Public Service Enterprise Group reported third-quarter 2026 results on Monday, November 2, before the market opened, and the quarter landed almost exactly where this publication’s preview said the honest reading would be: modest growth in the regulated business, a headline GAAP number that requires translation, and a guidance decision that mattered more than the print itself. Non-GAAP operating earnings were $1.15 per share, up from $1.13 per share in the third quarter of 2025. That is growth of about 2%, not the roughly 4 to 5% implied by the consensus near $1.18 per share, and below the Zacks consensus of $1.21 per share. Read against the preview’s benchmark, the quarter was a narrow miss on expectations and a small gain on the prior year — both descriptions are true, and neither alone is the story.
Start, as this publication’s earnings checklist prescribes, with the two EPS numbers. GAAP net income was $0.76 per share, down from $1.24 a year earlier, on net income of $376 million against $622 million. Non-GAAP operating earnings were $574 million, up from $565 million. The $0.39 gap is the reconciliation, and this quarter it reads as familiar housekeeping: mark-to-market and Nuclear Decommissioning Trust losses dragged PSEG Power & Other to a $130 million GAAP net loss, against $107 million of net income a year earlier, while that segment’s operating earnings improved. Revenue was $3.02 billion, down from $3.226 billion and below the Zacks consensus of $3.30 billion — soft against forecasts, but for a predominantly regulated utility the operating-earnings line, not revenue, is the measure guidance is written against.
The guidance math, updated
Guidance is the promise that matters most, and on Monday management kept it intact without narrowing it. Full-year 2026 non-GAAP operating earnings guidance remains $4.28 to $4.40 per share, and the longer-term target of 6% to 8% compound annual growth in non-GAAP operating earnings through 2030 was reaffirmed alongside it. The preview’s question was whether management would narrow the range toward the top half, signaling confidence in the fourth quarter, or flatly reaffirm it. The answer was the second option, with a verbal nudge: on the call, Chair, President and CEO Ralph LaRossa told an analyst pressing for a tightening that the company had “not kind of pushed you higher or lower” and that investors should “still be thinking somewhere around the midpoint of where we are.”
Do the arithmetic the checklist prescribes, now with actuals instead of estimates. Nine-month non-GAAP operating earnings stand at $3.56 per share, up from $3.33 in the first nine months of 2025. Subtract $3.56 from the guidance range and the fourth quarter must deliver between $0.72 and $0.84 per share to land inside it; the midpoint of $4.34 implies a fourth quarter of about $0.78. That is a plausible winter quarter for a utility whose regulated earnings are seasonally weighted toward the summer. The honest summary is that the quarter tracked toward the middle of the range, not the top of it: $3.56 banked through nine months puts the company on course for the midpoint, and the top of the range would now require a fourth quarter of $0.84, a strong but not implausible winter print.
That distinction matters because the preview framed the top half as the confidence signal. Management declined to send it, and declined explicitly: when asked directly about tightening, LaRossa answered that the range was unchanged and the midpoint remained the right way to think about it. There is no narrowing to parse, no raised floor to celebrate, and no lowered ceiling to worry over. The next guidance event is now set: management said it expects to introduce 2027 non-GAAP operating earnings guidance, roll forward the capital plan, and update its rate-base and long-term growth outlooks on the year-end call in February 2027.
The utility: margin growth, absorbed by cost
PSE&G, the regulated utility, reported net income and non-GAAP operating earnings of $506 million for the quarter, down from $515 million a year earlier. The waterfall behind that small decline is the quarter in miniature. Transmission margin rose $0.02 per share on higher investment, and distribution margin rose $0.03 per share, reflecting higher investment in distribution and energy efficiency and a growing customer count. Those gains were more than offset on the expense side: distribution operations and maintenance rose $0.01 per share, depreciation and interest each rose $0.01 per share on incremental investment and debt refinanced at higher long-term rates, and taxes and other items had a net unfavorable impact of $0.04 per share, driven mostly by tax timing that the company said zeroes out over a full year.
PSE&G invested approximately $1.1 billion during the third quarter and remains on track for about $4.2 billion of regulated capital investment in 2026, within the five-year regulated program of $22.5 billion to $25.5 billion through 2030. The funding claim was repeated without change: the plan is to be funded without issuing new equity or selling assets, with liquidity of $3.9 billion at the end of September including more than $830 million of cash. Financing in the quarter fit that claim: PSE&G issued $1 billion of secured medium-term notes in August, $650 million of 10-year notes at 5.4% and $350 million of 30-year notes at 6.05%, redeeming $425 million of 2.25% notes at maturity in September, and PSEG Power issued $400 million of five-year senior notes at 5.55%.
The rate case, reframed
The preview identified the planned New Jersey base rate case, expected before the end of 2026, as the most consequential item on PSEG’s calendar. Monday’s call did not confirm a base rate case filing in those terms. What management said, instead, was that it anticipates filing a proposal with the New Jersey Board of Public Utilities to address the regulatory lag of capital investments made since the last distribution rate case. The language matters, and it should be quoted rather than paraphrased into something firmer: a proposal addressing regulatory lag is not necessarily a full base rate case, and management said it looks forward to providing more details shortly, without giving a filing date, a requested revenue figure, or a procedural schedule on the call.
The context offered was affordability: LaRossa cited two federal executive orders from earlier this year and “the Governor’s affordability agenda” as the spirit behind the proposal. Whether it proves a faster path to recovery or a smaller one cannot be judged until it is filed; what can be judged now is that the expected year-end filing has changed shape.
Two smaller regulatory items from the call cut in the customer’s favor and deserve recording. First, PJM has prospectively reduced wholesale transmission rates for PSE&G customers following a Federal Energy Regulatory Commission ruling earlier this year on transmission cost allocation, the product of the company’s collaboration with the state, and PSEG expects to file in early 2027 to credit those dollars back to retail customers. That is a customer benefit flowing from a federal proceeding, and it sits alongside the roughly $33 million of zonal transmission-customer savings from June through December 2026 that the company cited last quarter. Second, the Board of Public Utilities approved a 5% decrease in residential gas bills effective October 1, along with roll-ins effective the same date of a $14 million annual revenue increase under the Infrastructure Advancement Program and an $8 million annual increase for Clean Energy Future electric-vehicle investments, with bill impacts offset by a reduction in another filing.
One item the preview flagged drew no new word on Monday, and that silence should be recorded rather than filled in. The potential annual net-income headwind of roughly $40 million, or about $0.08 per share, from possible changes to the transmission return incentive beginning in 2027 was not updated in the prepared remarks or, as transcribed, in the Q&A. It remains a 2027 item carried forward from last quarter, not a resolved one, and belongs on the watch list for the February year-end call, when 2027 guidance arrives.
The nuclear fleet: the quarter’s clearest strength
If the utility’s quarter was margin growth absorbed by cost, the nuclear fleet’s quarter was the opposite: output up, costs down, earnings up. PSEG Power & Other reported non-GAAP operating earnings of $68 million, up from $50 million a year earlier, on net energy margin up $0.04 per share from higher generation and capacity prices and gas operations, and operations and maintenance down $0.02 per share. The cost decline has a specific, verifiable cause: the absence of last fall’s refueling and fuel-cycle extension work at Hope Creek, the company’s wholly owned unit, which had depressed the prior-year quarter. The fleet produced 8.2 terawatt-hours in the quarter at a 95.5% capacity factor, against the preview’s baseline of 7.9 terawatt-hours at 92.4% in the third quarter of 2025, and 23.9 terawatt-hours over the first nine months at a 94.3% capacity factor. Salem Unit 1 recently entered its fall refueling after a 491-day breaker-to-breaker run, matching Salem Unit 2’s back-to-back run earlier this year.
Capacity revenue is where the fleet’s forward story gets concrete. PSEG Power cleared approximately 3,600 megawatts of existing capacity in PJM’s July 2026 base residual auction at $325 per megawatt-day for the energy year running June 2028 through May 2029 — the top of the existing $175 to $325 per megawatt-day price collar, which management noted will continue in effect for December’s auction covering the 2029–2030 energy year. A clearing price at the collar’s cap is a market signal about regional scarcity, and LaRossa framed it as such: PJM “continues to have a significant resource adequacy problem and will require both existing and new generation to meet ever increasing electric demand in the region.” The December auction, and the delayed reliability backstop procurement auction now expected in March 2027 or later after FERC accepted some aspects of PJM’s reliability pricing proposal and rejected others, are the next data points on that story.
Contracting remains the open question the preview identified, and Monday’s call advanced it in tone more than in signed terms. Management said PSEG Power continues to develop terms with large-load entities for arrangements involving existing nuclear production, future nuclear upgrades, and other generation opportunities, similar to recently announced power purchase agreements in the PJM region and in New Jersey. No agreement was announced, no counterparty named, and no volume or price disclosed — and none should be inferred. The hedge position was described with unusual care: about 70 terawatt-hours of expected output sold forward as of September 30, more than 95% hedged for 2026, with realized prices historically aligned to the PECO zone at about a 20% discount to the PJM Western hub, a basis differential that has recently widened to about 30%. Management’s point, pressed repeatedly in the Q&A, was that its hedges are executed where its units actually price — at PECO, not at the Western hub — and that anyone modeling the fleet off Western hub prices will overstate its realized value.
What to watch next
Six markers, carried forward from the preview and updated with results. First, the fourth quarter against guidance: $0.72 to $0.84 per share lands inside the range, with about $0.78 marking the midpoint management pointed to. Second, the regulatory-lag proposal: its filing, its scope, and whether the Board treats it as a bridge to a full case or a substitute for one. Third, the early-2027 retail credit filing for the transmission-rate reduction, and the dollars attached to it when filed. Fourth, the December PJM capacity auction under the continuing $175 to $325 collar, and the March 2027 or later backstop auction. Fifth, nuclear contracting: whether any large-load arrangement moves from developed terms to an announced agreement, and on what disclosed terms. Sixth, the February 2027 year-end call, when 2027 guidance, the rolled-forward capital plan, and any update on the transmission return incentive should finally put numbers on the 2027 story this quarter only gestured toward.
PSEG’s third quarter is best read as a progress report that confirmed the thesis without accelerating it. The regulated business grew its margin through transmission and energy-efficiency investment and spent on pace toward a $4.2 billion year; the nuclear fleet ran at a 95.5% capacity factor and earned more on higher prices and lower outage costs; guidance was held at $4.28 to $4.40 with the midpoint, not the top, as the indicated destination; and the year’s most important regulatory event changed shape from a base rate case into an affordability-framed proposal to address regulatory lag. The quarter missed the consensus by a few cents and grew over the prior year by two. Both facts belong in the same sentence, because the distance between them is the distance between a market expectation and a regulated business’s actual pace.
None of this is investment advice, and nothing in this analysis recommends buying, selling, or holding any security. It is a reading of a reported quarter against the expectations set before it: a $1.15 operating print against a roughly $1.18 consensus, a guidance range reaffirmed but not narrowed, a rate-case calendar reframed, and a nuclear fleet whose performance can be measured in terawatt-hours and capacity factors rather than headlines.