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PECO Energy Company
PECO Energy Company
PECO Energy Company
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PECO, formerly the Philadelphia Electric Company, is an energy company founded in 1881 and incorporated in 1929.[1] It became part of Exelon Corporation in 2000 when it merged with Commonwealth Edison's holding company Unicom Corp.

Key Information

The company has approximately 2,300 employees; its call center and field craft personnel are members of IBEW Local 614. PECO serves about 1.6 million electric and over 511,000 natural gas customers; it is the largest combination utility in Pennsylvania, and has a franchise utility service area of 2,100 square miles (5,400 km2) with a population of 3.8 million people.

Electricity and natural gas

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PECO operates in southeastern Pennsylvania and provides electricity to about 1.6 million customers and natural gas to over 511,000 customers. The company's electric service area covers all of the city of Philadelphia and Delaware County; most of Bucks, Chester, and Montgomery counties; and the southeastern corner of York County. The company's natural gas service area covers all of Delaware County; most of Bucks, Chester, and Montgomery counties; and a small portion of eastern Lancaster County.[2]

PECO formerly provided electricity to 35,000 customers in portions of Cecil and Harford counties in Maryland through subsidiary Conowingo Power Company.[3] On June 19, 1995, Delmarva Power acquired the Conowingo Power Company service area from PECO.[4]

PECO's distribution line voltages are 2,400/4,160 volts wye and 7,620/13,200 volts wye. Subtransmission voltages are 34,500 volts and 69,000 volts. Transmission line voltages are 138,000 volts, 230,000 volts and 500,000 volts. The company is a member of the PJM Interconnection.

As of 2012 PECO's peak electric load occurred on July 22, 2011 and was 8,983 megawatts (MWs) and its highest peak load in the winter season occurred on December 20, 2004 and was 6,838 MW.[5] Residential electric usage makes up about 35 percent of PECO's total electric delivery and half of the annual electric revenue.

PECO's electric sales tend to peak in the summer and winter seasons, driven by air conditioning and heating load respectively when extreme temperatures create greater demand. The company's natural gas sales are generally higher during the winter periods when cold temperatures create demand for heating. The company's highest gas sales occurred on January 17, 2000 and was 718 million cubic feet (20.3 million cubic metres) of gas.[5] Gas usage by residential customers is approximately half of PECO's total deliveries.

The PECO transition period for the competitive electric generation market ended on Dec. 31, 2010, when caps on retail rates and competitive transition charges on customer bills ended. PECO electric rates had been capped for 12 years. PECO expects to purchase all of its wholesale electricity from competitive market sources subsequent to 2010 with retail customers charged the actual costs of procurement.

According to Exelon SEC Form 10-k for the year 2012: nuclear energy supplied 53% of power supplied, fossils and renewables provided 12% of power supplied, and purchased power provided 35% of power supplied.

Facilities and infrastructure

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Secretary of Energy Ernest Moniz, Mayor Michael Nutter, and Vice President Joe Biden visiting PECO's headquarters in 2015

PECO owns, maintains, and operates:

  • 1,067 miles (1,720 km) of higher-voltage transmission lines
  • 15,260 square miles (39,500 km2) of underground electrical distribution cable
  • 12,933 miles (20,810 km) of aerial electrical distribution lines
  • 12,157 miles (19,560 km) of natural gas transmission, distribution and service piplines.

PECO has a liquefied natural gas storage facility in West Conshohocken, PA. with capacity of 1,200,000,000 cubic feet (34,000,000 m3) and a propane-air plant in Chester, PA. with storage capacity of 1,980,000 US gallons (7,500 m3). The company also owns 29 natural gas city gate stations at locations that link with various interstate pipelines.

The Chester Waterside Station of the Philadelphia Electric Company was constructed in 1916 and listed on the National Register of Historic Places in 2007.[6]

PECO supplies legacy two-phase electric power[7] to sections of Philadelphia where infrastructure upgrades are impracticable. Philadelphia is one of only two cities with in-service two-phase infrastructure.[8]

Revenues

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PECO's total assets are valued at $9.8 billion. The company delivered 87,700,000,000 cubic feet (2.5×109 m3) of natural gas and 39.5 billion kilowatt-hours of electricity in 2008, generating $5.5 billion in revenue.

PECO's utility business is capital intensive and requires significant investments for the electric and gas delivery systems to ensure adequate capacity and reliability for customers. PECO's anticipated capital expenditures for 2009 are estimated at $400 million—about three-fourths for the electric business, nearly 20 percent for gas, and the rest is common. The company pays about $510 million in local, state and federal income and other taxes annually.

Controversies

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In the 1970s through the 1980s, community activist pressure contributed to the delayed opening of nuclear power plants at PECO's Limerick Generating Station and the temporary cancellation of the planned Limerick 2 nuclear power plant, Pennsylvania.[9] Both Limerick 1 and Limerick 2 were built and producing power by 1990.

In 2015, the Earth Quaker Action Team began protesting PECO to demand that it expand the amount of solar energy that it buys, and to source solar power from North Philadelphia in order to create jobs.[10] PECO purchases enough solar energy to power 2,000 residential households. Twice each year, in March and September, it submits those plans to the Pennsylvania's state regulators for approval. The utility runs the bidding process through a third party for energy suppliers and wholesalers. PECO's sister company, Constellation, is the third largest developer in Pennsylvania of solar installations for commercial, industrial, government and customers, and its parent company, Exelon, has a portfolio of wind-generating power projects across the country.[11] PECO currently generates 0.14% of its energy portfolio from solar energy,[12] but, according to the environmental activists group Earth Quaker Action Team, “...could generate up to 20% of their portfolio from solar.” Sourcing solar energy from rooftop solar panels “...would generate 70 jobs...” or “...could generate up to 4000 new jobs in Philadelphia.”[13]

References

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Further reading

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Revisions and contributorsEdit on WikipediaRead on Wikipedia

PECO Energy Company

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from Grokipedia
PECO Energy Company is Pennsylvania's largest electric and delivery utility, serving approximately 1.7 million electric customers and over 540,000 customers primarily in the Greater region. Founded in 1881 as the Brush Electric Light Company, initially focused on commercial and street lighting, PECO traces its modern corporate structure to the Philadelphia Electric Company, incorporated in 1902, and has since expanded to operate an extensive including 550 electric substations and 21,000 miles of distribution lines. As a of Corporation since 2000, PECO maintains a monopoly on distribution in its service territory under state regulation by the Pennsylvania Public Utility Commission, emphasizing reliability, energy efficiency programs, and modernization amid challenges like regulatory disputes over management and past operational errors leading to unlawful customer shutoffs. Notable aspects include its long-standing role in regional energy delivery, contributions to environmental cleanups as one of Pennsylvania's first integrated state-federal remediation projects, and ongoing commitments to customer assistance funds following compliance issues.

History

Founding and Early Years (1881–1920s)

The origins of PECO Energy Company trace to March 1881, when the Brush Electric Light Company of Philadelphia was formed by Thomas Dolan and associates to install the city's first electric arc lamps along Chestnut Street, marking the introduction of electric street lighting in Philadelphia. Initially funded through private investment after limited municipal support, the company powered a small number of arc lamps using dynamo-generated direct current from a nearby generating station, replacing gas lighting for public illumination. The late 1880s saw rapid proliferation of competing electric ventures in , driven by technological advances in incandescent lighting and central station generation. Key predecessors included the Edison Electric Light Company of , organized in December 1886 to distribute Thomas Edison's incandescent systems, and the Philadelphia Electric Lighting Company, established in 1882 by inventors Edwin J. Houston and Elihu Thomson for arc and incandescent applications. Between and , over twenty such firms operated fragmented grids and power plants, serving streetlights, commercial establishments, and early residential customers amid intense rivalry and overlapping territories. Consolidation occurred in 1902 with the incorporation of the Electric Company under law, merging the entity, Edison operations, and other rivals into a unified chartered to maintain and expand 's electric infrastructure. This structure enabled centralized control over generation and distribution, with initial focus on coal-fired steam plants supplying to urban centers. Through the and , Philadelphia Electric expanded capacity to address surging demand from industrial growth and household electrification, constructing additional central stations like those on the and anticipating needs far exceeding pre-war projections. By the mid-, the company operated multiple bituminous coal-powered facilities, serving over 400,000 customers in the Philadelphia metropolitan area with conversions and extended transmission lines, solidifying its role as the region's dominant provider.

Mid-20th Century Expansion and Nuclear Development (1930s–1980s)

During the , Electric Company pursued expansion amid the , launching initiatives to extend service to underserved areas and constructing major coal-fired facilities to meet growing urban demand. In 1932, the company completed Richmond Station Unit 12, then the world's largest single generator at 165 megawatts (MW), incorporating early emission controls for coal combustion. By the late , a third unit at Schuylkill Station enhanced capacity, supporting industrial recovery and electrification of 's suburbs. Post-World War II economic growth drove significant infrastructure investment, with the company building 13 new generating stations between 1939 and 1958 to accommodate surging demand from household appliances, , and increases. Key projects included the 1960 completion of Eddystone Station Unit 1, a supercritical coal-fired plant that became the world's largest at the time, boasting high efficiency and 325 MW capacity. In , joint ventures expanded capabilities: the Keystone coal-fired plant (shared with other utilities) entered service, while the company-operated Muddy Run pumped-storage hydroelectric facility on the added 1,071 MW of peaking power, enabling better load management. These developments roughly tripled generating capacity from wartime levels, aligning with national trends in utility scale-up. Pioneering nuclear involvement began in the late 1950s as Philadelphia Electric joined feasibility studies through the Atomic Power Development Associates , reflecting optimism about atomic energy's potential to supplant fuels amid rising costs and environmental pressures. In , the company ordered Peach Bottom Unit 1, a 40 MW prototype (HTGR), which achieved criticality in 1966 and began commercial operation in 1967 as one of the earliest U.S. nuclear plants. This experimental unit tested advanced helium-cooling technology but operated only until 1974 due to technical issues. By the 1960s, Philadelphia Electric committed to large-scale nuclear deployment, planning four 1,000 MW units to diversify from coal dependency. Peach Bottom Units 2 and 3, boiling water reactors (BWRs) developed with Philadelphia Electric as lead owner, entered commercial service in 1974, each at 1,093 MW, contributing to the regional grid via the Pennsylvania-New Jersey-Maryland Interconnection (PJM). Construction on in Montgomery County started in 1974 (with planning from 1968), yielding two BWR units; Unit 1 achieved commercial operation in 1985 at 1,314 MW, followed by Unit 2 in 1990, though delays stemmed from regulatory scrutiny and cost overruns exceeding $10 billion total. The 1980s brought challenges, including Peach Bottom's 1987 shutdown for fatigue-related operator issues, enforced by the , with restart only after extensive management reforms and $225 million in upgrades by 1989. Despite setbacks, nuclear assets positioned the company for baseload generation, comprising over 20% of its capacity by decade's end.

Deregulation, Renaming, and Merger with Exelon (1990s–2000s)

In the early 1990s, PECO, then operating as the Philadelphia Electric Company, undertook a corporate reorganization to prepare for an anticipated shift toward a less regulated electric industry, including efforts to streamline operations and position itself for competitive markets. This restructuring reflected broader national trends in utility , driven by high electricity rates in —approximately 15% above the national average—and pressure to introduce competition to reduce costs for consumers. By the mid-1990s, PECO adopted a "generation-led" , emphasizing asset optimization and market entry ahead of regulatory changes. The pivotal legislative development occurred on December 3, 1996, when enacted the Electricity Generation Customer Choice and Competition Act (Act 138), which restructured the state's electricity market by separating from transmission and distribution, allowing retail customers to choose suppliers, and imposing rate caps on utilities like until at least 2001. For , this meant transitioning from a vertically integrated monopoly to a model where it retained responsibility for delivery infrastructure while facing competition in supply; customer choice was phased in starting in 1998 for large users and expanding to all by 1999, with serving as the default provider under price controls. The act facilitated 's divestiture of certain assets to unregulated entities, enabling focus on regulated distribution while exposing the company to wholesale market volatility. In 1994, the company rebranded from Philadelphia Electric Company to PECO Energy Company, a change intended to modernize its identity and align with its evolving role in a competitive landscape, retaining the longstanding "PECO" acronym derived from its service territory in , eastern , , and other areas. Deregulation pressures culminated in strategic consolidation, as PECO Energy merged with Unicom Corporation—parent of Commonwealth Edison—on October 20, 2000, forming Exelon Corporation in a transaction valued at approximately $9.77 billion. The merger, approved by shareholders in June 2000 and the SEC shortly before closing, created one of the largest U.S. utilities with over $12 billion in annual revenues, a combined nuclear fleet exceeding 17,000 megawatts, and synergies projected to yield $100 million in cost savings by 2001, rising to $180 million by 2003. Under Exelon, PECO shifted primarily to regulated distribution and delivery in southeastern Pennsylvania, while generation assets transferred to Exelon's unregulated subsidiary, enhancing efficiency in the post-deregulation environment. This structure complied with federal and state requirements under the Public Utility Holding Company Act and supported PECO's adaptation to competitive generation markets.

Corporate Structure and Ownership

Parent Company Relationship with Exelon

PECO Energy Company became a wholly owned of Corporation through the merger of PECO with Corporation, the of , completed on October 20, 2000. This transaction restructured PECO from a standalone public entity into an operating under 's oversight, with assuming the role of publicly traded parent corporation. The merger integrated PECO's Pennsylvania-based distribution assets with 's Midwest operations, forming a diversified with approximately $40 billion in assets at the time. As a , maintains operational autonomy in its regulated electricity and delivery services for over 1.6 million customers in southeastern Pennsylvania, while provides centralized financial management, strategic planning, and access to capital markets. and exhibit strong parent-subsidiary linkages, including shared assessments and participation in 's corporate money pool, where the parent can lend funds to subsidiaries but not borrow from them, supporting and investment needs. This structure enables to leverage 's scale for investments, such as grid modernization, without direct interference in day-to-day or . In February 2022, completed the spinoff of its competitive business into Constellation Energy Corporation, retaining focus on regulated delivery utilities like , which strengthened the parent's commitment to stable, rate-regulated operations amid shifting energy markets. continues to report as one of 's core subsidiaries, contributing to the parent's portfolio of six utilities serving 10 million customers across multiple states, with emphasizing transmission and distribution reliability over activities post-spinoff. This evolution underscores 's role in providing regulatory and financial stability to , mitigating risks from deregulation-era challenges faced by the subsidiary prior to the merger.

Separation of Generation and Delivery Businesses

In response to Pennsylvania's Electricity Choice Act of 1996, which mandated the unbundling of from distribution to foster in , PECO Energy Company restructured its operations to comply with regulatory requirements for separating competitive activities from regulated delivery services. This separation was formalized through 's corporate restructuring effective January 1, 2001, when PECO transferred its electric generating assets—including nuclear, fossil fuel, and other facilities—to Exelon Generation Company, LLC, a newly formed affiliate focused on competitive power production and marketing. The transfer encompassed substantially all of PECO's capacity, valued at billions in assets, allowing PECO to retain only its wires and infrastructure for while divesting ownership of power plants. Post-separation, PECO's business model shifted to operating as a regulated electric distribution company (EDC), responsible for maintaining and operating the transmission and distribution grid serving approximately 1.6 million customers in the Philadelphia region, with delivery charges subject to oversight by the Pennsylvania Public Utility Commission (PUC). Generation supply became a competitive market function, where PECO procures wholesale power through power purchase agreements (PPAs) with Exelon Generation (later spun off as Constellation Energy in 2022) or third-party suppliers to fulfill its default service obligation, known as Price to Compare (PTC). This arrangement ensured functional unbundling, with customers able to choose alternative generation suppliers since full retail choice implementation in 1999, while PECO's monopoly on delivery persisted under rate caps that phased out by 2010. The mitigated stranded cost risks associated with high-cost legacy assets, such as PECO's nuclear plants, by isolating them in the competitive sector, where recovery depended on market performance rather than bundled rates. PECO's delivery revenues, derived from fixed distribution charges averaging around 40-50% of customer bills, remained stable and regulated, contrasting with volatile costs passed through via PTC adjustments. This model has supported infrastructure investments exceeding $1 billion annually in recent years for grid reliability, without cross-subsidization from profits.

Core Operations

Electricity Distribution and Delivery

PECO Energy Company serves as the regulated electric distribution for approximately 1.7 million customers in southeastern , encompassing County and portions of Bucks, , , and Montgomery counties. Following 's electric in 1997, PECO separated its generation assets, focusing exclusively on the delivery of procured from competitive suppliers or its default service program over its local wires network. This infrastructure connects to the PJM Interconnection's regional transmission grid, ensuring voltage transformation and safe conveyance to end-users including residential, commercial, and industrial loads. The company's distribution system includes over 30,500 miles of combined distribution and transmission lines, of which 16,900 miles consist of underground cable to mitigate weather-related disruptions in urban areas. PECO operates 114 power substations featuring 425 distribution busses for voltage regulation and load balancing, alongside additional unit substations many of which exceed 45 years in age and are slated for phased retirements. As of May 1, 2025, 1,821,605 smart meters have been installed across the territory, supporting advanced metering infrastructure (AMI) for real-time usage data and outage detection. Reliability enhancements form a core aspect of operations, with PECO's Reliability & Resiliency Plan directing $1.36 billion in investments through 2025 toward equipment upgrades, vegetation management, and fault location systems, yielding a 41% reduction in the (SAIFI) compared to 2020 baselines. Distribution automation technologies enable automated fault isolation and service restoration, minimizing outage durations during storms or equipment failures. These measures have also reduced underground residential distribution (URD) cable failures by 99% and main stem cable failures by 41% through prior targeted replacements. Forward-looking initiatives include the Long-Term Infrastructure Improvement Plan III, approved by the Pennsylvania Public Utility Commission, which allocates $1.97 billion from 2026 to 2030 for storm-hardened poles, underground cable reconductoring, and substation reinforcements to withstand and integrate sources. This plan aims to cut interruptions by 25% in priority areas by 2031 while accommodating growing demands without compromising grid stability. PECO's efforts align with state reliability standards, earning recognition as one of 's top-performing electric distribution companies in the 2024 state reliability report.

Natural Gas Distribution and Supply

PECO Energy Company serves as the local distribution company for in southeastern Pennsylvania, delivering service to approximately 553,000 residential, commercial, and industrial customers across Bucks, , , Montgomery, and counties, covering an area of more than 2,100 square miles. The distribution network comprises over 13,970 miles of transmission, distribution mains, and service lines, supported by 29 gas gate stations that regulate flow from transmission pipelines into the local system. This infrastructure enables reliable delivery, with PECO maintaining operational control over pipelines originating from major interstate sources connected to the region's supply hubs. Pennsylvania's natural gas market restructuring, enacted through House Bill 937 signed into on December 3, 1999, separated supply from distribution, allowing customers to choose competitive suppliers while mandating that local utilities like PECO handle transportation, metering, and system maintenance. For customers not selecting an alternative supplier, PECO procures and provides default natural gas supply through competitive bidding processes overseen by the Pennsylvania Public Utility Commission, ensuring continuity amid market fluctuations. This framework has facilitated access to diverse supply options, including sourced volumes from Marcellus Shale production, which has bolstered regional availability since the mid-2000s, though PECO's role remains confined to regulated delivery rather than generation or upstream production. To uphold system safety and reliability, PECO performs annual inspections of its entire distribution infrastructure, including targeted checks on over 46,000 meters and regulators in key counties as part of ongoing compliance with federal safety standards. Investments in integrity management, such as technologies and replacement of aging cast-iron lines, have contributed to low incident rates, with the company reporting consistent adherence to U.S. requirements for distribution operators. These efforts underscore PECO's focus on mitigating risks in a dense urban service territory, where demand peaks during winter heating seasons, averaging higher volumes than summer baseline usage.

Infrastructure and Assets

Transmission and Distribution Systems

PECO Energy Company's electric consists of approximately 862 circuit miles of lines operating at voltages ranging from 69 kV to 230 kV, including 177 miles at 69 kV, 135 miles at 138 kV, and 550 miles at 230 kV. The company also holds partial ownership interests in higher-voltage 500 kV lines, such as 188 miles jointly owned with other utilities, managed through shared arrangements like a 42.55% stake in certain segments crossing state lines. These transmission assets fall under the operational control of the , the regional transmission organization responsible for grid reliability in the mid-Atlantic region, with PECO providing services via FERC-approved tariffs. The distribution system encompasses roughly 22,800 circuit miles, comprising 12,982 miles of overhead lines and 9,814 miles of underground lines, which deliver power to approximately 1.7 million customers across a 1,900-square-mile service territory in southeastern , centered on . operates approximately 200 substations to transform voltage from transmission levels to distribution-appropriate ranges, typically 13 kV for primary feeders, supporting local delivery while adhering to reliability standards set by the Commission and . Infrastructure enhancements include targeted capital expenditures, with $200 million allocated to transmission and $1,300 million to distribution in 2025, focusing on preventive , aerial inspections, and upgrades to mitigate risks from aging assets and environmental factors. These systems, largely situated on public and private easements, enable to maintain a regulated monopoly on delivery while separating it from competitive generation under Pennsylvania's 1990s framework.

Key Facilities and Historical Generation Sites

PECO Energy Company, formerly the Philadelphia Electric Company, developed a network of coal-fired power stations in the early to meet growing demand in the region, leveraging riverfront locations for coal barge access and . The Schuylkill Station, also known as Station A, opened around 1900 as 's first large-scale centralized generating plant, initially equipped with two turbines producing 7,000 kilowatts, and underwent repeated expansions through the and to increase capacity. Similarly, the Delaware Station, constructed between 1917 and 1927 along the , featured multiple turbine-generator units fueled by and later , achieving a peak capacity exceeding 500 megawatts before ceasing operations in 2008. Other notable early facilities included the Richmond Power Station, built from 1923 to 1925 in Beaux-Arts style , which generated using coal-fired boilers until its conversion and eventual decommissioning by 1967, and the Eddystone Station Unit 1, a pioneering 325-megawatt pulverized-coal plant commissioned in 1926 that incorporated advanced supercritical steam technology for higher efficiency. The Chester Waterside Station, erected in 1916 on the , operated as a coal-fired facility supporting industrial loads in . These stations relied on transported by rail from central , reflecting the era's dependence on fossil fuels for baseload power. In the mid-20th century, PECO shifted toward nuclear generation to diversify and expand capacity. The company constructed the Peach Bottom Atomic Power Station in York County, with initial units operational by the 1960s, and the in Montgomery County, where Unit 1 entered commercial service on February 1, 1986, at 1,200 megawatts, followed by Unit 2 on January 8, 1990; construction delays from the 1970s stemmed from regulatory hurdles and community opposition post-Three Mile Island. By the 1990s, nuclear sources accounted for over 65% of PECO's . Following Pennsylvania's 1996 deregulation and PECO's 2000 merger into , generation assets including Limerick and Peach Bottom transferred to Exelon Generation LLC, leaving PECO focused on distribution infrastructure such as substations and transmission lines rather than owned generation sites. Current key facilities emphasize delivery networks, with investments targeting grid resilience but no active company-owned power plants.

Financial Performance

PECO Energy Company's primary revenue sources consist of regulated charges for the distribution and delivery of electricity and , as well as revenues from providing default supply services to customers who do not select competitive suppliers. Electric distribution services, which include transmission and local delivery to approximately 1.7 million customers in southeastern , account for the majority of revenues, supplemented by distribution to over 500,000 customers and provider-of-last-resort (PLR) supply where PECO procures energy and passes through costs to eligible customers. These revenues are subject to oversight by the Commission (PUC), with delivery charges from volume usage to stabilize earnings amid weather or efficiency variations. In 2022, PECO reported total electric operating revenues of $3.165 billion, encompassing both delivery and supply components for customers purchasing directly from the . This marked an increase from $2.658 billion in 2021, driven by approved rate adjustments, higher recoverable costs for infrastructure investments, and growth in energy efficiency program revenues mandated by state regulations. revenues, derived similarly from distribution and default supply, contribute a smaller but stable portion, with overall company revenues estimated at approximately $2.8 billion annually in recent years, though electric operations dominate. Historical trends reflect steady growth tied to capital expenditures on grid upgrades and regulatory rate base expansions, with electric revenues rising amid Pennsylvania's post-deregulation structure separating competitive from regulated delivery. From 2021 to 2022, the uptick aligned with PUC-approved base rate increases to recover deployments and reliability enhancements, while supply revenues fluctuated with wholesale market costs passed through to customers. Further increases in 2023 and 2024 stemmed from ongoing investments in resilience and transmission, though exact figures vary with annual PUC filings and Exelon's segment reporting showing PECO comprising about 18% of parent company revenues.

Capital Investments and Expenditures

PECO Energy Company has directed substantial capital expenditures toward upgrading its electric and distribution systems, emphasizing grid reliability, storm hardening, and modernization to accommodate growing demand and events. In its Long-Term Infrastructure Improvement Plan III (LTIIP III), filed with the Pennsylvania Public Utility Commission in August 2025, PECO proposed an additional $1.97 billion in investments over the five years ending December 31, 2030, targeted at enhancing distribution system resilience through measures such as undergrounding overhead lines, reinforcing substations, and installing advanced protective equipment. These expenditures build on prior plans, with PECO committing approximately $9.3 billion across its electric and infrastructure from 2024 through 2028 to support reliability enhancements, vegetation management, and capacity expansions. As part of its Reliability & Resiliency Plan, allocated $1.36 billion through 2025 for targeted projects, including substation upgrades and line reinforcements in high-outage areas, which contributed to record reliability performance in prior years by reducing outage durations. Independent assessments project 's total capital spending at nearly $7.4 billion from 2024 to 2027, a 19% increase over earlier forecasts, driven by accelerated investments in distribution automation and renewable integration readiness. These figures reflect regulatory approvals from the Commission, which prioritize cost recovery through rate base mechanisms while scrutinizing and impacts. Historical capital expenditures have trended upward in response to aging and regulatory mandates, with variances often tied to timing and supply chain factors as noted in Exelon's annual filings. For instance, earlier five-year plans around 2020 targeted $6 billion for system-wide inspections and replacements, evolving into the more ambitious current outlays amid rising demands and climate risks. Such investments have been financed through a mix of , equity, and ratepayer contributions, with oversight ensuring alignment with verifiable reliability gains rather than speculative ventures.

Regulatory Framework

Oversight by Pennsylvania Public Utility Commission

The Pennsylvania Public Utility Commission (PUC) exercises regulatory authority over PECO Energy Company as an electric distribution company (EDC) and distribution company (LDC) under Title 66 of the Pennsylvania Consolidated Statutes, ensuring safe, adequate, and reasonable service while protecting consumer interests. This oversight includes approving base distribution rates, monitoring service reliability, enforcing compliance with energy efficiency standards under Act 129 of 2008, and adjudicating customer complaints related to billing, outages, and infrastructure maintenance. In rate regulation, the PUC reviews PECO's periodic filings for adjustments to distribution charges, often approving settlements that reduce requested increases to balance utility recovery of costs—such as grid investments—with ratepayer affordability. For instance, on December 12, 2024, the PUC approved electric distribution rate changes resulting in a $0.75 monthly increase for a typical residential using 700 kWh (7.1% overall), far below PECO's initial proposal, and changes yielding a $15.70 monthly increase (10.2%). Similarly, in October 2022, the PUC endorsed a settlement for PECO's gas division allowing a $54.8 million (6%) base rate revenue increase, incorporating contributions to low-income assistance funds. These decisions follow formal proceedings with evidentiary hearings, where judges recommend outcomes based on cost-of-service analyses, excluding generation-related costs due to Pennsylvania's deregulated markets. Service reliability oversight mandates PECO to meet PUC-prescribed performance metrics, including outage duration and frequency indices under 52 Pa. Code Chapter 57, with annual reporting and penalties for non-compliance. The PUC also approves PECO's default service programs for customers not choosing competitive suppliers, as in the 2020 order authorizing time-of-use rates for users to promote . Additionally, under Act 129, the PUC enforces PECO's three-year energy efficiency and demand-response plans, requiring verifiable reductions in peak load and annual reporting on program impacts. Violations, such as inadequate storm response, have prompted PUC investigations and fines, though PECO has generally complied with benchmarks in recent audits.

Impact of Deregulation and Market Restructuring

The Electricity Customer Choice and Competition Act of 1996 initiated and market restructuring in the state's electric industry, with full retail customer choice implemented for 's service territory on July 1, 1999. This unbundled from transmission and distribution services, requiring to separate its competitive functions from its regulated delivery operations. Effective January 1, 2001, transferred its electric generating assets to Company as part of 's corporate restructuring following the 2000 merger with Unicom Corporation, allowing to concentrate on its monopoly-protected wires business while competed in wholesale markets managed by the . Restructuring settlements approved by the Public Utility Commission (PUC) in the late enabled to recover stranded costs through phase-in recovery adjustments and imposed rate caps on services until at least 2002, mitigating short-term financial risks from divested assets. Operationally, shifted PECO's role to procuring power for default service customers via competitive wholesale auctions in PJM, fostering reliance on market signals for supply rather than integrated . This promoted , contributing to an 18% increase (7.1 GW) in Pennsylvania's installed capacity from 1996 to 2014, alongside a 26% rise in natural gas-fired generation and a 16.8% decline in output, as competitive pressures incentivized shifts and new builds. PECO maintained oversight of its distribution grid, ensuring reliability under PUC , while retail expanded options, with PECO offering 57 to 138 competitive plans by 2016, including fixed-price, variable-rate, and renewable-focused products. Customer shopping penetration in PECO's territory reached 22% to 46%, reflecting active market participation. Economically, the reforms yielded measurable benefits for PECO customers, with residential generation and transmission default prices 2% to 41% lower in 2016 compared to 1996 levels adjusted for inflation. Total bundled bills for PECO residential users were 16% to 21% below inflation-adjusted 1996 figures, driven by competitive and efficiency gains, equating to potential statewide default service savings exceeding $818 million in 2016. These outcomes stemmed from deregulation's emphasis on wholesale and divestiture incentives, though PECO faced exposure to price volatility post-rate caps, necessitating hedging strategies for default supply stability. Overall, the transition reinforced PECO's regulated distribution model while integrating it into broader regional markets, supporting long-term cost reductions absent under pre-restructuring .

Achievements and Operational Improvements

Grid Modernization and Reliability Enhancements

PECO Energy Company has deployed technologies, including automated smart switches for fault isolation and power rerouting, smart substations for problem detection and outage prevention, and advanced smart meters for real-time outage notifications and usage data, enabling faster restoration and enhanced overall system reliability. Through its Reliability & Resiliency Plan, allocated $1.36 billion in targeted infrastructure upgrades through 2025, completing more than 200 major electric reliability projects in 2023, which contributed to record-breaking system performance in 2022 by reducing outage durations and frequencies. In August 2025, PECO submitted its Long-Term Infrastructure Improvement Plan III (LTIIP III) to the Commission, outlining $1.97 billion in investments from 2026 to 2030, including $570 million for storm hardening via pole, wire, and substation replacements; $685 million to renew 1,000 miles of aging underground cable; $13 million for substation equipment upgrades; $495 million to retire obsolete small substations; and $206 million to replace 800,000 aging electric meters for better outage detection and safety. These measures aim to minimize weather-related disruptions, support distributed energy resources like solar integration, and facilitate electric vehicle adoption while bolstering grid resilience. Further reliability enhancements encompass $75 million in proactive vegetation management during 2025 to mitigate tree-related outages, alongside advanced grid investments such as microprocessor-based upgrades and networks for superior monitoring and rapid response capabilities.

Investments in Resilience and Customer Service

PECO has implemented its Reliability & Resiliency Plan, investing $1.36 billion through 2025 in targeted electric system infrastructure upgrades to enhance safety, reliability, and storm resistance, including equipment inspections, vegetation management, and new hardening measures. This plan forms part of a broader $6 billion commitment over five years across electric and natural gas systems, focusing on mitigating outage risks from extreme weather events. In August 2025, PECO filed its Long-Term Infrastructure Improvement Plan III (LTIIP III) with the Pennsylvania Public Utility Commission, proposing an additional $1.97 billion in capital investments to prioritize and accelerate system enhancements for reliability in high-risk areas. Complementing these efforts, PECO secured up to $100 million in federal funding through the U.S. Department of Energy's Grid Resilience and Innovation Partnerships program under the , announced in 2023, to execute the CREATE Plan. Key projects include modernizing aging infrastructure, relocating substation equipment from flood-prone zones, and deploying microgrids with battery storage to support rapid storm recovery and maintain critical loads. These initiatives aim to boost grid capacity for renewable integration and charging while minimizing bill impacts, with expected outcomes including reduced outage durations and enhanced resilience against frequent , as evidenced by ongoing tree-trimming investments of $320 million across 600 miles of aerial lines over the next decade. These resilience investments have contributed to improved customer service metrics, with PECO achieving record Customer Satisfaction Index scores in 2021 and sustaining top-decile performance in perceptions of reliability and through 2025, as measured by independent studies from Escalent. and meter technologies provide customers with real-time data, outage notifications, and usage insights, enabling greater flexibility and informed energy management. In 2025, PECO launched a $10 million Customer Relief Fund offering $500 bill credits to income-qualified households (151-300% of federal poverty level) to address summer billing pressures, alongside financial incentives like rebates for energy-efficient upgrades through programs such as C-PACE and NEIF. Overall, these measures have supported consistent recognition as a "Customer Champion" among utilities, with reliability enhancements directly correlating to higher satisfaction in service responsiveness and outage restoration.

Controversies and Criticisms

Delays in Nuclear Infrastructure Development

The , a two-unit facility developed by Philadelphia Electric Company (the predecessor to PECO Energy Company), encountered substantial delays during its construction phase in the 1970s and 1980s, primarily due to regulatory scrutiny, community opposition, and utility prioritization decisions. Construction on Unit 1 commenced in June 1974 following initial in the late , but faced immediate resistance from environmental groups and local residents concerned about safety risks near the and population centers in . These challenges, including protests led by organizations such as the Keystone Alliance, protracted legal battles, and extensive public hearings, extended the development timeline significantly. Unit 1 did not achieve commercial operation until February 20, 1986, representing a delay of over 11 years from the start of construction amid accumulating regulatory requirements and opposition-driven interventions that slowed permitting and oversight processes. Unit 2, with construction advancing to approximately 30% completion by mid-1982, was further impacted when the Pennsylvania Public Utility Commission ordered a halt to work in June 1982 pending reviews of project prudence and cost implications for ratepayers. Philadelphia Electric then suspended active construction on Unit 2 in January 1984 to focus resources on completing Unit 1, a decision influenced by financial pressures and the need to demonstrate operational viability before resuming the second unit, which ultimately entered commercial service on January 25, 1990. These delays not only postponed the addition of approximately 2,300 megawatts of nuclear generating capacity to the regional grid but also escalated project costs into the billions, fueling criticisms from advocates and regulators over the utility's of timelines and the pass-through of overruns to customers via rate adjustments. Opposition efforts also led to the abandonment of plans for a third unit at Limerick, reflecting broader national trends in nuclear development where proliferating regulations and activism contributed to extended lead times from to operation, often exceeding a decade per unit. While the completed units provided baseload power, the episode highlighted vulnerabilities in large-scale nuclear infrastructure projects undertaken by vertically integrated utilities like Electric, including exposure to external stakeholder challenges and internal trade-offs.

Billing System Failures and Customer Impacts

In late 2024, PECO's billing system encountered glitches that prevented bill generation for numerous customers, resulting in delays of up to six months before accumulated charges were issued as past-due notices. These failures stemmed from errors in the system responsible for producing statements, affecting both electric and gas accounts, including budget billing participants. By May 2025, PECO acknowledged that as many as 8,000 customers had been impacted since the previous fall, with some experiencing incorrect usage calculations due to meter programming errors. Customers faced severe financial shocks from sudden large bills; for instance, one resident received a $11,723.93 statement in May 2025 after months without prior notices, attributed to an inaccurate meter reading that overstated usage. Extreme cases included erroneous charges exceeding $193,000 following smart meter replacements, prompting urgent complaints to the Pennsylvania Public Utility Commission (PUC). In August 2025, additional customers reported receiving backbilled amounts after prolonged absences of statements, leading to disputes over validity and threats of service disconnection. The disruptions eroded customer trust, with dozens filing informal complaints via the PUC for billing inaccuracies and service quality lapses, alongside reports to the highlighting unresolved payment disputes. PECO attributed ongoing errors to a new online billing platform under development, while offering individualized resolutions such as payment plans and bill adjustments. By November 2024, despite claims of progress, persistent issues continued to generate public frustration and calls for regulatory intervention.

Rate Increases and Affordability Debates

In December 2024, the Pennsylvania Public Utility Commission (PUC) approved PECO Energy Company's requests for electric and natural gas distribution rate increases, but at levels below those proposed by the utility. For electric service, the approved net increase totaled approximately $160 million annually, resulting in a 10% rise or $13.58 monthly for a typical residential customer using 700 kilowatt-hours (kWh), bringing the average bill to $149.43 effective January 1, 2025. Natural gas bills increased by about $12.25 monthly for residential customers, compared to PECO's requested $16.15. These adjustments followed PUC investigations into PECO's April 2024 filings, which sought a net $399 million electric increase (25.1% after proposed credits) to recover investments in grid infrastructure and operations. Rate hikes have intensified affordability concerns amid broader Pennsylvania energy price escalations, with state electric prices rising 11.4% from June 2024 to June 2025—the highest annual increase in available data. PECO customers faced additional pressures from Price to Compare (PTC) adjustments tied to PJM Interconnection wholesale markets, including a 13% PTC rise effective June 1, 2025, and a 10% phased bill increase over two years from higher capacity auction costs. Critics, including consumer advocates and environmental groups like Audubon Pennsylvania, argued that PJM's market mechanisms unfairly burden ratepayers with costs from retiring fossil fuel plants and data center demands, prompting protests and calls for federal review. Residential bills in the Philadelphia region reached record highs for some in summer 2025, exacerbating strains on low-income households amid inflation and extreme weather driving usage. PECO justified increases as necessary to fund reliability enhancements and regulatory compliance, with PUC approvals reflecting verified costs rather than full requests after evidentiary hearings. To address affordability, PECO expanded assistance via programs like the Low-Income Home Energy Assistance Program (LIHEAP) partnerships and bill payment plans, while encouraging energy efficiency rebates and supplier shopping in Pennsylvania's deregulated market. The PUC emphasized consumer options, such as reducing usage and comparing generation suppliers, to mitigate impacts, though supply-side volatility remains a key debate factor. Public input sessions, including those in Montgomery County in June 2024, highlighted customer testimonies on bill burdens, influencing PUC's moderated approvals.

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