POR on NYSE

Portland General Electric

Logo: Portland General Electric , by Cacophony ., Public domain, via Wikimedia Commons5

Public utility based in Portland, Oregon

Portland General Electric (PGE) is a Fortune 1000, publicly traded energy company based in Portland, Oregon, that generates, transmits and distributes electricity, serving almost two-thirds of Oregon's commercial and industrial activity. PGE is regulated by the Oregon Public Utility Commission.3 Wikipedia text CC BY-SA 4.0

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Last updated Oct 21, 2026.

Overview

1888Founded1

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  • TickerPOR on NYSE1
  • Industrypublic utility1
  • HeadquartersPortland1
  • Websiteportlandgeneral.com
  • Incorporated inOR6
  • Business address121 Sw Salmon St, 1Wtc0501, Portland, Or 972046
  • Filer categoryLarge accelerated filer6
  • Legal formBusiness Corporation4
  • LEIGJOUP9M7C39GLSK9R8704
  • StatusActive4
  • LEI statusIssued and current4
  • Registered address121 SW SALMON ST, 97204 Portland, United States4
  • Registered withCorporation Division (Oregon Secretary of State), 034142-164

Portland General Electric (PGE) is a Fortune 1000, publicly traded energy company based in Portland, Oregon, that generates, transmits and distributes electricity, serving almost two-thirds of Oregon's commercial and industrial activity. PGE is regulated by the Oregon Public Utility Commission. Founded in 1888 as the Willamette Falls Electric Company, the company has been an independent company for most of its existence, though was briefly owned by the Houston-based Enron Corporation from 1997 until 2006, when Enron divested itself of PGE during its bankruptcy.3

Financials

From the company’s reports to the SEC. Every number links to the filing it came from.

Key numbers, fiscal 2025

15.5%Operating margin8
8.6%Net margin8
4.0%Revenue growth, 20258
7.4%Return on equity8
1.13×Debt to equity8
-$71.0MFree cash flow8

Where the money goes

Where each dollar of revenue went, fiscal 2025

  • Other costs83¢$3.0B
  • Interest6¢$232.0M
  • Income tax1¢$53.0M
  • Profit9¢$306.0M

Out of $3.6B in revenue.8

Where each dollar of operating cash went, fiscal 2025

  • Capital spending84¢$1.2B
  • Dividends paid16¢$225.0M

Out of $1.1B of cash from operations. Spending exceeded cash from operations; the rest came from savings or borrowing.8

Financial statements

Revenue91011128$3.6B in 2025+68% since 2019
0$1.0B$2.0B$3.0B$4.0B2019: $2.1B$2.1B20192020: $2.1B$2.1B2020+1%2021: $2.4B$2.4B2021+12%2022: $2.6B$2.6B2022+10%2023: $2.9B$2.9B2023+10%2024: $3.4B$3.4B2024+18%2025: $3.6B$3.6B2025+4%
Operating income91011128$555.0M in 2025+57% since 2019
0$200.0M$400.0M$600.0M2019: $353.0M$353.0M20192020: $269.0M$269.0M2020−24%2021: $378.0M$378.0M2021+41%2022: $397.0M$397.0M2022+5%2023: $396.0M$396.0M2023−0%2024: $512.0M$512.0M2024+29%2025: $555.0M$555.0M2025+8%
Net income91011128$306.0M in 2025+43% since 2019
0$100.0M$200.0M$300.0M$400.0M2019: $214.0M$214.0M20192020: $155.0M$155.0M2020−28%2021: $244.0M$244.0M2021+57%2022: $233.0M$233.0M2022−5%2023: $228.0M$228.0M2023−2%2024: $313.0M$313.0M2024+37%2025: $306.0M$306.0M2025−2%

Every line of the income statement as filed: the last 3 fiscal years, latest first.8

Period ending2025-12-312024-12-312023-12-31
Revenues, net$3.6B$3.5B$2.9B
Alternative revenue programs, net of amortization$21.0M-$40.0M$11.0M
Total Revenues$3.6B$3.4B$2.9B
Purchased power and fuel$1.4B$1.4B$1.2B
Generation, transmission and distribution$450.0M$436.0M$374.0M
Administrative and other$392.0M$403.0M$341.0M
Depreciation and amortization$578.0M$496.0M$458.0M
Taxes other than income taxes$190.0M$175.0M$164.0M
Total operating expenses$3.0B$2.9B$2.5B
Income from operations$555.0M$512.0M$396.0M
Interest expense, net$232.0M$211.0M$173.0M
Allowance for equity funds used during construction$18.0M$23.0M$19.0M
Miscellaneous income, net$18.0M$26.0M$31.0M
Other income, net$36.0M$49.0M$50.0M
Income before income taxes$359.0M$350.0M$273.0M
Income tax expense$53.0M$37.0M$45.0M
Net income$306.0M$313.0M$228.0M
Basic110.5M shares103.9M shares97.8M shares
Diluted110.7M shares104.2M shares98.0M shares
Basic$2.77$3.02$2.33
Diluted$2.77$3.01$2.33

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Corporate structure

Portland General Electric sits at the top of its group. 1 entity, 1 country on record. Switch between the flow chart and the network, and select any entity to see its details.

Major holders of Portland General Electric

  • Portland General Electric Portland, Oregon, United States

Built from parent and subsidiary links from GLEIF, the Global Legal Entity Identifier Foundation (CC0); major holders from Schedules 13D and 13G. Each entity in the chart links to its source.

What it owns

What Portland General Electric reports owning in its annual reports to the SEC: buildings, land and equipment, real estate and locations, investments, intangible assets and inventory, at the end of its latest fiscal year and a year before.

Property and equipment

ItemLatestA year beforeChange
Finance-lease assets$262.0M8 Dec 31, 2025$276.0M8 Dec 31, 2024−5.1%
Operating-lease assets (leased space)$303.0M8 Dec 31, 2025$312.0M8 Dec 31, 2024−2.9%

Investments

ItemLatestA year beforeChange
Stakes in other companies (equity method)$19.0M8 Dec 31, 2025$13.0M8 Dec 31, 2024+46.2%

Intangibles and goodwill

ItemLatestA year beforeChange
Accumulated amortization$622.0M8 Dec 31, 2025$611.0M8 Dec 31, 2024+1.8%

Inventory

ItemLatestA year beforeChange
Supplies$99.0M8 Dec 31, 2025$92.0M8 Dec 31, 2024+7.6%

Properties, in its own words

PGE’s principal property, plant, and equipment are generally located on land owned by the Company or land under the control of the Company pursuant to existing leases, federal or state licenses, easements, or other agreements. In some cases, meters and transformers are located on customer property. The Indenture securing the Company’s FMBs constitutes a direct first mortgage lien on substantially all utility property and franchises, other than expressly excepted property.

Generating Facilities

The rest of Item 2

The following are generating facilities owned by PGE as of December 31, 2025 (in MW):

Facility · Location · Capacity

Wholly-owned:

Natural Gas or Oil (1):

Beaver · Clatskanie, Oregon · 516

Carty · Boardman, Oregon · 426

Port Westward Unit 1 · Clatskanie, Oregon · 403

Coyote Springs · Boardman, Oregon · 257

Port Westward Unit 2 · Clatskanie, Oregon · 225

Wind (2):

Biglow Canyon · Sherman County, Oregon · 450

Tucannon River · Columbia County, Washington · 267

Clearwater · Custer County, Montana · 208

Wheatridge · Morrow County, Oregon · 100

Hydro (3):

North Fork · Clackamas River · 56

Faraday · Clackamas River · 46

Oak Grove · Clackamas River · 42

River Mill · Clackamas River · 25

T.W. Sullivan · Willamette River · 18

Jointly-owned (4):

Coal:

Colstrip (5) · Colstrip, Montana · 296

Hydro (3):

Round Butte (6) · Deschutes River · 187

Pelton (6) · Deschutes River · 61

Capacity · 3,583

Represents net capacity of generating unit as demonstrated by actual operating or test experience, net of electricity used in the operation of a given facility.

Represents nameplate ratings. A generator’s nameplate rating is its full-load capacity under normal operating conditions as defined by the manufacturer.

Represents most favorable operating conditions, which refers to the set of optimal circumstances under which a power plant or energy generation system can achieve its maximum output capacity efficiently and reliably.

Represents PGE’s ownership share.

PGE has a 20% ownership interest in the facility, which is operated by Talen Montana, LLC.

PGE has a 50.01% ownership interest in the Pelton/Round Butte hydroelectric project.

PGE’s hydroelectric projects are operated pursuant to FERC licenses issued under the FPA. The licenses for the hydroelectric projects on the three different rivers expire as follows: Clackamas River, 2055; Willamette River, 2035; and Deschutes River, 2055.

Energy Storage Facilities

The following are energy storage facilities owned by PGE as of December 31, 2025 (in MW):

Facility · Location · Capacity

Seaside BESS · Multnomah County, Oregon · 200

Constable BESS · Washington County, Oregon · 75

Coffee Creek BESS · Washington County, Oregon · 17

Other BESS facilities · Various · 9

Total Energy Storage Capacity · 301

Transmission and Distribution

PGE owns or has contractual rights associated with transmission lines that deliver electricity from its generation facilities to its distribution system in its service territory and also to the Western Interconnection. As of December 31, 2025, the PGE-owned electric transmission system consisted of 1,744 circuit miles as follows: 287 circuit miles of 500 kV line; 414 circuit miles of 230 kV line; 577 miles of 115 kV line; and 466 miles of 57 kV line. The Company also has 29,251 circuit miles of distribution lines that deliver electricity to its customers. PGE also has an ownership interest in, and capacity on, the following:

14% of the 2,260 MW transmission facilities between the Colstrip switchyard and the Broadview switchyard, near Billings, Montana, and 16% of the 1,930 MW transmission facilities between the Broadview switchyard and the interconnection point with BPA’s transmission system near Townsend, Montana; and

20% of the Northwest AC Intertie, a 4,800 MW transmission facility between the John Day Substation, near the Columbia River in northern Oregon, and Malin, Oregon, near the California border. The Northwest AC Intertie is used primarily for the transmission of interstate purchases and sales of electricity among utilities, including PGE.

In addition, the Company has contractual rights to a total of 4,335 MW of BPA’s transmission systems, and 300 MW of Northwestern Energy’s transmission systems.

Non-utility Real Estate

PGE owns, through a wholly owned subsidiary, its corporate headquarters building located in Portland, Oregon. As of December 31, 2025, the non-utility property, plant, and equipment balance, net of accumulated depreciation was $76 million, recorded in Other noncurrent assets on the Company’s consolidated balance sheets in Item 8.— “Financial Statements and Supplementary Data.”

PGE also owns unregulated properties that are currently or previously leased to third parties and located adjacent to PGE’s T.W. Sullivan hydro generating facility. PGE has recorded a non-utility ARO related to this site. For more information regarding the Company’s AROs, see “Asset Retirement Obligations” within the “Critical Accounting Policies and Estimates” section of Item 7.— “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Note 8, Asset Retirement Obligations in the Notes to Consolidated Financial Statements in Item 8.— “Financial Statements and Supplementary Data.”

Item 2 of the 10-K filed Feb 17, 2026.17

The story

The utility was founded in 1888 by Parker F. Morey and Edward L. Eastham as Willamette Falls Electric Company. On June 3, 1889, it sent power generated by one of four brush arc light dynamos at Willamette Falls over a 14-mile (23 km) electric power transmission line to Portland, the first US power plant to do so.

On August 6, 1892, Morey, Frederick Van Voorhies Holman, and Henry Failing formed the Portland General Electric Company. It was funded by General Electric and the investment arm of Old Colony Trust, with $4.25 million in capital. The newly formed PGE Company purchased Willamette Falls Electric and the Albina Light & Water Company in 1892.

Less than a year later, in May 1893, PGE purchased the City-Eastside Electric Light Plant, a municipal power company. E. Kimbark MacColl, who chronicled the history of Portland, referred to it "a generous gift to a private company at the expense of future taxpayers" since it was constructed for a cost of $40,342 and sold 15 months later for $27,000.

In 1903, Henry W. Goode, the president of PGE, decided to make PGE a "popular public utility." His vision was for the company to light the Lewis and Clark Centennial Exposition in 1905. in 1903, he traveled to the east coast to raise $3,000 from shareholders. His plan went through, and Thomas H. Wright was put in charge of designing the lighting for the fair.

PGE also purchased the Union Power Company in 1905, and the Vancouver Electric Light & Power Company in 1906. In 1906, PGE, Portland Railway Company, and Oregon Water Power & Railway Company merged, becoming the Portland Railway, Light and Power Company (PRL&P). It was the only streetcar operator within Portland city limits, and the predecessor of the modern PGE.

The company name became Portland Electric Power Company (PEPCO) in 1932. It was reorganized in 1948 as PGE.

On March 1, 1939, PEPCO defaulted on interest bonds that had been issued in March 1934. The bonds were pledged with PGE (the electric subsidiary) and Portland Traction Company (the streetcar subsidiary) as collateral, with Guaranty Trust as trustee. PEPCO filed for Chapter X bankruptcy (now known as Chapter 9) on April 3, 1939, and was assigned District Judge James Alger Fee. The proceedings were later called "one of the most prolonged and complicated series of legal proceedings in Portland's history".

The reorganization and bond default was brought on by PGE's difficult negotiations with Bonneville Power Administration, the death of Seattle City Light's visionary J. D. Ross, and the indecision created by the possible creation of a public utility district in PGE's territory. The Columbia Valley Authority project would have allowed CVA to purchase utilities such as PGE.

Read the full text

PGE survived bankruptcy partially through cheap power purchases from BPA beginning in the fall of 1939, and by the end of 1941 they showed net profits. In the meantime, Ormond R. Bean, the Oregon Public Utility Commissioner, forced PGE to lower its rates. Ultimately, PEPCO and PGE were saved by World War II, which led to the construction of three Kaiser Shipyards and of Vanport City, Oregon to support them. By 1945, PGE derived nearly $400,000 in revenue from the two Kaiser shipyards in Oregon. In August 1946, after the war, they were able to sell Portland Traction for $8 million in cash. Judge Fee ruled the bankruptcy reorganization complete on June 29, 1946.

On July 1, 1997, Enron Corporation bought PGE for $2 billion in stock and $1.1 billion in assumed debt. Then in 1999, and again in 2001, Enron attempted to sell PGE to other investor-owned utilities including Portland-based NW Natural. The corporate officers of PGE claimed that this utility was not involved in the financial mis-dealings of its owner, pointing to the fact that many of its employees suffered when Enron froze the 401(k) retirement plan and were unable to sell the rapidly declining stock. However, Ken Harrison and Joseph Hirko, PGE's CEO and CFO respectively at the time of the Enron merger were charged on several felony level counts primarily related to financial misrepresentation regarding Enron Broadband Services which had its headquarters within the World Trade Center complex that comprises PGE's corporate offices. In addition Timothy Belden, head of the West Coast Trading Desk and John Forney, an energy trader who invented various electricity trading strategies such as the Death Star, operated from the trading floor in the PGE corporate offices and were also convicted of financial crimes related to the California Electricity Crisis.

Early attempts to convert the company to a public utility district

Ballot measures have been filed by citizens several times since the 1960s to convert some or all of PGE into a public utility district (PUD), the latest of these being in 2003. Most were unsuccessful, but an exception was in 1999, when PGE announced it was selling its customer base in St. Helens, Scappoose, and Columbia City to West Oregon Electric PUD for $7.9 million. The terms of this sale proposed to leave the physical assets of the distribution system —the poles, wires and other components— owned by Enron, who would then manage this system as a contractor exempt from state regulation. Voter distrust of both Enron and PGE was severe enough for voters to approve the measure, despite $71,592 being spent in advertisements to oppose it, in comparison to the $2,304 spent by supporters. This resulted in those three cities becoming part of the Columbia River PUD on terms far more favorable to the customers; electricity rates immediately dropped in these cities, and remain lower than those for current PGE customers.

Attempted acquisition by Texas Pacific Group

Concerned by uncertainty that the Enron bankruptcy would bring, several local governments began investigation into acquiring PGE by condemnation. These studies ended after the announcement on November 17, 2003, that a group called Oregon Electric Utility, led by former governor Neil Goldschmidt and backed by Texas Pacific Group, offered to buy PGE for $2.35 billion. This was the sole bid received by the bankruptcy judge, who approved the bid. When details that Goldschmidt had sexually assaulted a minor in the 1970s emerged, he withdrew from the negotiations, and was replaced by Peter O. Kohler, president of the Oregon Health and Science University.

Discomfort over the Texas Pacific purchase led to further voter initiatives to convert parts of PGE into PUDs. PGE defeated measures in Multnomah County (November 14, 2003), Yamhill County (March 2004), and Clackamas County (May 18, 2004).

Also during this time period, PGE received notice of a strike by 900 union workers, effective March 8, 2004, represented by the International Brotherhood of Electrical Workers. Points over which the negotiations broke down included retiree medical benefits as well as losses of the members' 401(k) plan. This labor dispute was resolved shortly afterward, and the union agreed to a new contract.

The TPG purchase offer was denied by the Oregon Public Utility Commission, a three-member regulatory board, on March 10, 2005.

With the rejection of the Texas Pacific Group's offer, the City of Portland announced it contacted Enron to resume negotiating an offer to purchase PGE. On April 19, 2005, Portland city officials announced that they were willing to spend $7.5 million in attorneys' fees to buy the utility. On July 6, the City Council unanimously adopted a measure to finance the acquisition of PGE by the sale of $3 billion in bonds.

However, Enron interim CEO Stephen Cooper called off negotiations on July 20, 2005. He explained that he did not "see a plausible solution under which our teams could reach an agreement that would lead to a transaction closing in a timely fashion". Cooper addressed several causes for the termination, including the refusal of the city to pay a $50 million deposit on the sale. The same day, Governor Ted Kulongoski vetoed a bill that would create a public corporation to purchase PGE.

Independence from Enron

In April 2006, shares in a newly independent PGE were issued as part of an Enron distribution to its creditors.

From Wikipedia’s article on Portland General Electric, shared under CC BY-SA 4.0.7

Leadership

Who has led Portland General Electric, and when. Pick a name to see everywhere that person has worked.

Board members and other officers (48)

Products and brands

  • electric power

Listed on Wikidata.1

Source for section:

Thermal power plants

Beaver Generating Plant – 511 MWe – a combined cycle cogeneration plant located in Clatskanie, Oregon. PGE's Beaver Generating Facility, located in Clatskanie Oregon, is a natural gas fired combined cycle power plant that includes six identical sets of GE Model MS 7001B combustion turbine (GTs) and Heat Recovery Steam Generators (HRSGs), and one Steam Turbine Generator (STG) configured in a 6x1 arrangement.

Port Westward High Efficiency Gas Power Plant 1 & 2 – 393 & 214 MWe capacity. Located next to Beaver Generating Plant.

Carty Generating Plant – 436 MWe – located next to the former Boardman Coal Plant.

Read the full text

Coyote Springs Generating Plant – 257 MWe – located in Boardman, Oregon; began operating in 1995. Coyote Springs is a combined cycle cogeneration plant.

Colstrip Power Plant 3 & 4 – 296 MWe – located in Colstrip, Montana.

Hydroelectric plants

Faraday (Clackamas River) – 46 MWe

North Fork (Clackamas River) – 58 MWe

Oak Grove (Clackamas River) – 43 MWe

River Mill Hydroelectric Project (Clackamas River) – 25 MWe

T. W. Sullivan Hydroelectric Plant (Willamette River) – 18 MWe

Pelton Dam (Deschutes River) – 57 MWe

Round Butte Dam (Deschutes River) – 187 MWe

Bull Run (Sandy and Little Sandy rivers) – 22 MWe (decommissioned, 2007)

Renewable sources

Biglow Canyon Wind Farm – generating capacity of 450 MWe

Tucannon River Wind Farm – generating capacity of 267 MWe

Marion County Waste-to-Energy Facility – 13 MWe from municipal garbage incineration.

Clearwater Wind Farm - generating capacity of 311 MWe

Wheatridge Renewable Energy Facility - generating capacity of 380 MWe – 300 MWe wind, 50 MWe solar facility and 30 MWe battery storage system.

Decommissioned facilities

Boardman Generating Plant (coal) – 601 MWe – located in Boardman, Oregon. Closed on October 15, 2020.

Bull Run Hydroelectric Plant (Sandy and Little Sandy rivers) - 22 MWe – located in Bull Run, Oregon. Closed on May 21, 2007.

Trojan Nuclear Plant – 1130 MWe – located in Rainier, Oregon. Closed on November 9, 1992.

From Wikipedia’s article on Portland General Electric, shared under CC BY-SA 4.0.7

Acquisitions

  1. Succeeded Portland Electric Power Co.1

Timeline

  1. Sep 28, 20268-K Other events71
  2. Aug 12, 20268-K Regulation FD disclosure72
  3. Jul 31, 20268-K Results of operations; Regulation FD disclosure73
  4. May 12, 20268-K Regulation FD disclosure74
  5. May 1, 20268-K Results of operations; Regulation FD disclosure75
  6. Apr 28, 20268-K Shareholder vote76
  7. Mar 24, 20268-K Entered a material agreement; New debt or obligation; Regulation FD disclosure77
  8. Feb 19, 20268-K Other events78
  9. Feb 17, 20268-K Entered a material agreement; Results of operations; New debt or obligation79
  10. Feb 17, 20268-K Other events80
  11. Dec 29, 20258-K Other events81
  12. Oct 31, 20258-K Results of operations; Regulation FD disclosure82
  13. Feb 16, 2018New chief executive Maria M. Pope becomes CEO18
  14. Jan 16, 2009New chief executive James J. Piro becomes CEO19
  15. Jul 14, 2006New chief executive Peggy Y. Fowler becomes CEO20
  16. 1888Founded Founded1

Calendar

Coming up

  1. Oct 29, 2026 · Before the openReports results for the quarter ending Sep/2026 A year earlier it reported $1 a share, on Oct 31, 2025.83

When it reported results

  1. Jul 31, 2026Reported quarterly or annual results73
  2. May 1, 2026Reported quarterly or annual results75
  3. Feb 17, 2026Reported quarterly or annual results79
  4. Oct 31, 2025Reported quarterly or annual results82
  5. Jul 25, 2025Reported quarterly or annual results84
  6. Apr 25, 2025Reported quarterly or annual results85
  7. Feb 14, 2025Reported quarterly or annual results86
  8. Oct 25, 2024Reported quarterly or annual results87

Upcoming dates from Nasdaq's calendar; past results from the company's 8-K filings (Item 2.02). The full markets calendar

Filings

355 filings to the SEC since October 2021: 5 annual reports, 15 quarterly reports, 67 major events, 180 insider forms, 18 large holders, 70 other. The latest 20:

  1. Sep 28, 20268-K EDGAR
  2. Aug 12, 20268-K EDGAR
  3. Jul 31, 2026SCHEDULE 13G EDGAR
  4. Jul 31, 20268-K EDGAR
  5. Jul 31, 202610-Q EDGAR
  6. Jul 29, 2026SCHEDULE 13G EDGAR
  7. Jul 28, 20264 EDGAR
  8. Jul 28, 20264 EDGAR
  9. Jul 28, 20264 EDGAR
  10. Jul 28, 20264 EDGAR
  11. Jul 28, 20264 EDGAR
  12. Jul 28, 20264 EDGAR
  13. Jul 28, 20264 EDGAR
  14. Jul 28, 20264 EDGAR
  15. Jul 27, 2026144 EDGAR
  16. Jun 1, 2026144 EDGAR
  17. May 13, 2026144 EDGAR
  18. May 12, 20264 EDGAR
  19. May 12, 20268-K EDGAR
  20. May 12, 20264 EDGAR

The 355 filings since October 2021 can be filtered by form type and year here when JavaScript is on.

Every filing from the last five years, summarized. The full record is on SEC EDGAR.

Insider trades

40 open-market trades by officers, directors and large owners since October 2021: 3 buys and 37 sales. Grants, option exercises and gifts are left out.

DateWhoTradeSharesPriceValueFiling
Jul 27, 2026Lewis Michael ADirectorSale1,537$51.83$79.7KForm 4
May 11, 2026McFarland John CarterSVP, Commercial & CustomerSale2,390$48.52$116.0KForm 4
May 11, 2026HOGLUND ROBERT NDirectorBuy2,000$48.80$97.6KForm 4
May 8, 2026Gallegos Juan DiegoVP, CHROSale2,750$48.68$133.9KForm 4
May 7, 2026Espinosa Maria AngelicaSVP, CLO, CCA & CC OfficerSale4,300$48.81$209.9KForm 4
May 6, 2026Trpik Joseph R JRSVP, CFOSale7,500$49.03$367.7KForm 4
Feb 27, 2026Felton BenjaminEVP, COOSale4,969$53.56$266.1KForm 4
Sep 10, 2025POPE MARIA MPresident and CEOSale18,896$42.50$803.1KForm 4
Aug 22, 2025Bekkedahl Larry NealSenior Vice PresidentSale2,000$43.00$86.0KForm 4
Aug 6, 2025McFarland John CarterSVP, Commercial & CustomerSale2,190$42.34$92.7KForm 4
Aug 1, 2025Trpik Joseph R JRSVP, CFOSale2,603$41.35$107.6KForm 4
Jul 31, 2025Kochavatr John TeerukVP, CIOSale6,000$41.15$246.9KForm 4
Jul 21, 2025Lewis Michael ADirectorSale1,937$40.10$77.7KForm 4
Apr 17, 2025Felton BenjaminEVP, COOSale1,845$43.02$79.4KForm 4
Feb 18, 2025Felton BenjaminEVP, COOSale575$41.32$23.8KForm 4
Feb 18, 2025Trpik Joseph R JRSVP, CFOSale1,375$41.32$56.8KForm 4
Feb 18, 2025Espinosa Maria AngelicaSVP, CLO, CCA & CC OfficerSale2,618$41.32$108.2KForm 4
Feb 13, 2025Espinosa Maria AngelicaSVP, CLO, CCA & CC OfficerSale2,199$41.90$92.1KForm 4
Nov 6, 2024Bekkedahl Larry NealSenior Vice PresidentSale2,000$47.17$94.3KForm 4
Sep 11, 2024Felton BenjaminEVP, COOBuy11$47.49$522Form 4

All 40 trades can be filtered by person here when JavaScript is on.

From Forms 4 filed with the SEC.

Major holders

Investors who own more than 5% of the shares must tell the SEC: a 13D if they may seek to influence the company, a 13G if they hold passively.

Executive pay

What the company paid its top executives, from the summary compensation table in its proxy statement. Total pay includes salary, bonus, stock and option awards and other pay, as the company valued them.

YearExecutiveAgeSalaryTotal pay
2025Maria Pope61$1.2M$7.6M96
2025Benjamin Felton$735.5K$2.5M96
2025Joe Trpik$690.8K$2.2M96
2025Martin WyspianskiVice President, Power Markets and Grid Operations$340.7K$2.1M96
2025Angelica Espinosa$596.5K$2.0M96
2024President and CEO$1.2M$7.4M96
2024Executive Vice PresidentChief Operating Officer$678.9K$2.5M96
2024Senior Vice PresidentFinance and Chief Financial Officer$632.5K$2.3M96
2023President and CEO$1.1M$7.0M96
2023Senior Vice PresidentFinance and Chief Financial Officer$302.3K$3.2M96
2023Executive Vice PresidentChief Operating Officer$487.5K$3.1M96

Held by these funds

The largest holders among investment managers' 13F reports for the quarter ending Jun 30, 2026, the top 25 of 100. Change is in shares since the quarter before.

FundSharesValueShare of the fundChange
BlackRock, Inc.18,719,655$970.2M0.0%+1,292,219
Vanguard Portfolio Management LLC7,298,588$378.3M0.0%−37,069
Clearbridge Investments, LLC6,363,146$329.8M0.3%+367,472
Vanguard Capital Management LLC5,237,016$271.4M0.0%+83,419
State Street Corp5,019,860$262.8M0.0%+372,165
Aqr Capital Management LLC4,756,376$246.2M0.1%+428,637
Fuller & Thaler Asset Management, Inc.3,841,325$199.1M0.5%−93,520
Two Sigma Investments, LP3,275,901$169.8M0.1%+234,982
Geode Capital Management, LLC3,243,925$168.2M0.0%+273,118
Invesco Ltd.3,217,843$166.8M0.0%+691,073
Norges Bank2,468,502$127.9M0.0%New
Massachusetts Financial Services Co /ma/2,329,723$120.7M0.0%+553,570
HITE Hedge Asset Management LLC2,133,988$110.6M6.1%−557,008
Millennium Management LLC1,982,858$102.8M0.1%+147,603
Morgan Stanley1,904,185$98.7M0.0%+144,038
Dimensional Fund Advisors LP1,861,953$96.5M0.0%+30,811
Neuberger Berman Group LLC1,828,102$94.8M0.1%+218,946
Bank Of America Corp /de/1,708,684$88.6M0.0%+48,238
Charles Schwab Investment Management Inc1,504,865$78.0M0.0%+20,722
Northern Trust Corp1,495,720$77.5M0.0%+97,502
Bank of New York Mellon Corp1,360,525$70.5M0.0%−54,662
Jpmorgan Chase & Co1,344,853$70.5M0.0%−226,519
Nuveen, LLC1,202,996$62.4M0.0%+47,467
Victory Capital Management Inc1,172,453$60.8M0.0%+98,258
Fmr LLC1,047,258$54.3M0.0%+240

13F reports cover disclosed long positions in U.S. stocks only.

Members of Congress who traded it

7 trades disclosed by members of Congress. “Vs S&P since” is the stock’s change since the trade minus the S&P 500’s.

DateMemberTradeAmountVs S&P sinceFiling
Sep 8, 2023Lois FrankelDemocratic, HouseSale$1,001 - $15,000+72.8%Report
Nov 30, 2020Lois FrankelDemocratic, HouseBuy$1,001 - $15,000−107.1%Report
Aug 11, 2020Earl Blumenauer, HouseSale$1,001 - $15,000+128.9%Report
Jun 2, 2020Earl Blumenauer, HouseBuy$1,001 - $15,000−158.1%Report
Jun 1, 2020Earl Blumenauer, HouseBuy$1,001 - $15,000−158.3%Report
May 28, 2020Lois FrankelDemocratic, HouseBuy$1,001 - $15,000−159.5%Report
May 27, 2020Lois FrankelDemocratic, HouseBuy$1,001 - $15,000−156.3%Report

Members report amounts as ranges, not exact figures. Returns are price-only (no dividends).

SEC filer profile

How Portland General Electric is registered with the Securities and Exchange Commission, from its EDGAR record and the cover page of its latest annual report.

  • Name on EDGARPORTLAND GENERAL ELECTRIC CO /OR/2
  • CIK0000784977
  • Employer ID (EIN)93-025682017
  • Filer statusLarge accelerated filer not an emerging growth company; not a smaller reporting company; not a shell company17
  • Incorporated inOregon17
  • Fiscal year endsDecember 312
  • Industry code (SIC)4911 Electric Services2
  • SEC reviewing officeOffice of Energy & Transportation, Division of Corporation Finance2
  • Business address121 Sw Salmon St, 1Wtc0501, Portland, OR 972042
  • Mailing address121 Sw Salmon Street, Portland, OR 972042
  • Phone50346480002
  • Shares outstanding117,607,740 as of Jul 24, 202614
  • Public float$4.4B as of Jun 30, 202517
  • AuditorDeloitte & Touche LLP, Portland, Oregon PCAOB ID 34; it also attests to the company’s internal control over financial reporting17
  • On EDGAR sinceFeb 17, 19942
  • Filings1,529 in all: 4 (727), 8-K (345), 10-Q (98), SC 13G/A (44), 3 (42), 144 (36), 10-K (33), DEFA14A (24)2
    All 43 form types

    DEF 14A (20), 4/A (18), 424B5 (17), SC 13G (16), UPLOAD (13), ARS (12), 424B2 (10), CORRESP (7), S-3ASR (7), SC 13D/A (6), S-8 (5), U-1/A (5), 10-K/A (4), 8-K/A (4), U-6B-2 (4), S-3 (3), SCHEDULE 13G (3), 3/A (2), 5 (2), 8-A12B (2), DEFR14A (2), FWP (2), NO ACT (2), PRE 14A (2), U-12-IB (2), 15-12B (1), 25 (1), 424B7 (1), CERTNYS (1), NT 10-K (1), S-3/A (1), SC 13D (1), SCHEDULE 13G/A (1), SE (1), U-1 (1)

  • Latest filingsAnnual report (10-K) Feb 17, 2026
    Quarterly report (10-Q) Jul 31, 2026
    Proxy statement (DEF 14A) Mar 13, 2026
    Latest 8-K (8-K) Sep 28, 2026

Securities registered for trading

ClassSymbolExchange
Common Stock, no par valuePORNew York Stock Exchange

From the cover page of the 10-K filed Feb 17, 2026 (Section 12(b) of the Exchange Act).17

Risk factors and legal proceedings

The risks Portland General Electric names in Item 1A of its 10-K filed Feb 17, 2026: 32 risks under these headings, as written.17

  • BUSINESS AND OPERATIONAL RISKS
  • The effects of unseasonable or severe weather and other natural phenomena can adversely affect the Company’s financial condition and results of operations, and the effects of climate change could result in more intense, frequent, and extreme weather events.
  • Facilities may be exposed to wildfires or cause wildfires, which could disrupt services, hinder the Company’s ability to execute its strategic plan, subject the Company to liability and litigation, adversely affect PGE’s access to capital and increase costs.
  • Cybersecurity attacks, data security breaches, physical attacks and security breaches, acts of terrorism, or other similar events could disrupt PGE’s operations, require significant expenditures, or result in claims against the Company.
  • Natural or human-caused disasters and other risks could damage the Company’s facilities and disrupt delivery of electricity resulting in significant property loss, repair costs, and reduced customer satisfaction.
  • Electric utility operations may pose risk to workers, the public, and property, and may have adverse impacts on the environment.
  • The inability to attract and retain a qualified workforce and to maintain satisfactory collective bargaining agreements without prolonged labor disruptions may adversely affect PGE’s results of operations.
  • The construction of new facilities and the modifications or replacements of existing facilities are subject to risks that could result in the disallowance of certain costs for recovery in customer prices or higher operating costs.
  • Trade tariffs and related market volatility and supply chain disruptions could increase PGE’s operating costs, impair PGE’s ability to complete capital projects, and impede access to capital markets.
  • Failure of potential data center or other large load customers to materialize as expected, or materialize and then relocate to other service areas, could result in an inability to recover the costs of certain capital investments or failure to achieve PGE’s strategic goals.
  • RISKS RELATED TO THE PENDING ASSET PURCHASE ACQUISITION
  • Failure to complete the Asset Purchase Acquisition (the “Acquisition”) could negatively impact the Company’s results of operations, financial condition, and the market value of its common stock and debt securities.
The other 22 risks
  • An adverse outcome in any litigation or other legal proceedings relating to the Agreement, or the transactions contemplated thereby, could have a material adverse impact on the businesses of PGE or their ability to consummate the transactions contemplated by the Agreement.
  • The Acquisition may not achieve its intended results, including anticipated synergies and cost savings.
  • As a result of the Acquisition, PGE will be subject to the regulatory oversight of Washington state, the scope and size of its business and operations are expected to change substantially, and PGE may not be able to successfully integrate or manage the Acquired Business.
  • REGULATORY, LEGAL, AND COMPLIANCE RISKS
  • PGE is subject to extensive price regulation and relies on recovery of costs, the uncertainty of which could affect the Company’s operations and costs.
  • PGE is subject to various legal and regulatory proceedings, the outcome of which is uncertain, and resolution unfavorable to PGE could adversely affect its results of operations, financial condition, or cash flows.
  • Compliance with environmental laws and regulations may result in capital expenditures, increased operating costs and various liabilities, and adverse impacts on the Company’s results of operations.
  • Changes in federal laws and programs may have an adverse impact on the Company’s financial position, results of operations, and cash flows.
  • ECONOMIC, FINANCIAL, AND MARKET RISKS
  • A change in forecasted customer demand for electricity may negatively impact PGE’s business.
  • Concerns about high prices for PGE’s customers could negatively impact PGE’s financial condition, results of operations, liquidity, and cash flows.
  • Capital and credit market conditions could adversely affect the Company’s access to capital, cost of capital, and ability to execute its strategic plan.
  • The declaration of future dividends is at the discretion of the Board of Directors and is not guaranteed and, in some circumstances, the payment of dividends may be limited by the terms of PGE’s debt instruments.
  • Adverse changes in PGE’s credit ratings could negatively affect its access to the capital markets and its cost of borrowed funds.
  • Under certain circumstances, banks participating in PGE’s syndicated unsecured revolving credit facility could decline to fund advances requested by the Company or could withdraw from participation in the credit facility, which could adversely affect PGE’s liquidity.
  • Adverse capital market performance could result in reductions in the fair value of benefit plan assets and increase the Company’s liabilities related to such plans. Sustained declines in the fair value of the plans’ assets could result in significant increases in funding requirements, which could adversely affect PGE’s liquidity and results of operations.
  • The volatility of market prices for power and natural gas could adversely affect PGE’s costs and ability to manage its energy supply, which could negatively impact the Company’s liquidity and results of operations.
  • Reduced river flows, unfavorable wind conditions, reduced capacity or degradation of solar panels, and forced outages at generating and battery storage facilities can increase the cost of power required to serve customers. The Company could be required to replace energy expected from these sources with higher cost power from other facilities or with wholesale market purchases, which could have an adverse effect on results of operations.
  • The capacity provided by the Company’s generating resources and third-party purchased power may not be sufficient to meet its customers’ energy demand requirements and may result in increased GHG emissions.
  • Advances in energy technology could make PGE’s business less competitive.
  • Changes in market conditions and environmental laws and regulations could negatively impact PGE’s non-utility real estate investments.
  • Stakeholder expectations and standards with respect to PGE’s environmental, social, and governance (ESG) programs could result in increased costs and exposure to incremental risk.
  • Actions of activist shareholders could have a negative impact on PGE’s business.
  • PGE’s business activities are concentrated in one region and future performance may be affected by events and factors unique to Oregon or the region.

Legal proceedings

See Note 19, Contingencies in the Notes to Consolidated Financial Statements in Item 8.—“Financial Statements and Supplementary Data,” for information regarding legal proceedings.

The opening of Item 3, Legal Proceedings.17

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