Pacific Gas and Electric Company

PG&E Corporation

File:Pacific Gas and Electric Company logo.svg
Company type	Public
Traded as	NYSE: PCG S&P 500 component
Industry	Electricity Natural gas
Founded	1905 (1905)
Headquarters	300 Lakeside Drive Oakland, California, U.S.
Key people	PG&E Corporation: Robert Flexon (chairman) Patti Poppe (CEO) Carolyn Burke (EVP & CFO) Pacific Gas & Electric Company: Sumeet Singh (EVP & COO) Peter Kenny (SVP, Electric) Joseph Forline (SVP, Gas)
Products	Electricity Natural gas
Revenue	Decrease Template:US$ (2024)
Operating income	Increase US$4.459 billion (2024)
Net income	Increase US$2.475 billion (2024)
Total assets	Increase US$133.7 billion (2024)
Total equity	Increase US$30.15 billion (2024)
Number of employees	28,400 (2024)
Website	pgecorp.com

The Pacific Gas and Electric Company (PG&E) is a U.S.-based Investor-owned utility with its headquarters located at the Kaiser Center in Oakland, California. PG&E delivers both natural gas and electricity to approximately 5.2 million customers throughout the northern two-thirds of California, spanning from Bakersfield, California up to areas near the borders of Oregon and Nevada.

As a regulated entity under the oversight of the California Public Utilities Commission, PG&E operates as the main subsidiary of PG&E Corporation, which held a market value of $34.9 billion as of March 10, 2025. Established in 1905 through the amalgamation of earlier utility firms, it had grown by 1984 to become the largest electric utility in the United States. PG&E ranks among six regulated investor-owned electric utilities in California, alongside firms such as PacifiCorp and Southern California Edison.

During 2018 and 2019, PG&E encountered considerable financial difficulties and damage to its reputation following investigations by the California Department of Forestry and Fire Protection (Cal Fire), which linked several major wildfires—including the fatal 2018 Camp Fire—to its equipment. These liabilities compelled PG&E to initiate Chapter 11 bankruptcy proceedings on January 14, 2019, due to claims arising from the devastating Northern California fires of 2017 and 2018.

The company sought to complete its bankruptcy process by mid-2020 and successfully emerged after U.S. Bankruptcy Judge Dennis Montali sanctioned its reorganization plan on June 30, 2020.

San Francisco Gas

During the 1850s, manufactured gas was introduced as a lighting source in the United States. While eastern cities developed gasworks, the western region lacked a gas industry. In San Francisco, streets like Merchant Street were illuminated solely by oil lamps.

Three brothers—Peter, James, and Michael Donahue—who operated the foundry that evolved into Union Iron Works, then the largest shipbuilder on the West Coast, pursued ventures into gas production. They collaborated with engineer Joseph G. Eastland on research efforts. In July 1852, James Donahue obtained a franchise from the San Francisco Common Council authorizing construction of a gasworks facility, installation of pipes, and street lamps utilizing "brilliant gas," offered at rates designed to encourage residential adoption. Eastland and the Donahue brothers established the San Francisco Gas Company on August 31, 1852, with an authorized capital of $150,000—marking it as the first gas utility in the western United States. The company’s emblem bore the motto "Fiat Lux" (meaning "let there be light"). The Donahue brothers owned 610 out of 1,500 shares.

The gasworks was situated south of Market Street near the bayfront, bordered by First, Fremont, Howard, and Natoma streets. Construction commenced in November 1852 and was completed within several months. On February 11, 1854, San Francisco’s streets were illuminated by gas for the first time—a milestone celebrated with a banquet held at the Oriental Hotel. Gas lighting rapidly gained popularity: customer numbers increased from 237 during its inaugural year to 563 in the following year; by 1855 more than six and a half miles of piping and 154 street lamps had been installed.

The company's success attracted competitors such as Aubin Patent Gas Company and Citizens Gas Company; however, San Francisco Gas swiftly acquired these rivals. A major competitor emerged when the Bank of California established City Gas Company in April 1870 intending to challenge the Donahues’ dominance. City Gas began operations in 1872 and ignited a price war between the firms. In 1873, both companies agreed to merge under terms granting partial ownership to the Bank of California over what became known as "the most profitable gas monopoly in the West." On April 1, 1873, this consolidation resulted in formation of the San Francisco Gas Light Company through merging San Francisco Gas Company, City Gas Company, and Metropolitan Gas Company.

San Francisco Gas and Electric

With the advent of electric lighting in California, gas providers such as San Francisco Gas Light encountered increasing competition. In 1879, San Francisco distinguished itself as the first American city to operate a centralized electric power station. To remain competitive, San Francisco Gas Light introduced the Argand lamp that same year, which improved the brightness of gas street lamps; however, its high cost limited widespread adoption. The demand for electric street lighting in downtown San Francisco grew consistently, marked by the installation of the first electric street lamp at City Hall in 1888 and the construction of a second power station by California Electric Light Company to meet rising electricity needs.

During the 1880s, water gas—a more efficient lighting fuel patented by Thaddeus Lowe—entered the market as a formidable rival. The United Gas Improvement Company, established after acquiring Lowe’s patents, initially leased and subsequently acquired stakes in San Francisco's Central Gas Light Company in 1883. In 1884, United was absorbed by Pacific Gas Improvement Company. Under the leadership of Albert Miller, Pacific Gas Improvement emerged as a significant competitor to San Francisco Gas Light. His sons, Horace A. Miller and C.O.G. Miller, eventually gained control over both Pacific Gas Improvement and Pacific Gas Lighting Company.

In 1888, San Francisco Gas Light constructed a water gas facility at the Potrero gas works to take advantage of low-cost petroleum. The company also developed an advanced gas works combining water gas and coal-gas technologies as a safeguard against petroleum supply interruptions. By 1891, under Joseph B. Crockett’s presidency, the North Beach Gas Works was completed, featuring what was then the largest gas holder west of Chicago.

The year 1896 saw Edison Light and Power merge with San Francisco Gas Light, creating San Francisco Gas and Electric Company. This merger eliminated competition and achieved operational cost efficiencies through consolidation. Other rivals—including Equitable Gas Light Company, Independent Electric Light and Power Company, and Independent Gas and Power Company—also merged into this entity. In 1903, it further expanded by acquiring its principal gas lighting adversary, Pacific Gas Improvement Company.

Pacific Gas and Electric Company

John Martin and Eugene J. de Sabla initially worked as gold miners along the Yuba River before transitioning into hydroelectric power by establishing plants in Nevada City (1895) and other parts of Northern California.

In the early 1890s, Martin, de Sabla, Alfonso Tregidgo, and Romulus Riggs Colgate collaborated to develop a hydroelectric powerhouse on the South Fork of the Yuba River.

By 1899, Martin and de Sabla had formed Yuba Power Company. Within a year, they founded Bay Counties Power Company, which constructed a 140-mile transmission line to support an electric railway system in Oakland. In 1903, they created California Gas & Electric Company to consolidate various gas and electric utilities, acquiring companies such as Oakland Gas Light & Heat, United Gas & Electric, and San Francisco Gas & Electric by 1905.

Martin and de Sabla established Pacific Gas and Electric Company in 1905 by merging San Francisco Gas and Electric Company with California Gas and Electric Corporation. This union provided entry into the San Francisco market while enhancing the electric grid by combining cost-effective hydroelectric power with existing steam generation facilities. Although operational coordination began immediately after the merger, both companies maintained separate corporate identities until their official consolidation in 1911.

In 1930, PG&E commenced natural gas deliveries to San Francisco and northern California through what was then the world’s longest pipeline linking Texas gas fields to California. Compressor stations outfitted with cooling towers were situated at Topock, Arizona, and near Hinkley, California. Most gas manufacturing plants were subsequently phased out except for a few retained as backups. Presently, PG&E operates eight compressor stations connected by an extensive network exceeding 40,000 miles of distribution pipelines alongside more than 6,000 miles of transportation pipelines serving approximately 4.2 million customers spanning from Bakersfield to the Oregon border.

During the mid-20th century—specifically in the 1950s and 1960s—hexavalent chromium was applied at compressor stations in Topock and Hinkley to inhibit corrosion within cooling towers. The disposal practices involving cooling tower water near these sites later resulted in significant groundwater contamination challenges.

The 1906 San Francisco earthquake

PG&E experienced significant disruption due to the 1906 San Francisco earthquake. The company's headquarters suffered structural damage from the seismic event and were subsequently destroyed by the fire that followed. Its subsidiary, the San Francisco Gas and Electric Company, lost extensive infrastructure, with numerous gas mains and electric lines cut off. Only a pair of gas plants and two electric facilities, all located outside the city limits, remained intact. These surviving assets—including the recently established 4,000,000-foot crude oil gas plant at Potrero Generating Station—played a vital role in supporting San Francisco’s recovery efforts. While many competitors were forced to cease operations in the aftermath, PG&E’s robust financial resources allowed it to endure, reconstruct, and grow.

Sacramento Electric, Gas and Railway Company

In 1906, PG&E expanded its holdings by acquiring the Sacramento Electric, Gas and Railway Company, thereby assuming control over its rail transit operations surrounding Sacramento. Beginning in 1915, the Sacramento City Street Railway operated under PG&E management, extending both its routes and services. By 1931, PG&E’s Sacramento Street Railway Division operated 75 streetcars across an extensive track network. These streetcars were energized by PG&E’s hydroelectric facility located in Folsom. In 1943, PG&E divested the rail operations to Pacific City Lines (which was subsequently acquired by National City Lines), an entity that converted many streetcar routes into bus lines; this transition culminated in track abandonment by 1947.

During this era, Pacific City Lines and National City Lines—financially backed by General Motors, Firestone Tire, Standard Oil of California, Phillips Petroleum, and Mack Trucks—acquired numerous streetcar systems and rapidly replaced them with bus services. This group was convicted in 1949 for conspiracy to monopolize interstate commerce related to bus sales, an event commonly referred to as the Great American Streetcar Scandal.

Further consolidation and expansion

Soon after its formation, PG&E significantly broadened its footprint in Northern California’s hydroelectric sector by acquiring water storage and conveyance infrastructure originally developed for mining operations in the Sierra Nevada. By 1914, PG&E had become the largest integrated utility on the Pacific Coast, managing 26% of California’s combined electric and gas business across a territory spanning 37,000 square miles and encompassing 30 counties.

Throughout the 1920s, PG&E strategically pursued consolidation by acquiring major companies such as California Telephone and Light Company, Western States Gas and Electric Company, and Sierra and San Francisco Power Company—key suppliers of hydropower for San Francisco’s streetcar system. These acquisitions not only enhanced PG&E’s infrastructure but also expanded its customer base to nearly one million individuals across approximately 300 Northern California communities by 1927.

In 1930, PG&E secured controlling interests in Great Western Power and San Joaquin Light and Power Corporation from The North American Company through an exchange valued at $114 million in PG&E common stock. This transaction also included Midland Counties Public Service and Fresno Water Company (the latter was later divested). Although these utilities initially operated as separate entities, this consolidation enabled PG&E to deliver integrated service coverage to almost all of Northern and Central California.

Natural gas

The identification of large natural gas reserves in the American Southwest beginning in 1918 revolutionized the gas industry landscape. Natural gas offered a cleaner and more cost-effective alternative to manufactured gas. While Southern California enjoyed plentiful natural gas supplies, Northern California lacked affordable access. In 1929, PG&E constructed a 300-mile pipeline from the Kettleman oil field to San Francisco, enabling the city to become the first major metropolitan area to transition from manufactured gas to natural gas. This shift necessitated modifications to burners and airflow settings on approximately 1.75 million appliances. By 1936, PG&E extended its distribution network with a 45-mile pipeline originating in Milpitas, which allowed for the gradual decommissioning of its gas manufacturing facilities.

The surge in defense-related activities during World War II elevated natural gas consumption but also depleted California’s own reserves. To address this, in 1947 PG&E entered agreements with Southern California Gas Company and Southern Counties Gas Company to procure natural gas through a newly constructed 1,000-mile pipeline stretching from Texas and New Mexico to Los Angeles. Additionally, an arrangement with El Paso Natural Gas Company connected PG&E’s infrastructure to the Texas-Arizona border via a 502-mile main pipeline completed in 1951, linking directly to El Paso’s system.

Throughout this period of expansion, PG&E underwent regulatory examination by the Securities and Exchange Commission concerning its relationship with the North American Company. Although North American owned 17% of PG&E’s shares, PG&E contended that this minority stake did not amount to control since North American held only two seats on the board. The SEC investigation continued until 1945 when North American reduced its ownership below 10%, after which PG&E ceased to be classified as a subsidiary. By 1948, North American had divested all remaining holdings in PG&E.

Nuclear plants and gas pipelines

In 1957, PG&E inaugurated the Vallecitos Nuclear Center in Pleasanton, California, marking the debut of the first privately operated nuclear reactor in the United States. The facility generated 5,000 kilowatts, sufficient to supply electricity for a community of around 12,000 residents.

Simultaneously with its nuclear ventures, PG&E expanded its natural gas sourcing efforts. In 1959, it sought regulatory permission to import natural gas from Alberta, Canada into California through a pipeline developed by Westcoast Transmission Co. and Alberta and Southern Gas Company in Canada, alongside Pacific Gas Transmission Company—a PG&E subsidiary—in the U.S. The pipeline’s construction spanned 14 months, with operational testing commencing in 1961 and formal dedication occurring early in 1962.

Construction on the Diablo Canyon Power Plant began in 1968, initially targeting commercial operation by 1979. However, environmental opposition and safety issues delayed its commissioning. Testing phases started in 1984, with full power generation achieved by 1985.

During Diablo Canyon’s development, PG&E also sought new natural gas sources. In 1972, it proposed a 3,000-mile pipeline running from Alaska through the Mackenzie River Valley, designed to connect with Alberta’s existing pipeline system. The Mackenzie Valley Pipeline project received approval from the U.S. Federal Power Commission in 1977 and garnered support from the Carter Administration but was ultimately hindered by Canadian court rulings related to Indigenous land claims and environmental considerations.

In 1984, David Roe—great-grandson of founder George H. Roe and an environmental advocate affiliated with the Environmental Defense Fund—published Dynamos and Virgins. His work questioned prevailing assumptions about the necessity of expanding coal and nuclear power generation and promoted energy efficiency alongside alternative energy sources as practical strategies for addressing rising electricity demands.

1990s, Deregulation, and Industry Downturn

By the end of 1992, PG&E managed 173 electric generation units spread over 85 facilities, supported by 18,450 miles of transmission lines and a distribution network extending 101,400 miles.

In 1997, PG&E restructured into PG&E Corporation, a holding entity comprising two branches: one regulated utility and one non-regulated energy enterprise.

Amid the electricity market deregulation in the late 1990s, PG&E divested most of its natural gas-fired power plants but maintained ownership of hydroelectric assets, the Diablo Canyon nuclear facility, and select gas plants. This move diminished its generation capacity, compelling the company to purchase electricity at unstable market rates while continuing to sell to customers at fixed prices. Market manipulation by Enron and others caused artificial price inflation, leading to the California electricity crisis beginning in 2000 along Path 15—a transmission corridor constructed by PG&E.

Starting January 17, 2001, rolling blackouts were implemented due to severe power shortages.

Fires in the 1990s

In 1994, PG&E was held criminally liable for negligence in connection with the Trauner Fire in Nevada County, California, which destroyed several homes and a school.

A substation fire in San Francisco's Mission District in 1996 was attributed to PG&E's failure to maintain safe operations.

The Pendola Fire of 1999 burned nearly 12,000 acres across Plumas and Tahoe National Forests and was linked to inadequate vegetation control by PG&E.

Bankruptcy Filing in 2001

The California Public Utility Commission (CPUC) regulated PG&E’s customer rates from 1998 onward, requiring the company to supply all requested power at those fixed prices.

A drought in 2001 curtailed hydroelectric generation. Alongside delays in approving new plants and manipulative market practices—most notably by Enron—PG&E faced soaring wholesale electricity prices. Unable to increase consumer rates under CPUC mandates, the company suffered extensive financial losses.

PG&E Company filed for Chapter 11 bankruptcy protection on April 6, 2001. The state attempted a bailout under similarly restrictive pricing constraints but experienced substantial financial setbacks as well. The crisis inflicted estimated losses between $40 billion and $45 billion on both PG&E and California.

Emerging from bankruptcy in April 2004 after settling $10.2 billion with creditors, PG&E restructured with customers paying above-market electricity rates for several years to retire debt.

Timeline

Confronted with potential wildfire liabilities totaling approximately $30 billion from incidents occurring between 2015 and 2018, Pacific Gas and Electric Company (PG&E) initiated bankruptcy protection filings on January 14, 2019, providing a fifteen-day notice of intent. On January 29, PG&E Corporation—the parent entity—also sought bankruptcy protection. As unsecured creditors alongside bondholders, wildfire survivors faced low prospects for full compensation following secured and priority claims settlements. To qualify for California’s wildfire insurance fund established under AB 1054, PG&E was required to exit bankruptcy by June 30, 2020.

On August 16, 2019, U.S. Bankruptcy Judge Dennis Montali authorized an expedited state jury trial to determine liability for the Tubbs Fire; Cal Fire attributed fault to customer equipment while attorneys representing victims alleged PG&E equipment caused the fire. Although scheduled for January 7, 2020, this trial was superseded by the December 9 Restructuring Support Agreement (RSA) and the approved bankruptcy plan under which PG&E accepted responsibility.

Initially uncertain was PG&E’s liability for the October 23, 2019 Kincade Fire. Following PG&E’s exit from bankruptcy on July 16, 2020, Cal Fire confirmed that transmission lines owned by PG&E ignited the fire. Damages related to this event were excluded from the bankruptcy settlement.

In June and September of 2019 respectively, PG&E reached settlements totaling $1 billion with state and local governments and $11 billion with insurers and hedge funds. Wildfire victims asserted claims exceeding $54 billion; however, PG&E proposed an $8.4 billion compensation package covering damages as well as payments to Cal Fire and FEMA. Should PG&E be found liable for over 500 homes destroyed in the Kincade Fire, these settlements could be revisited. Subsequently, PG&E suggested a $13.5 billion fund dedicated to wildfire victim claims. FEMA initially sought $3.9 billion from this fund—overlapping with Cal OES’s claim of $2.3 billion—but ultimately settled for $1 billion after wildfire victims received payments.

Claims from wildfire victims encompassed wrongful death, personal injury, property damage, business interruption losses, and other damages. U.S. District Judge James Donato supervised valuation of these claims for inclusion in a trust fund; hearings commenced on February 18, 2020. Costs incurred by government agencies were excluded from this estimation due to precise accounting methods employed. The legal proceedings were eventually overtaken by the RSA and bankruptcy plan agreements.

On October 9, Judge Montali permitted consideration of a senior bondholders’ reorganization plan alongside PG&E’s own plan; this bondholders’ proposal had support from the wildfire victims’ committee valuing claims at $13.5 billion. This plan would have granted control of the company to bondholders at shareholders’ expense—a scenario PG&E described as an "unjustified windfall." Later negotiations resulted in settlements between PG&E, bondholders, and victims’ committee that allowed only PG&E’s plan to move forward without bondholder control.

On November 12, PG&E augmented its wildfire victim compensation offer by $6.6 billion to reach a total of $13.5 billion—matching bondholders’ valuation. Securities filings revealed total fire-related claims amounting to $25.5 billion: $11 billion owed to insurers and investment funds; $1 billion owed to governmental entities; and $13.5 billion allocated for other claims. The $11 billion insurer settlement faced opposition from Governor Gavin Newsom as well as the wildfire victims’ committee; nevertheless both parties eventually endorsed the reorganization plan.

On December 6, PG&E presented a $13.5 billion settlement addressing liabilities associated with multiple fires including Camp Fire, Tubbs Fire, Butte Fire, Ghost Ship warehouse fire (not a wildfire), and various October 2017 Northern California wildfires. Wildfire victims were slated to receive half their settlement as shares in the reorganized company—introducing uncertainty regarding timing and amounts of actual payments. Amid COVID-19 market disruptions on June 12, 2020, PG&E increased stock allocations for wildfire claimants; payments comprised cash portions plus stock liquidated over time at undetermined prices.

On December 17, Judge Montali allowed litigation related to the Ghost Ship warehouse fire (distinct from wildfires) to proceed; this case draws upon separate insurance funds valued at approximately $900 million apart from wildfire settlements. On August 18, 2020, PG&E reached undisclosed settlements with families representing most victims of that fire within limits set by insurance coverage applicable at that time.

On June 16, 2020, PG&E entered guilty pleas on eighty-four counts of involuntary manslaughter connected with the Camp Fire; it agreed to pay up to $3.5 million in fines and concluded criminal proceedings but remains subject to civil lawsuits outside bankruptcy protections.

U.S. Bankruptcy Judge Dennis Montali approved PG&E’s reorganization plan on June 20—meeting the June 30 deadline necessary for qualification into California’s wildfire insurance fund program. On July 1, PG&E funded the Fire Victim Trust with $5.4 billion in cash plus a roughly twenty-two percent ownership stake in reorganized PG&E stock to satisfy most obligations owed to wildfire claimants; two additional payments totaling approximately $1.35 billion are scheduled for January of both 2021 and 2022 to complete these commitments.

Additional details

Following the departure of CEO Geisha Williams on January 14, 2019, PG&E declared Chapter 11 bankruptcy, citing financial difficulties stemming from the Northern California wildfires of 2017 and 2018. The subsequent day, January 15, the company failed to make a $21.6 million interest payment on its 5.40% Senior Notes maturing in 2040, resulting in a default after the grace period expired on February 14.

PG&E officially filed for bankruptcy protection on January 29, 2019, with its disclosure statement receiving court approval on March 17, 2020. The company holds 32 bond series totaling approximately $17.5 billion. The restructuring was anticipated to span two years. In April 2019, Governor Gavin Newsom expressed disapproval of proposals to appoint new board members lacking experience in California utilities.

That same month, PG&E named Bill Johnson—previously CEO of Progress Energy Inc and Tennessee Valley Authority—to lead the company through the bankruptcy process as its new CEO. On November 1, 2019, Governor Newsom urged PG&E to achieve a "consensual resolution" during bankruptcy proceedings or face potential state intervention. He attributed wildfire hazards and power outages to PG&E’s "greed and mismanagement."

A customer-owned cooperative proposal spearheaded by San Jose Mayor Sam Liccardo garnered backing from over 110 elected officials representing the majority of PG&E’s customer base, including 21 mayors. In September 2019, San Francisco made a $2.5 billion bid to acquire PG&E’s electrical infrastructure within the city limits; this offer was declined by PG&E.

In March 2020, PG&E petitioned the court for authorization of $454 million in bonuses for employees and executives shortly after requesting permission to hire additional tree trimmers as part of compliance with criminal probation stemming from the 2010 San Bruno pipeline explosion.

As part of its emergence from bankruptcy, PG&E agreed to compensate wildfire victims with $13.5 billion—half of which was paid in company stock—leading to nearly 70,000 claimants collectively owning about 22% of the enterprise. This event marked the largest utility bankruptcy in U.S. history and one of the most intricate restructurings.

In November 2020, Patti Poppe was appointed CEO effective January 2021. By April 2022, her total remuneration for 2021 surpassed $50 million, predominantly composed of stock-based awards.

In June 2020, PG&E revealed plans to gradually relocate its headquarters from San Francisco to Oakland’s Kaiser Center between 2022 and 2026.

In December 2024, the U.S. Department of Energy extended a $15 billion loan to PG&E aimed at expanding hydropower capacity and battery storage, enhancing transmission capabilities through reconductoring and grid-boosting technologies, and facilitating virtual power plants across its service territory. This loan represents the largest commitment ever made by the DOE’s Loan Programs Office.

Generation portfolio

PG&E’s portfolio of utility-owned generation assets consists of an extensive hydroelectric network, one active nuclear power facility, one operational natural gas-fired plant, and an additional gas-fired station currently under construction. Two plants have been permanently shut down: Humboldt Bay Unit 3 (nuclear) and Hunters Point (natural gas).

Hydroelectric

As the largest private hydroelectric facility owner in the United States, PG&E manages 174 dams. According to its 2011 Form 10-K filing, its hydroelectric operations encompass 110 generating units spread across 68 powerhouses—including the Helms pumped storage plant—with a combined capacity of 3,896 MW. The system incorporates 99 reservoirs, 56 water diversions, a total of 174 dams, along with 172 miles of canals complemented by extensive tunnels and pipelines.

The Helms Pumped Storage Plant near Sawmill Flat in Fresno County stands out as the largest asset within this system. It consists of three generating units rated at 404 MW each for a total capacity of 1,212 MW. This facility operates between Courtright and Wishon reservoirs by producing electricity during peak demand periods through water release from Courtright reservoir and subsequently pumping it back from Wishon reservoir when demand is low. The Haas Powerhouse is situated over a thousand feet inside a granite mountain.

Nuclear

PG&E’s only active nuclear facility is the Diablo Canyon Power Plant located in Avila Beach, California, which has a combined capacity of 2,240 MWe generated by its two reactors. The original design included provisions for expanding to four reactors, potentially doubling its output. In 1981, protests against Diablo Canyon led to the arrest of 1,900 demonstrators, marking the largest single mass arrest in the history of the U.S. anti-nuclear movement.

In June 2016, PG&E revealed intentions to retire Diablo Canyon by 2025, which would result in the loss of 2,256 MW of generation capacity producing more than 18,000 GWh annually and effectively ending commercial nuclear power generation in California.

PG&E also formerly operated the Humboldt Bay Power Plant, Unit 3 near Eureka, California, recognized as California’s oldest commercial nuclear facility with a capacity of 65 MWe. It was in service for 13 years until its shutdown in 1976 for seismic upgrades. Subsequent regulatory changes following the Three Mile Island incident rendered the plant economically unviable, preventing its restart; decommissioning efforts are projected to complete by 2019.

The company had initially proposed constructing the first commercially feasible nuclear plant in the United States at Bodega Bay, north of San Francisco. Beginning in 1958, this initiative encountered strong local resistance and large-scale protests by 1963. Due to persistent community opposition, the project was ultimately canceled in 1964.

Combustion

Constructed in 1956, two units fueled by natural gas and fuel oil at the Humboldt Bay Power Plant delivered a total output of 105 MWe. These units were retired in 2010 alongside two Mobile Emergency Power Plants (MEPPs) each rated at 15 MWe. They were succeeded by the Humboldt Bay Generating Station on the same site, which generates 163 MWe utilizing natural gas with fuel oil as backup through Wärtsilä Diesel engines. This new plant achieves a 33% efficiency improvement, reduces ozone-forming emissions by 85%, and lowers greenhouse gas emissions by 34%. Its closed-loop cooling system eliminates water withdrawal from Humboldt Bay.

Following a settlement agreement with Mirant Services LLC related to alleged market manipulation during the 2001 California electricity crisis, PG&E acquired a partially constructed natural gas facility in Antioch, California. PG&E completed this project as the Gateway Generating Station with a capacity of 530 MW, which commenced operations in 2009.

On May 15, 2006, PG&E permanently closed its Hunters Point Power Plant in San Francisco, ending operations after nearly five decades amid sustained political opposition.

In 2008, PG&E began construction of a 660 MW natural gas power plant located in Colusa County that started operating in December 2010. This facility supplies electricity to nearly half a million homes and incorporates dry cooling technology to minimize water consumption. Additionally, it employs advanced turbines that reduce CO₂ emissions by approximately 35% compared to older generation units.

Solar

On April 1, 2008, PG&E announced agreements to procure electricity from three newly developed solar power plants in the Mojave Desert totaling an initial capacity of 500 MW with options for an extra 400 MW. These solar arrays initially produce sufficient energy to meet the needs of over 375,000 households.

In April 2009, PG&E requested authorization from the California Public Utilities Commission for a project led by company Solaren aiming to supply 200 MW of solar-generated power from space-based platforms. This innovative approach seeks to address the issue of solar energy unavailability during nighttime hours at terrestrial sites. PG&E noted that the cost of this energy would be competitive with other renewable energy contracts.

PG&E and Environmental Initiatives

Starting in the mid-1970s, shifts in regulatory and political landscapes prompted California utilities to move away from conventional operational frameworks. In 1976, the California Legislature revised the Warren–Alquist Act, empowering the California Energy Commission with the authority to effectively block the construction of new nuclear power facilities. During PG&E's 1978 General Rate Case, the Environmental Defense Fund (EDF) intervened, disputing PG&E’s requested rate hikes due to overstated load growth forecasts and advocating for economically viable industrial cogeneration alongside enhanced energy efficiency measures. As a result, the California Public Utilities Commission imposed a $50 million penalty on PG&E for inadequate implementation of energy-saving programs.

In the early 2000s, PG&E Corporation’s CEO Peter Darbee and Pacific Gas & Electric Company’s CEO Tom King endorsed California Assembly Bill 32, which sought to cap greenhouse gas emissions statewide and reduce them by 25% by 2020. Governor Arnold Schwarzenegger enacted this legislation in 2006.

By 2014, renewable energy sources constituted 28% of PG&E's portfolio, rising to 32.9% in 2016. In 2017, PG&E announced that 80% of its electricity supply was derived from sources free of greenhouse gas emissions—including renewables, nuclear power, and hydropower—with renewables alone comprising roughly one-third of total supply. This achievement allowed PG&E to meet California’s 2020 renewable energy targets nearly three years ahead of schedule.

PG&E submitted its Wildfire Safety Plan to the California Public Utilities Commission in February 2019, detailing strategies to mitigate wildfire risks linked to electrical infrastructure. Since then, the company has escalated its preventative measures and climate resilience initiatives in response to increasing extreme weather events.

In June 2020, PG&E embarked on a year-long research partnership with SoCalGas and Twelve aimed at transforming raw biogas into carbon-neutral methane. This project focuses on generating renewable fuel from waste sources such as landfills, sewage treatment facilities, and dairy farms by utilizing wind and solar energy inputs.

Carbon Emissions

For the twelve months ending December 31, 2019, Pacific Gas and Electric Company reported total CO2e emissions (combining direct and indirect sources) of 4,510 kilotonnes, marking a 1.3% reduction compared to the previous year.

Annual Total CO2e Emissions for Pacific Gas and Electric Company – Location-Based Scope 1 + Scope 2 (kilotonnes)

Dec 2016	Dec 2017	Dec 2018	Dec 2019
4,950	4,650	4,570	4,510

Native American Opposition

In 1970, the Pit River Tribe initiated a boycott against PG&E, asserting ownership over lands utilized by the company and demanding entitlement to revenue shares. The movement received backing from supporters including musician Buffy Sainte-Marie, who contributed boycott funds directly to the tribe.

Chromium Contamination in Hinkley, California

Between 1952 and 1966, PG&E released about 370 million gallons of wastewater containing chromium-6 into unlined evaporation ponds near Hinkley, California. Chromium-6 was employed as a corrosion inhibitor within cooling towers at PG&E’s compressor stations along natural gas pipelines but was not disclosed to local authorities until 1987, which delayed cleanup efforts.

Residents affected by this contamination filed a landmark lawsuit that culminated in a $333 million settlement—the largest direct-action payout in U.S. legal history. This case inspired the widely known film Erin Brockovich and attracted global attention.

At CalEPA’s request in 2001, the Chromate Toxicity Review Committee evaluated chromium-6 toxicity; however, experts influenced by PG&E shaped the report to minimize perceived risks and recommended academic oversight rather than regulatory action. By 2014, California became the first state to classify ingested chromium-6 as carcinogenic and established a maximum contaminant level (MCL) of 10 parts per billion.

By 2013, PG&E had remediated contamination across 54 acres but anticipated that cleanup operations would extend over four more decades. Remediation methods included constructing a half-mile concrete barrier to contain the contaminant plume, injecting ethanol to chemically reduce chromium-6 into less toxic chromium-3, and cultivating alfalfa irrigated within the desert zone—though these agricultural activities were later restricted due to inhalation hazards.

In 2015, as the contamination plume expanded to approximately eight miles in length and two miles in width affecting new territories, California’s Regional Water Quality Control Board issued an order mandating further cleanup actions. By early 2016, property devaluation linked to pollution had nearly depopulated Hinkley.

A report authored by epidemiologist John Morgan in 2010 for the California Cancer Registry concluded there was no cancer cluster associated with chromium-6 exposure in Hinkley between 1988 and 2008, noting cancer incidence rates below regional expectations. However, a subsequent investigation by the Center for Public Integrity in 2013 revealed significant methodological flaws in Morgan’s analysis—including omission of heavily exposed individuals—and challenged his dismissal of evidence indicating an actual cancer cluster.

Metcalf sniper attack

On April 16, 2013, armed assailants targeted the Metcalf transmission substation located in Coyote, California. Their assault damaged 17 high-voltage transformers, inflicting losses exceeding $15 million. Additionally, they severed an AT&T fiber-optic cable. PG&E and AT&T jointly offered a $250,000 reward for information that would lead to the apprehension of those responsible; however, the culprits were never identified. The FBI dismissed the possibility of domestic terrorism, while the Department of Homeland Security indicated the incident might have involved an insider.

Wildfires

PG&E equipment has been repeatedly implicated in igniting wildfires across California, resulting in multiple findings of criminal negligence. Significant events include the Trauner Fire in 1994, Pendola Fire in 1999, Sims and Fred's Fires in 2004, the San Bruno pipeline explosion in 2010, the Carmel Gas Explosion in 2014, the Butte Fire in 2015, and the Camp Fire in 2018. In 2012, PG&E resolved forest-fire-related lawsuits with a $29.5 million settlement.

Between 2017 and 2018, around 40 out of 315 wildfires within PG&E’s service territory were attributed to its equipment. Following its criminal liability determination for the San Bruno fire, PG&E operated under probation. A federally appointed monitor expanded oversight from gas infrastructure to include electricity distribution after the fires of 2017. Furthermore, PG&E faced accusations of falsifying gas pipeline documentation spanning from 2012 to 2017.

California law mandates that PG&E submit wildfire prevention plans annually. The 2019 submission received conditional approval accompanied by recommendations to improve performance metrics and strengthen collaboration with local authorities. Regulators also proposed considering temporary power shutdowns to mitigate wildfire risks during high-danger periods. PG&E filed a request to modify certain deadlines within this plan, with a decision pending as of May 2019.

Liability

California’s wildfire liability framework is based on the principle of "inverse condemnation", which holds utilities accountable for damages caused by fires linked to their equipment regardless of maintenance or negligence. This strict liability approach resulted in PG&E facing approximately $30 billion in liabilities related to the fires of 2017 and 2018, ultimately contributing to the company’s bankruptcy.

In July 2019, a $21 billion wildfire trust fund was created to address future wildfire-related claims. This fund is financed equally by utilities and their customers and reduces utilities’ exposure by requiring customers to demonstrate negligence before holding companies liable. Serving as a secondary insurance mechanism, it alleviates investor concerns about overwhelming liabilities threatening California’s energy sector. Utilities contribute $10.5 billion through ongoing customer fees, which helps prevent direct rate increases by covering wildfire costs beyond insurance limits. Additionally, regulatory proceedings now place the burden on external parties to prove utility mismanagement when seeking liability.

Undergrounding

By 2019, California’s public utilities managed roughly 26,000 miles of high-voltage transmission lines and about 240,000 miles of distribution lines; approximately two-thirds of distribution lines remain overhead. Converting transmission lines to underground systems costs near $80 million per mile, while undergrounding distribution lines runs around $3 million per mile compared with $800,000 per mile for overhead lines.

PG&E—the state’s largest utility—operates approximately 107,000 miles of distribution lines, with about 81,000 miles above ground. Fully converting all overhead distribution lines to underground would require an estimated investment of $240 billion or roughly $15,000 per PG&E customer. This figure excludes the higher-voltage transmission infrastructure.

In July 2021, PG&E unveiled plans to bury an additional 10,000 miles of distribution lines over a decade—representing about a 9% increase beyond the existing one-quarter underground—to mitigate wildfire hazards. Presently, PG&E maintains approximately 27,000 miles underground, mostly outside designated high fire-risk areas. Nationally, around 18% of distribution lines are underground due to evolving standards for new residential and commercial developments.

This initiative is projected at $4 million per mile totaling $40 billion; however, PG&E’s CEO aims to reduce expenses to between $15 billion and $20 billion. These costs are expected to be passed on to PG&E’s customer base of 5.5 million—already among those facing some of the highest electricity rates nationwide.

Sierra blaze

On June 19, 1997, a jury in Nevada County determined that PG&E was culpable for "a series of tree-trimming violations" that led to a destructive wildfire in the Sierra region in 1994. The utility was found guilty on 739 counts of criminal negligence due to its failure to properly trim trees near power lines—marking the most significant criminal conviction against California's largest utility company.

San Bruno, California explosion

On September 9, 2010, a natural gas pipeline installed by PG&E in 1956 ruptured and exploded in San Bruno, California, resulting in eight fatalities, nearly fifty injuries, and the destruction of approximately 100 homes. The explosion produced a crater and a shockwave comparable to a 1.1 magnitude earthquake. The company faced severe criticism for disregarding warnings issued by a state inspector in 2009 and for insufficient safety protocols. The National Transportation Safety Board (NTSB) attributed fault to PG&E for operating a pipeline that failed to meet even the safety standards applicable at the time of installation.

PG&E faced twelve felony charges related to violations of the Natural Gas Pipeline Safety Act. The company entered a plea of not guilty and opted to challenge the accusations. On April 1, 2014, a federal grand jury indicted PG&E on charges of "knowingly and willfully" breaching pipeline safety regulations.

In August 2015, the California Public Utilities Commission imposed a $300 million fine on PG&E, which the utility paid. Additionally, PG&E reimbursed $400 million to gas customers, allocated $850 million toward gas system safety enhancements, and settled more than $500 million in claims with victims and their families.

Despite these efforts, PG&E did not fully comply with mandated safety procedures from 2012 through 2017. A CPUC investigation revealed that staffing shortages caused delays in locating and marking pipelines, with management potentially misrepresenting tens of thousands of overdue tickets as completed punctually—information vital for contractor safety. These violations resulted in an extra $110 million fine against PG&E.

Butte Fire

In September 2015, the fatal Butte Fire broke out across Amador and Calaveras counties, claiming two lives and destroying hundreds of buildings. Investigations attributed responsibility to PG&E after a gray pine tree came into contact with one of their power lines.

October 2017 Northern California wildfires

During October 2017, PG&E equipment was linked to thirteen out of approximately 250 fires that severely impacted Northern California. These incidents originated from failures involving electric power lines, conductors, and poles. The confirmed fires connected to PG&E include:

• Redwood Fire in Mendocino County
• Sulphur Fire in Lake County
• Cherokee Fire in Butte County
• 37 Fire in Sonoma County
• Blue Fire in Humboldt County
• Pocket Fire in Sonoma County
• Atlas Fire in Napa County
• Norrbom, Adobe, Partrick, Pythian, and Nuns fires across Sonoma and Napa counties
• Cascade Fire in Yuba County

Ghost Ship fire

On December 2, 2016, a blaze erupted at the illegally converted Ghost Ship warehouse in Oakland during an event attended by between 80 and 100 people, resulting in 36 fatalities. Plaintiffs contend that the fire originated from an electrical malfunction associated with PG&E equipment. In August 2020, PG&E reached a civil settlement with families of 32 victims for an undisclosed sum limited to the utility’s insurance coverage from 2016.

Tubbs Fire

The Tubbs Fire, which occurred in Northern California in October 2017, was at that time the most devastating wildfire in the state’s history. It affected Napa, Sonoma, and Lake counties, with Santa Rosa suffering the most extensive destruction. While initial allegations pointed to PG&E as the cause, a Cal Fire investigation released in January 2019 exonerated the utility company, leading to a significant rise in PG&E’s stock price.

In August 2019, U.S. Bankruptcy Judge Dennis Montali approved an expedited civil trial to assess PG&E’s liability for the Tubbs Fire concurrently with ongoing bankruptcy proceedings. This decision resulted in a 25% decline in PG&E's share value.

On December 6, 2019, PG&E put forward a $13.5 billion settlement offer addressing claims related to the Tubbs Fire, Camp Fire, Butte Fire, and other 2017 North Bay wildfires as part of its bankruptcy restructuring plan. This agreement and the confirmed reorganization plan acknowledged PG&E’s responsibility for the Tubbs Fire.

Camp Fire

In November 2018, lawsuits were filed against PG&E and its parent company in San Francisco County Superior Court by victims of the Camp Fire, recognized as California’s deadliest wildfire. The fire destroyed more than 18,000 structures, including approximately 14,000 residences, disproportionately affecting low-income communities. By June 2020, nearly 90% of Paradise, California’s residents remained displaced. The complaints accused PG&E of neglecting proper maintenance of its infrastructure.

PG&E’s "electric incident report" submitted to the California Public Utilities Commission revealed a power outage on a transmission line minutes before the fire ignited. Investigations suggested that a broken hook might have caused energized equipment to arc and start the fire.

The California Department of Forestry and Fire Protection along with state regulatory agencies examined PG&E’s adherence to relevant state regulations.

Subsequent to these developments, PG&E and its parent entity filed for Chapter 11 bankruptcy on January 29 following California’s mandatory waiting period. PG&E resolved criminal charges by pleading guilty to one felony count related to causing the fire and 84 counts of involuntary manslaughter, accompanied by fines.

Civil litigation was settled through negotiated agreements. On July 1, 2020, PG&E established the Fire Victim Trust with $5.4 billion in cash plus a 22.19% equity stake in reorganized PG&E stock to cover most wildfire-related claims. Additional payments amounting to $1.35 billion were scheduled for disbursement in January 2021 and January 2022 to fulfill remaining obligations.

Kincade Fire

The Kincade Fire ignited near Geyserville, California at 9:24 p.m. on October 23, 2019, within Sonoma County, California. It consumed and was fully contained by November 6, 2019. The blaze posed threats to over 90,000 buildings and necessitated extensive evacuations across Sonoma County including communities such as Geyserville, Healdsburg, and Windsor. Evacuation warnings extended into large portions of Sonoma County as well as parts of Lake County. This event marked the largest wildfire during the 2019 wildfire season.

Initially uncertain about PG&E’s role in causing this fire; however, on July 16, 2020—after emerging from bankruptcy—Cal Fire attributed the origin of the Kincade Fire to PG&E transmission lines. Damages from this fire were excluded from the wildfire victim settlement established during PG&E’s bankruptcy process.

Public safety power shutoff

In response to the devastating wildfire season of 2017, the CPUC adopted Resolution ESRB-8 in July 2018, endorsing power de-energization as a wildfire risk mitigation measure and establishing protocols for notification and reporting. PG&E implemented its inaugural Public Safety Power Shutoff (PSPS) from October 14 to 16, 2018, with subsequent PSPS events occurring in June and throughout the summer of 2019.

During October 2019, PG&E preemptively disconnected electricity in numerous areas to reduce wildfire risks linked to electrical infrastructure. This action impacted over 2 million individuals out of PG&E’s total customer base of 16 million, spanning nearly of the utility’s electrical network. Power outages persisted for several days following high wind events to facilitate safety inspections. Two days after the shutdown began, calmer winds allowed restoration of electricity to roughly 500,000 of the approximately 800,000 affected customers.

Since initiating PSPS measures in 2018, PG&E has bolstered its wildfire prevention program by creating a round-the-clock threat monitoring center, increasing vegetation clearance around utility poles from four to fifteen feet, and deploying an additional 100 weather stations in areas deemed high-risk. Their approach incorporates selective PSPS deployments when conditions warrant.

Power interruptions continued into 2020 and 2021. In the latter year, PG&E incorporated machine learning algorithms into PSPS decision processes to enhance fire spread forecasting and optimize power shutdown strategies.

In 2021, California imposed a $106 million penalty on PG&E for insufficient public communication during the PSPS events of 2019. Violations cited included website outages during PSPS periods, inaccurate outage mapping, restricted access to data portals for safety partners, and failure to provide advance notification to nearly 50,000 customers—including those with medical baseline needs—prior to power interruptions.

Dixie Fire

On January 4, 2022, CalFire attributed the origin of the Dixie Fire to a tree making contact with electrical distribution lines owned and operated by Pacific Gas and Electric (PG&E) near Cresta Dam. The investigative findings were submitted to the Butte County District Attorney's office, which had previously prosecuted PG&E following the 2018 Camp Fire.

Zogg Fire

The Zogg Fire consumed 56,338 acres across southwestern Shasta County and northwestern Tehama County during California’s 2020 wildfire season. First reported on September 27, 2020, and contained by October 13, it devastated much of Igo and Ono communities, resulted in four fatalities, and destroyed 204 structures. A March 2021 investigation determined that the fire was ignited when a grey pine tree fell onto PG&E power lines. Although this tree had been marked for removal after the 2018 Carr Fire, it had not been cut down.

Community Pipeline Safety Initiative (CPSI)

In 2014, PG&E initiated the Community Pipeline Safety Initiative (CPSI), committing $500 million over four years to clear vegetation along nearly 7,000 miles of high-pressure gas transmission pipelines throughout California. The utility asserted that removing trees was essential for emergency access and safeguarding pipelines from root intrusion. However, numerous communities opposed the removal of both private and public trees. Critics contend that PG&E’s safety justifications are flawed and suggest that tree clearing primarily facilitates more cost-effective aerial pipeline inspections.

In Contra Costa County in 2017, the non-profit Save Lafayette Trees filed lawsuits alleging that PG&E neglected proper compliance with the California Environmental Quality Act and failed to provide adequate public notice before entering agreements for tree removal.

Statewide tree clearing activities by PG&E may have inadvertently heightened risks associated with stress corrosion cracking (SCC). According to PG&E’s own research, pipeline coatings damaged by tree roots can increase SCC susceptibility. Additionally, decomposing roots may elevate soil carbon dioxide levels, thereby accelerating corrosion on pipe surfaces.

Smart meters

In 2010, PG&E rolled out electronic smart meters to replace the older mechanical versions. Some customers observed spikes in their energy bills and questioned the accuracy of these new meters, suspecting PG&E of inflating charges. An investigation by the California Public Utilities Commission tested 613 smart meters, with 611 meeting accuracy requirements. Two meters were excluded: one was faulty upon delivery, and the other experienced event-related errors. Moreover, certain customers who opted to retain mechanical meters reported that PG&E eventually replaced them regardless of prior assurances from contractors.

Proposition 16

During 2010, PG&E drew criticism for supporting Proposition 16, which sought to mandate a two-thirds voter majority to establish or expand local utility providers. Critics contended that this measure would hinder municipal governments from forming their own power utilities, thereby safeguarding PG&E’s dominant market position. PG&E invested $46 million to promote the proposition, while opposition groups raised merely $100,000. The measure was ultimately rejected by 52.5% of voters.

Tax dodging and lobbying

In December 2011, the nonpartisan organization Public Campaign condemned PG&E for allocating $79 million toward lobbying efforts and avoiding income taxes between 2008 and 2010 despite generating $4.8 billion in profits. During this timeframe, PG&E received $1 billion in tax rebates and increased the compensation of its top five executives by 94%, reaching $8.5 million in 2010.

Restatements

On February 28, 2002, in the aftermath of Enron’s collapse due to dubious accounting practices, PG&E announced it would restate financial results dating back to 1999 to incorporate previously excluded off-balance-sheet leases associated with power plant construction.

On June 27, 2003, PG&E National Energy Group amended its 2002 Form 10-K/A by reclassifying certain offsetting revenues and expenses that netted zero impact, thereby updating its 2002 financial disclosures accordingly.

Collusion with regulatory agencies

A state investigation in California during 2014 uncovered that PG&E executives engaged in frequent communications with senior officials at the California Public Utilities Commission (CPUC) over multiple years. This raised suspicions of regulatory collusion and alleged "judge shopping." As a consequence of the email scandal, PG&E terminated Vice President of Regulatory Affairs Brian Cherry, Senior Vice President Tom Bottorff, and Vice President of Regulatory Proceedings Trina Horner.

Rates

PG&E operates as a regulated monopoly in California with a guaranteed negotiated fair return on equity (ROE) fixed at 10.4%, and a return on rate base (ROR) set at 8.06% by the CPUC as of December 2012. The company’s electricity prices are among the highest nationwide. Jonathan Cook from UC Davis attributed this partly to PG&E sourcing approximately 60% of its electricity from third-party producers and the remaining 40% from its own nuclear, fossil fuel, and hydroelectric facilities. Many hydroelectric dams were constructed in the early 20th century and demand expensive upkeep costs projected to increase from $28 million in 2012 to $48 million. Capital investments are heavily concentrated on Diablo Canyon Power Plant and hydroelectric infrastructure, while operations and maintenance expenses have risen due to regulations implemented after Fukushima. PG&E’s relatively lower dependence on natural gas might help temper future rate increases amid escalating emission allowance costs.

By 2021, PG&E’s electricity rates stood roughly 80% above the national average, driven primarily by high fixed costs—which account for between 66% and 77% of total system expenses—covering maintenance, generation, transmission, distribution, and wildfire prevention efforts. Research conducted by Next 10 and UC Berkeley's Haas Business School indicated that net-metering policies contribute to elevated rates because solar-powered households often fail to cover their portion of fixed system costs despite significant reliance on the grid for electricity needs.

"Locate and Mark" Investigation

In December 2018, the California Public Utilities Commission (CPUC) launched an inquiry into PG&E's "locate and mark" procedures after uncovering that the company had fabricated tens of thousands of "Call Before You Dig" records. Between 2012 and 2016, PG&E breached state regulations, putting both workers and local residents at risk through these actions, which culminated in a $110 million penalty. This investigation followed the 2010 San Bruno pipeline explosion, which was similarly attributed to negligent practices. In response, PG&E introduced a "Corrective Action Plan," prioritized safety enhancements, and dismissed multiple employees. COO and president Nick Stavropoulos stepped down during this period, although the firm did not explicitly link his retirement to the CPUC’s findings.

Largest loan from US Department of Energy

In December 2024, the Loan Programs Office of the U.S. Department of Energy granted PG&E a $15 billion low-interest loan aimed at modernizing its hydroelectric assets and enhancing transmission infrastructure essential for integrating renewable energy sources, data centers, and electric vehicle support. Although PG&E initially requested $30 billion, the amount was scaled back due to concerns about repayment capacity. This unprecedented DOE loan serves as a crucial financial resource while PG&E navigates ongoing bankruptcy proceedings and wildfire-related litigation.

South San Joaquin Irrigation District (SSJID)

The California Public Utilities Commission (CPUC) authorized the South San Joaquin Irrigation District (SSJID) in 2009 to acquire PG&E’s electric facilities serving Manteca, Ripon, and Escalon. In March 2016, San Joaquin County Superior Court Judge Carter Holly dismissed PG&E’s argument that SSJID lacked adequate revenue to supply retail electricity to these municipalities and adjacent agricultural areas. The Municipal Service Review (MSR) determined that SSJID’s customer rates would be approximately 15% lower than those charged by PG&E, underscoring notable cost advantages within SSJID’s service zones.

See also

• Diablo Canyon Power Plant
• Erin Brockovich
• Hinkley groundwater contamination
• Grid-tied electrical system
• List of articles associated with nuclear issues in California
• Raker Act
• San Diego Gas & Electric
• Southern California Edison