PEG · Q1 2026 Earnings
CautiousPublic Service Enterprise Group
Reported May 5, 2026
30-second summary
PSEG delivered Q1 non-GAAP EPS of $1.55 — ~36% of the $4.34 FY midpoint and above the $1.50 Q1-2025 watch threshold — but maintained rather than raised the $4.28–$4.40 FY2026 guide and reaffirmed the 6–8% CAGR through 2030 unchanged. The print is operationally clean (revenue +19.4% YoY to $3.85B, operating cash flow $1.27B +21.2% YoY) but the strategic levers analysts have been watching for four quarters — nuclear multi-year offtake contracts, NJ procurement mechanism crystallization, hedge disclosure for 2027 — all remained unresolved, with management redirecting each to pending stakeholder processes and BPU consultant studies due "this summer."
Headline numbers
EPS
Q1 FY2026
$1.55
Revenue
Q1 FY2026
$3.85B
+19.4% YoY
Operating margin
Q1 FY2026
27.9%
Key financials
Q1 FY2026| Metric | Q1 FY2026 | YoY | Q4 FY2025 | QoQ |
|---|---|---|---|---|
| Revenue | $3.85B | +19.4% | $2.92B | +32.0% |
| EPS | $1.55 | — | $0.72 | +115.3% |
| Operating margin | 27.9% | — | 17.5% | +1037bps |
Guidance
PSEG maintained FY2026 non-GAAP operating earnings guidance at $4.28–$4.40/share and reaffirmed long-term 6–8% CAGR through 2030; no forward Q2 guidance provided.
Guidance is issued for the full year only, refreshed each quarter. Prior and new below are the same FY updated this quarter.
Reaffirmed unchanged this quarter: Non-GAAP Operating Earnings Per Share ($4.28 - $4.40), Long-Term Non-GAAP Operating Earnings Growth (CAGR 2026–2030) (6% to 8% CAGR)
Segment KPIs
Q1 FY2026| Segment | Q1 FY2026 | YoY |
|---|---|---|
| PSE&G | $3.085B | +15.8% |
| PSEG Power & Other | $1.416B | +29.7% |
Other KPIs
Q1 FY2026| Segment | Q1 FY2026 |
|---|---|
| PSE&G Non-GAAP Operating Earnings | $577M |
| PSEG Power & Other Non-GAAP Operating Earnings | $201M |
| Electric Sales (Total) | 10,371 GWh |
| Gas Sales (Total) | 1,464 million therms |
| Nuclear Generation (NJ + PA) | 7,989 GWh |
| Operating Income Margin | 27.9% |
| Heating Degree Days (Actual) | 2,561 |
| Operating Cash Flow | $1,271M |
Management tone
Pipeline build-out → policy advocacy → growth-story selling → growth optionality → defensive engagement with restructuring.
Across four quarters the posture has migrated from selling load conversion, to lobbying for procurement, to pitching PSEG as the supply solution, to — this quarter — defensive engagement with a regulatory process management does not control. The shift is subtle but real. Last quarter's marketing-pitch language about "sites with grid connection capability and pipeline supplies" has been replaced with "we will continue our vigilance during the stakeholder process to advocate on behalf of PSEG's customers" — a phrase that appears twice in the call. Vigilance is not a growth posture; it is a posture for protecting an existing earnings base from regulatory restructuring risk.
Nuclear has been escalated again, but the framing has changed character. Three quarters ago it was a PTC-protected baseload asset; two quarters ago it was a "scarcity value" asset with uprate optionality; last quarter it was a contract-able earnings lever above the 6–8% CAGR. This quarter management introduced explicit competitive positioning for new construction: "PSEG is engaging in efforts to advance new nuclear development at PSEG's site, and we believe the site's unique strengths, including an early site permit, prime logistics, access to a skilled workforce...make it a leading candidate for new nuclear deployment." The new piece is "leading candidate" language — a beauty-contest framing aimed at the state task force. But notably absent is any announcement of a multi-year offtake contract, which management has named as the upside lever for two consecutive quarters now.
The NJ regulatory frame shifted from "policy window opening" to "business model under examination." Last quarter management positioned itself to be first in line for procurement; this quarter the BPU has opened an examination of the electric distribution utility business model itself, with a consultant study due summer 2026 and stakeholder process running through year-end. "We intend to fully engage with the BPU throughout this process." That is not the language of a company expecting near-term procurement awards — it is the language of a company defending its operating framework. The Q&A made this explicit: management expects "performance" (reliability, customer hookup, satisfaction) to be the framing axis of the business model review, which is a defensive talking-point selection.
Hedging language increased materially versus Q4. The tone extraction flags "expected," "based on our estimates," "we expect," and "subject to implementation" appearing more frequently. Combined with the absence of a Q2 forward EPS guide (PSEG does not typically issue one, but the contrast with the cleaner Q4 print is notable) and the maintenance — not narrowing — of the FY range despite Q1 tracking above pace, this is management telegraphing that they want more data points (summer performance, BPU study, PJM auction) before committing to any upside.
The ZEC-to-capacity transition is now formally complete. "Higher gas volume, and capacity revenues have more than offset the absence of the zero emission certificate program that concluded last May." This is the cleanest read on why Power & Other operating earnings can grow 29.7% on revenue with nuclear generation down 4.4% — and it validates the Q4 framing that the merchant-style upside is becoming a meaningful earnings contributor. But management is still not disclosing what merchant assumption is embedded in the 6–8% CAGR.
Recurring themes management leaned on this quarter:
Risks management surfaced:
Q&A highlights
Constantine · Wells Fargo
Questions on New Jersey BPU legislative process, cost of service model, ROE impact on affordability, and PGM capacity auction participation and cost allocation concerns.
Management stated that different branches are finding their footing with constructive conversations between companies, administration, legislators, and BPU. On PGM RBA, management emphasized the need to balance multiple planning assumptions from different states' IRPs, PJM, and customer requests, while protecting utilities from being burdened by external planning drivers. Committed to ensuring fair cost allocations for customers.
Carly Davenport · Goldman Sachs
Questions on New Jersey BPU Executive Order 1 stakeholder meeting focus areas and utility business model discussion; and nuclear opportunity participation on state task force.
Management expects performance to be a major discussion topic and welcomes it, highlighting exemplary performance in reliability, customer hookup, and satisfaction. On nuclear, management noted that the Sherrill administration is supportive and the lifting of the moratorium was a positive signal. Emphasized plans to continue advocating hard, noting Salem site advantages including completed port construction, strong local labor, and operational capabilities.
Jeremy Tornay · JP Morgan
Large load increase trends and current count of interested parties; bifurcation by state and impact of demand response on data center discussions.
Management reported current large load count at approximately 11,000 with directional leveling off after significant increase throughout prior year. Historically, 10-15-20% of pipeline converts to actual load. By state: absent significant tax incentives in New Jersey, sizable data center interest has not materialized; activity is following hyperscaler incentives in other states. Demand response has not materially changed conversation dynamics.
Nick Amesuchi · Evercore ISI
Salem capacity upgrade timing and relationship to license extension; and expectations for moving guidance given strong Q1 performance (36% of full-year guidance).
Management clarified that license extension (for 20-year period advance of 2036/2040 expiration) is not a gating factor for upgrades; upgrades expected in 2027 or 2029 outages. License extension activity will occur but upgrade timing is independent. On guidance, management indicated summer performance will be key determinant; normal year volatility includes winter/summer impacts and weather-driven elements.
Rene Singh · Bank of America
BGS auction repeatability of 1.8% bill reduction given potential capacity and energy price dynamics; and RBP proposal priorities for cost responsibility and planning accountability.
Management explained BGS mechanism procures third of load for three-year periods using locked capacity prices and energy forecasts. Energy price is biggest variable; $3 energy price impact results in $1 bill impact due to gradualism across three years. Noted prior year sticker shock resulted from capacity auction delay, not incremental price increases. On RBP, management emphasized planning process alignment is key; planning accountability should sit with same entity performing planning (LSEs), not burden utilities/EDCs since PJM already has transmission planning responsibility and states have IRP requirements.
Answers to last quarter's watch list
What to watch into next quarter
FY2026 guide narrowing on the Q2 print: Q1 landed at 36% of midpoint and summer performance is now explicitly named as the determinant. A raised floor (e.g. $4.32–$4.40) or narrowed range on Q2 would confirm the upside; a held range would signal a second-half drag management isn't yet flagging.
BPU consultant study release (summer 2026): this is now the single most important external event on the calendar. Watch whether the study endorses the existing cost-of-service model and PSE&G's performance framing, or whether it opens the door to performance-based ratemaking or business-model restructuring that compresses regulated returns.
Nuclear offtake or Salem task force seat: management has named contracting as the upside lever for three consecutive quarters without delivery. Watch the Q2 call for either a first announced multi-year offtake or a formal Salem task force role — either would substantiate the "leading candidate" framing.
Large-load pipeline movement vs. the 11 GW plateau: pipeline has been flat for two quarters and management explicitly conceded NJ economics are uncompetitive vs. PA. Watch whether the mature application bucket (last disclosed at 2,800 MW in Q3-2025) moves in either direction; sustained flatness with PA migration would force a downward revision of the data-center thesis.
FERC PJM cost-reallocation refund execution: management estimates "over $100M" in refunds to PSE&G customers post-PJM implementation. Watch for the timing of the refund and whether the bill credit is large enough to defuse affordability advocacy at the BPU.
Sources
- PSEG Q1 2026 press release, SEC Form 8-K Exhibit 99: https://www.sec.gov/Archives/edgar/data/788784/000119312526205254/d63722dex99.htm
- Q1 2026 earnings call Q&A (as referenced in Q&A and tone extractions)
- Tapebrief PEG Q4-2025 brief (FY2026 guide initiation and watch-list baseline)
- Tapebrief PEG Q3-2025 brief (large-load pipeline and capital plan trajectory)
- Tapebrief PEG Q2-2025 brief (multi-quarter narrative baseline)
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