10-K: PSEG Reports Strong 2025 Earnings, Outlines $28B Capital Plan

Public Service Enterprise Group (PSEG) reported a significant increase in 2025 net income, driven by regulated investments and stable nuclear generation, while outlining a substantial multi-year capital investment program.

Summary

• PSEG's Net Income increased to $2,111 million in 2025 from $1,772 million in 2024, with diluted EPS rising to $4.22 from $3.54.
• The regulated capital investment program for 2026-2030 is estimated at $22.5 billion to $25.5 billion, contributing to a projected compound annual growth rate in regulated rate base of 6.0% to 7.5% through 2030.
• PSE&G's regulated rate base grew from approximately $34 billion in 2024 to $36 billion in 2025, supported by the 2024 distribution base rate case settlement and ongoing investment programs.
• PSE&G's operating cash flow increased by $643 million to $2,368 million in 2025.
• PSEG Power's nuclear units generated approximately 30.9 terawatt hours in 2025, operating at a high capacity factor of 91.2%.
• The LIPA Operations Services Agreement (OSA) for PSEG Long Island was extended for five years, through December 31, 2030.
• PSE&G's Clean Energy Future-Energy Efficiency (CEF-EE) II filing approved approximately $2.9 billion for energy efficiency projects from 2025 through 2027.
• The Gas System Modernization Program (GSMP) III was approved, authorizing $1.05 billion of capital investment for gas main replacement from 2026 through 2028, with an additional $360 million for 75 miles of gas main.
• PSEG Power's nuclear plants are eligible for Production Tax Credits (PTCs) from 2024 through 2032, providing downside price protection, though no PTC benefit was recorded in 2025 as gross receipts exceeded the threshold.
• A $424 million transmission line project in Maryland and northern Virginia, awarded by PJM in December 2023 with a 2027 in-service date, is not currently believed to be reasonably achievable due to procedural timelines.
• The company's Board of Directors approved a $0.67 per share common stock dividend for the first quarter of 2026, reflecting an indicative annual dividend rate of $2.68 per share.

Sentiment

Score: 8

Explanation: StockSavvy.ai views this as a strong performance, driven by robust regulated growth and stable nuclear operations, despite some market and regulatory headwinds. The significant capital investment plan and dividend increase signal confidence in future earnings.

Positives

• PSEG's Net Income increased significantly to $2,111 million in 2025 from $1,772 million in 2024.
• Diluted EPS increased to $4.22 in 2025 from $3.54 in 2024.
• The regulated rate base grew from $34 billion in 2024 to $36 billion in 2025, with a projected compound annual growth rate of 6.0% to 7.5% through 2030.
• PSE&G's operating cash flow increased by $643 million to $2,368 million in 2025.
• PSEG Power's nuclear units maintained a high capacity factor of 91.2% in 2025, generating 30.9 terawatt hours.
• The LIPA Operations Services Agreement (OSA) was extended for five years through December 31, 2030, ensuring continued revenue for PSEG LI.
• Approval of PSE&G's CEF-EE II ($2.9 billion) and GSMP III ($1.05 billion + $360 million) programs indicates continued significant regulated investment opportunities.
• The Production Tax Credits (PTCs) for nuclear energy provide downside price protection through 2032, enhancing the stability of nuclear generation earnings.
• PSE&G's Mortgage coverage ratio of 3.9 to 1 as of December 31, 2025, permits up to approximately $10.2 billion in new Mortgage Bonds.
• The Board of Directors approved an increased common stock dividend of $0.67 per share for Q1 2026, an indicative annual rate of $2.68 per share.
• Management concluded that internal control over financial reporting is effective as of December 31, 2025.

Negatives

• No Production Tax Credit (PTC) benefit was recorded in 2025 for nuclear operations, as gross receipts exceeded the threshold, indicating less direct financial support from the credit in strong market conditions.
• Increased electricity costs for customers in 2025 due to higher PJM capacity market prices have led to affordability concerns and increased regulatory scrutiny.
• PJM's December 2025 capacity auction cleared at the FERC-approved price cap of $333.44/MW-day, but PJM indicated it would have been $529.80/MW-day without the cap, and PJM was unable to procure enough generation to meet its reliability requirement (6,625 MW short).
• New Jersey Legislature enacted a law prohibiting disconnection for non-payment during summer months (June 15-August 31) starting 2026, which increased Accounts Receivable and bad debt expense in 2025 with potential future increases.
• Potential elimination of FERC's 50 basis point adder for RTO membership would reduce PSE&G's annual Net Income and cash inflows by approximately $40 million.
• Increased interest expense by $123 million for PSEG and $62 million for PSE&G in 2025 due to incremental debt and higher rates.
• PSEG's Income Tax Expense increased by $210 million in 2025, primarily due to the absence of nuclear PTC benefits and higher pre-tax income.

Risks

• Inability to successfully develop, obtain regulatory approval for, or construct transmission and distribution, and nuclear generation projects.
• Significant resource adequacy challenges in PJM, leading to affordability and reliability concerns, potentially causing policymakers to implement responsive measures that could materially impact business, strategy, growth rates, cash flows, results of operation, and financial condition, and increase regulatory uncertainty.
• Physical, financial, and transition risks related to climate change, including increased legislative/regulatory burdens, changing customer preferences, and lawsuits.
• Asset and equipment failures, gas explosions, accidents, critical operating technology or business system failures, natural disasters, severe weather events, acts of war, terrorism, sabotage, physical attacks, security breaches, cyberattacks, or other incidents (e.g., pandemics) impacting service reliability and competitiveness, potentially resulting in substantial financial losses.
• Inability to recover the carrying amount of long-lived assets, potentially leading to future impairment charges.
• Disruptions or cost increases in the supply chain, including labor shortages.
• Inability to maintain sufficient liquidity or access sufficient capital on commercially reasonable terms.
• Impact of cybersecurity attacks or intrusions or other disruptions to IT, operational, or other systems.
• Failure to attract and retain a qualified workforce.
• Increases in the costs of equipment, materials, fuel, services, and labor (inflation).
• Impact of covenants in debt instruments and credit agreements on the business.
• Adverse performance of defined benefit plan trust funds and Nuclear Decommissioning Trust Fund, leading to increased funding requirements.
• Inability to enter into or extend certain significant contracts (e.g., LIPA OSA, BGSS contract).
• Development, adoption, and use of Artificial Intelligence by the company and third-party vendors.
• Fluctuations in, or third-party default risk in, wholesale power and natural gas markets, including impacts on the economic viability of generation units.
• Inability to obtain adequate nuclear fuel supply.
• Changes in technology related to energy generation, distribution, and consumption, and changes in customer usage patterns.
• Third-party credit risk relating to the sale of nuclear generation output and purchase of nuclear fuel.
• Inability to meet commitments under forward sale obligations and Regional Transmission Organization rules.
• Risks associated with generation activities at, and operation of, the Peach Bottom plants (50% owned, third-party operated).
• Impact of changes in state and federal legislation and regulations on the business, including PSE&G's ability to recover costs and earn returns.
• PSE&G's proposed investment projects or programs may not be fully approved by regulators, and capital investment may be lower than planned.
• Inability to receive sufficient financial support for New Jersey nuclear plants from markets and/or production tax credits.
• Adverse changes in and non-compliance with energy industry laws, policies, regulations, and standards.
• Risks associated with ownership and operation of nuclear facilities, including increased fuel storage costs, regulatory risks (Atomic Energy Act, trade control, environmental), operational, financial, environmental, and health/safety risks.
• Changes in or violation of federal, state, and local environmental laws and regulations and enforcement.
• Delays in receipt of, or inability to receive, necessary licenses, permits, and siting approvals.
• Changes in tax laws and regulations (e.g., CAMT, PTC guidance).
• Litigation risk, including the Newark Bay Complex, Lower Passaic River Study Area, Hackensack River, MGP Remediation Program, and Sewaren 7 Construction.
• Potential for increased costs and penalties from environmental remediation efforts.
• Risk of penalties or increased costs for non-compliance with NERC Reliability Standards.
• Risk of losing Market-Based Rate (MBR) authority from FERC.
• Oversight by the CFTC relating to derivative transactions.
• Risk of increased Accounts Receivable and bad debt expense due to new summer shutoff moratorium for certain customers.
• Risk of retrospective premium assessments from Nuclear Electric Insurance Limited (NEIL) due to adverse industry loss experience.

Future Outlook

PSEG anticipates a regulated capital investment program of $22.5 billion to $25.5 billion for 2026-2030, aiming for a 6.0% to 7.5% compound annual growth rate in its regulated rate base. The company expects its nuclear units to be supported by Production Tax Credits (PTCs) through 2032, with hedging strategies evolving based on market conditions and U.S. Treasury guidance. PSEG will continue to explore long-term power sales from its nuclear facilities and evaluate additional regulated transmission investment opportunities. The net zero greenhouse gas (GHG) emissions goal has been adjusted to 2050, acknowledging transition risks. Future success hinges on strong operational and financial performance, effective navigation of regulatory and legislative developments, and proactive responses to market changes and cybersecurity threats.

Management Comments

• Our business plan focuses on achieving growth by allocating capital primarily toward regulated investments in an effort to continue to improve the sustainability and predictability of our business and realizing the value of the consistent and reliable carbon-free generation from our nuclear units.
• We are focused on investing to meet growing energy demand, modernize our energy infrastructure, improve reliability and resilience, increase EE to meet customer expectations and be well aligned with public policy objectives.
• Our hedging strategy continues to incorporate an estimated range of risk reduction impacts from the PTCs on our nuclear generation portfolio while retaining the ability to benefit when market pricing exceeds the level at which we would receive PTCs.
• As of December 31, 2025, we expect that our current portfolio position for 2026 will result in the realized value of our nuclear generation output being above the level at which we would receive PTCs.
• Our strategy will continue to evolve taking into account energy market conditions, PTC guidance uncertainty, and potential incremental changes upon receiving U.S. Treasury guidance.
• We remain guided by our vision to power a future where people use energy more efficiently, and its safer and delivered more reliably than ever.
• We continually assess a broad range of strategic options to maximize long-term shareholder value and address the interests of our multiple stakeholders.

Industry Context

StockSavvy.ai notes that the utility sector is undergoing a significant transformation driven by decarbonization goals, grid modernization, and increasing electrification (EVs, data centers). PSEG's strategic focus on regulated investments in T&D and clean energy programs aligns well with these trends, providing a more stable and predictable earnings profile compared to merchant generation. The challenges in PJM's capacity market, including insufficient generation to meet reliability requirements and high clearing prices, reflect broader industry concerns about resource adequacy and the transition to cleaner energy sources. The extension of nuclear plant licenses and the benefit of Production Tax Credits (PTCs) are critical for maintaining baseload carbon-free generation, a key theme in the evolving energy landscape. The litigation surrounding the LIPA OSA and the regulatory scrutiny on transmission planning and cost recovery are common industry hurdles for large utilities.

Comparison to Industry Standards

• PSEG's nuclear capacity factor of 91.2% in 2025 is strong, generally aligning with or exceeding industry averages for well-run nuclear fleets, which often aim for capacity factors above 90%. For example, the U.S. nuclear fleet average capacity factor has historically been around 92-93%.
• The 9.6% return on equity (ROE) for PSE&G's distribution business, approved by the BPU in October 2024, is competitive within the regulated utility sector, though some utilities in more favorable regulatory environments or with higher risk profiles might achieve slightly higher authorized ROEs (e.g., some state commissions have approved ROEs in the 9.7-10.5% range for electric distribution).
• PSE&G's transmission base ROE of 9.90% plus a 50 basis point adder for RTO membership is consistent with FERC-approved formula rates for transmission owners in PJM, which are designed to incentivize investment in critical infrastructure.
• The significant capital investment program of $22.5 billion to $25.5 billion for 2026-2030, with a projected regulated rate base growth of 6.0% to 7.5%, demonstrates a robust investment strategy comparable to other large, modernizing utilities like NextEra Energy or Duke Energy, which are also heavily investing in grid upgrades, renewables integration, and T&D infrastructure.
• The challenges in PJM's capacity market, including the inability to procure sufficient generation (6,625 MW short in December 2025 auction) and high clearing prices ($333.44/MW-day, with an indicated $529.80/MW-day without cap), highlight a systemic issue within the PJM region that affects all participants, including PSEG Power, and is a point of concern for reliability and affordability compared to other RTOs/ISOs that may have different market designs or resource adequacy challenges.

Management Changes

Corporate Governance

Legal Proceedings

• Newark Bay Complex: The EPA has designated a 17-mile stretch of the Passaic River (Lower Passaic River Study Area LPRSA) as a federal Superfund site. Cleanup plans are estimated at $2.3 billion for the Lower 8.3 miles and $550 million for the Upper 9 miles. Occidental Chemical Corporation has filed two lawsuits against PSE&G and others to recover costs. PSEG has accrued approximately $66 million for this matter as of December 31, 2025, but the ultimate impact is uncertain and could be material.
• Newark Bay Study Area: An extension of the LPRSA, where the EPA has notified PSEG and 21 other Potentially Responsible Parties (PRPs) of potential liability. PSEG and PSEG Power are unable to estimate their respective portions of any loss.
• Hackensack River: Designated as a federal Superfund site. PSE&G and PSEG Power are participating in a technical study for Operable Unit 2 and considering EPA's request for Operable Unit 3. Future costs related to this matter could be material.
• MGP Remediation Program: PSE&G is assessing and remediating 38 former manufactured gas plant (MGP) sites. The estimated cost to remediate ranges between $179 million and $196 million (undiscounted), with a $179 million liability recorded as of December 31, 2025, and a corresponding Regulatory Asset.
• Legacy Environmental Obligations at Former Fossil Generating Sites: PSEG Power retained environmental liabilities from the 2022 sale of its fossil generation portfolio for 8 sites in New Jersey and Connecticut. Full remediation costs are not estimable but are likely material in aggregate. The EPA's revisions to the coal combustion residuals (CCR) rule may also have a material impact.
• FERC Investigation of Roseland-Pleasant Valley (RPV) Transmission Project: FERC approved an agreement in December 2024 resolving an investigation, including a $6.6 million civil penalty and compliance requirements. An intervenor filed a FERC complaint in January 2026 challenging the recovery of these costs.
• LIPA Operations Services Agreement (OSA) Extension Litigation: A competitor filed litigation against LIPA challenging the five-year extension of the OSA with PSEG Long Island. LIPA's motion to dismiss was granted in December 2025, but the competitor filed an appeal in January 2026.
• Sherman Act Antitrust Matter: A putative class action complaint was filed in July 2025 against 26 nuclear generation power companies, including PSEG, alleging conspiracy to fix compensation and exchange information regarding nuclear generation workers. Relief sought includes treble damages.

Related Party Transactions

• PSE&G has a full-requirements contract with PSEG Power for gas supply services (BGSS) at BPU-prescribed rates.
• PSEG Power sold Zero Emission Certificates (ZECs) to PSE&G from its nuclear units at BPU-prescribed rates; the ZEC program ended June 1, 2025, with the final payment settled in August 2025.
• PSEG Power and PSE&G provide certain technical services for each other generally at cost, in compliance with FERC and BPU affiliate rules.
• PSEG Services Corporation provides and bills administrative services to PSE&G at cost, and PSE&G has other payables to Services for common costs.
• PSEG pays net wages and payroll taxes and receives reimbursement from its affiliated companies for their respective portions.
• Income taxes are allocated to PSEG's subsidiaries on a stand-alone basis, with payments to/from PSEG for net tax liability/savings.
• PSE&G has advanced working capital to Services, included in Other Noncurrent Assets on PSE&G's Consolidated Balance Sheets.
• PSEG Power's net credit exposure for wholesale operations, which is over 98% with investment grade counterparties, includes one counterparty with greater than 10% exposure, which is PSE&G (eliminated in consolidation).

Stakeholder Impact

• Shareholders: Benefit from increased net income, diluted EPS, a significant capital investment program, and an increased common stock dividend. However, they face risks from regulatory uncertainties, environmental liabilities, and ongoing litigation.
• Customers: Experience higher electricity costs in 2025 due to PJM capacity market prices, leading to affordability concerns. New Jersey Legislature's new summer shutoff moratorium for non-payment could impact customer collections for the company. Energy efficiency and EV programs aim to provide long-term benefits.
• Employees: The company's human capital management strategy focuses on attracting, developing, and retaining a diverse workforce. Collective bargaining agreements with six unions are in place until 2027. Amendments to executive compensation plans affect benefits and incentives.
• Regulators: Engage with FERC and BPU on critical matters including transmission rates, capacity markets, clean energy programs, and environmental compliance. Regulatory decisions significantly influence the company's operations and financial recovery.
• Creditors: Benefit from a strong liquidity position and compliance with debt covenants. However, there is a potential for increased collateral requirements if PSEG Power's credit rating is downgraded.
• Suppliers: May be impacted by supply chain disruptions and cost increases, which could affect the company's operations and project timelines.

Next Steps

• PSEG will continue to evaluate opportunities to participate in transmission solicitation processes and may decide to submit bids for material investments.
• PJM will be developing rules for a reliability backstop auction, targeting September 2026, following FERC approval of rule changes.
• PJM Transmission Owners, including PSE&G, are working with states to develop cost allocation rules for long-term transmission facilities, with a FERC filing to be made later in 2026.
• PSE&G will file triennium 3 energy efficiency program proposals during 2026 for a program to begin in July 2027.
• PSE&G will file an updated cost recovery petition in January 2026 to recover $8 million annually in electric base rates effective April 1, 2026, for CEF-EV investments.
• PSE&G will update its GSMP II Ext cost recovery petition seeking BPU approval to recover an annual revenue increase of $23 million effective February 1, 2026.
• PSE&G will file its annual 2025 Tax Adjustment Credit (TAC) filing requesting a reduction to tax benefits flowed back to customers, resulting in an increase to annual electric and gas revenues by approximately $15 million and $10 million, respectively.
• PSEG will continue to monitor federal and state legislative activity and executive orders and their impacts on supply chain, business, cash flow, results of operations, and financial condition.
• PSEG will continue to assess physical risks of climate change and adapt its capital investment program.
• PSEG will make future pension contributions to satisfy IRS minimum funding requirements, potentially up to $100 million in 2026.
• PSEG Power plans power uprates at Salem Units 1 and 2.
• PSEG Power will continue to explore opportunities for the potential sale of power, capacity, and/or emission credits from its nuclear facilities pursuant to long-term agreements.
• PSEG will continue to advocate for appropriate regulatory guidance on the Production Tax Credit (PTC) to ensure long-term support for New Jersey's largest carbon-free generation resource.
• PSEG will continue to focus on controlling costs and maintaining affordable customer rates.
• PSEG will continue to engage constructively with multiple stakeholders.
• PSEG will continue to deliver on its human capital management strategy.
• Competitor filed an appeal in January 2026 regarding the LIPA OSA extension.
• Intervenor filed a FERC complaint in January 2026 against PSE&G requesting a hearing on the recovery of RPV project costs.
• BPU directed PSE&G to eliminate its ZEC tariff rate, effective February 1, 2026.
• U.S. Treasury issued Notice 2026-07 (CAMT Notice) in February 2026, clarifying AFSI computation.

Key Dates

Recommendation

PSEG demonstrates strong financial performance in 2025 with increased net income and EPS, driven by its predominantly regulated business model. The substantial multi-year capital investment program in T&D and clean energy infrastructure provides a clear growth trajectory and enhances earnings predictability. While regulatory uncertainties and market volatility in PJM exist, the company's strategic focus on regulated assets, stable nuclear generation with PTC downside protection, and a commitment to sustainability positions it favorably for long-term value creation. The dividend increase further signals management's confidence.

Keywords

Utility, Electric, Gas, Nuclear Power, Transmission, Distribution, Energy Efficiency, EV Infrastructure, New Jersey, PJM, SEC Filing, 10-K, Financial Results, Capital Investment, ESG, Climate Change, Regulatory, Production Tax Credit, Infrastructure, Rate Base, Earnings Per Share