Item 5. OTHER INFORMATION

Certain information is provided below for new matters that have arisen subsequent to the filing of the Form 10-K and the first quarter 2026 Form 10-Q.

Director and Officer Rule 10b5-1 and non-Rule 10b5-1 Trading Plans

During the three months ended June 30, 2026, none of the Company’s directors or officers adopted, terminated or modified a Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement (as such terms are defined in Item 408 of Regulation S-K of the Securities Act of 1933).

Federal Regulation

Transmission Regulation—Transmission Rate Proceedings and ROE

December 31, 2025 Form 10-K page 10. Under current FERC rules, PSE&G continues to earn a 50 basis point adder to its base ROE for its voluntary membership in PJM as a transmission owner. In June 2026, legislation was passed in New Jersey that requires transmission owners that own and operate transmission facilities in New Jersey to be members of a Regional Transmission Organization (RTO) approved by FERC. The legislation will require that, effective January 1, 2027, transmission owners be members in an RTO. While we are continuing to assess the potential impact of this legislation, this mandatory RTO membership requirement could result in the future loss of PSE&G’s 50 basis-point ROE adder for participating in an RTO. This would prospectively reduce PSE&G’s annual Net Income and annual cash inflows by approximately $40 million. We cannot predict the outcome of this matter.

Transmission Regulation—Transmission Planning Proceedings

December 31, 2025 Form 10-K page 11 and March 31, 2026 Form 10-Q page 66. In March 2026, FERC issued an order addressing a longstanding dispute about the methodology used in PJM to calculate and assign transmission project costs. The FERC order, among other things, rejected a proposed settlement agreement that would have shifted significant costs to PSE&G’s transmission customers. FERC directed PJM to recalculate cost responsibility assignments and resettle billings going back to 2015. Proceedings continue at FERC and at the U.S. Court of Appeals for the DC Circuit. We cannot predict the outcome of these proceedings.

Regulation of Wholesale Sales—Generation/Market Issues/Market Power

December 31, 2025 Form 10-K page 10. In October 2025, in response to a directive by the Secretary of Energy, FERC initiated a rulemaking proceeding to establish rules by the end of April 2026 to facilitate the interconnection of large load customers to the transmission system through a queue process. In June 2026, FERC issued an order directing PJM and its transmission customers to show cause as to why the PJM Tariff should not be found to be unjust and unreasonable because it does not contain provisions relating to the application and study process for large customers seeking transmission service, mitigation of risk of cost shifting among transmission customers due to large loads, including providing transparency into

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transmission costs, and accommodation of co-location arrangements and behind the meter generation. We cannot predict the outcome of these matters.

Capacity Market Issues

In July 2026, PJM proposed tariff revisions to FERC to implement a proposed “Reliability Backstop Procurement” framework to address the 6.8 GW resource shortfall for the 2028/2029 delivery year. This procurement mechanism seeks 15-year commitments from new generation resources, with costs passed to load-serving entities and end-use customers, including data centers. We cannot predict the outcome of this matter.

State Regulation

Energy Efficiency, Triennial Review

December 31, 2025 Form 10-K page 14 and March 31, 2026 Form 10-Q page 66. While it was previously anticipated that the BPU would issue a final framework for the third triennium during the first half of 2026, in April 2026, BPU Staff issued its straw proposal for a one-year extension to the second triennium of energy efficiency programs rather than issuing a framework for the third triennium to accommodate the time needed for the BPU to establish the third triennium framework. In July 2026, the BPU issued the final framework for the extension. The final framework includes elements that adjust the overall budget for the extension, requiring budgets to be based on gross, not net, energy savings, adjusts return on equity that the utilities can earn for achieving performance goals, and replaces the existing method to collect foregone revenue. The framework also allows for utilities to file for alternative proposals, including but not limited to ROE and savings targets. Petitions by utilities for the extension are due on September 30, 2026. It is anticipated that the BPU will issue the framework for the third program cycle of energy efficiency programs later in 2026. We cannot predict the outcome of this matter at this time.

BGS Process

December 31, 2025 Form 10-K page 14. The February 2025 BGS auction resulted in a significant cost increase for electricity supplied by PSE&G and all other New Jersey electric distribution companies that was reflected in customers’ rates beginning June 1, 2025. The cost increases were in large part due to higher prices from the PJM capacity market (base residual auction). The February 2026 BGS auction resulted in a slight cost decrease for electricity supplied by PSE&G that became effective June 1, 2026. In July 2026, New Jersey’s EDCs filed their annual joint proposal for conduct of the February 2027 BGS auction covering energy years 2028 through 2030. Rates resulting from the February 2027 BGS auction will become effective June 1, 2027.

Certain Recently-Enacted State Legislation

In July 2026, Governor Sherrill signed the Advance Grid Technologies Act into law. This Act will increase BPU oversight of supplemental electric transmission projects that are developed under PJM's Attachment M-3 process. It requires any supplemental transmission project that is 100kV or more to file for and obtain a Certificate of Public Convenience and Necessity before beginning construction of the project. At the same time, it encourages utilities to use advanced grid technologies, such as dynamic line ratings, advanced conductors, and power flow control devices, by providing an expedited approval process for projects that meaningfully incorporate these technologies.

In July 2026, Governor Sherrill also signed the Data Center Fair Share Act into law. This legislation is designed to protect non-data center customers from bearing the costs of providing service to the state's rapidly growing large data center sector. The law requires the BPU and electric utilities to establish a separate rate class and tailored service requirements for qualifying large data centers, ensuring they pay the full cost of the electricity infrastructure and grid upgrades, among other costs, needed to serve their operations. It also encourages data centers to bring new, lower-cost clean energy resources online and requires them to reduce electricity demand during periods of grid stress before residential customers are affected. In addition, the legislation requires the BPU to create with stakeholder input an innovative retail program allowing new large-load customers to offset their capacity obligations by funding demand-reduction measures elsewhere on the grid, with the goal of supporting AI and data center growth while maintaining grid reliability and keeping electricity bills affordable for other New Jersey customers. The BPU is expected to initiate policy proceedings to develop rate class and demand reduction programs, the outcome of which is uncertain at this time.

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In July 2026, the Power NJ Act was signed into law. This legislation establishes a competitive framework to evaluate and procure at least 1,100 MW of new nuclear generation, including advanced reactors and small modular reactors, to help meet growing electricity demand while supporting the state's clean energy goals. The legislation directs the BPU to solicit proposals, evaluate developers, and negotiate contracts through a structured process with significant oversight and public input and establishes a Reliable Capacity Certificate program to provide qualifying projects with a stable revenue mechanism that supports financing while ensuring reliable, carbon-free electricity for New Jersey.