 2026 in the allowance for credit losses (in millions):


	Three Months Ended September 30,			Nine Months Ended September 30,
Balance as of beginning of period	$	14		$	13
Increase in provision		3			9
Amounts written off		(5	)		(14	)
Recoveries		2			6
Balance as of end of period	$	14		$	14

Schedule of Other Current Assets

Other current assets consist of the following (in millions):


	September 30, 2026		December 31, 2025
Prepaid expenses	$	93	$	96
Margin deposits		53		116
Assets from price risk management activities		4		32
Other current assets	$	150	$	244

Schedule of Public Utility Property, Plant, and Equipment

Electric utility plant, net consists of the following (in millions):


	September 30, 2026			December 31, 2025
Electric utility plant in-service	$	16,469		$	15,996
Construction work-in-progress		954			416
Total cost		17,423			16,412
Less: accumulated depreciation and amortization		(5,711	)		(5,419	)
Electric utility plant, net	$	11,712		$	10,993

Schedule of Regulatory Assets and Liabilities

Regulatory assets and liabilities consist of the following (in millions):


	September 30, 2026					December 31, 2025
	Current			Noncurrent		Current			Noncurrent
Regulatory assets:
Price risk management	$	109		$	46	$	127		$	54
Pension and other postretirement plans		—			64		—			64
Trojan decommissioning activities		—			168		—			161
February 2021 ice storm and damage		12			27		13			33
January 2024 storm and damage		24			12		—			48
Reliability contingency events		43			22		—			90
2020 Labor Day wildfire		5			11		5			14
Wildfire mitigation		35			3		9			33
Portland Harbor environmental remediation account		—			65		—			24
Other		29			95		14			98
Total regulatory assets	$	257		$	513	$	168		$	619
Regulatory liabilities:
Asset retirement removal costs	$	—		$	1,279	$	—		$	1,245
Deferred income taxes		—			215		—			228
Clearwater RAC		6			—		21			1
Other		59			30		53			16
Total regulatory liabilities	$	65	*	$	1,524	$	74	*	$	1,490

* Included in Accrued expenses and other current liabilities in the condensed consolidated balance sheets.

Schedule of Other Accrued Expenses and Other Current Liabilities

Accrued Expenses and Other Current Liabilities

Accrued expenses and other current liabilities consist of the following (in millions):


	September 30, 2026		December 31, 2025
Accrued employee compensation and benefits	$	65	$	87
Accrued taxes payable		67		38
Accrued interest payable		55		53
Accrued dividends payable		69		63
Regulatory liabilities—current		65		73
Margin deposits from wholesale counterparties		2		21
Other		139		143
Total accrued expenses and other current liabilities	$	462	$	478

Schedule of Pension and Other Postretirement Benefits Disclosure

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 September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
Service cost	$	3		$	2		$	7		$	7
Interest cost*		8			8			24			24
Expected return on plan assets*		(10	)		(9	)		(28	)		(27	)
Net periodic benefit cost	$	1		$	1		$	3		$	4

- Definition

The entire disclosure for retirement benefits.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
-SubTopic 20
-Name Accounting Standards Codification
-Section 50
-Paragraph 1
-Subparagraph (o)
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Reference 2: http://www.xbrl.org/2003/role/disclosureRef
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/exampleRef
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
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Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
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Reference 11: http://www.xbrl.org/2003/role/disclosureRef
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Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
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Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Topic 715
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-URI https://asc.fasb.org/1943274/2147480506/715-20-50-1

+ Details