EXC · Q2 2025 Earnings
BullishExelon
Reported July 31, 2025
30-second summary
30-second take. Exelon delivered $0.39 in non-GAAP EPS on $5.43B of revenue (+1.2% YoY) and reaffirmed its FY2025 EPS guide of $2.64–$2.74, with management explicitly committing to "midpoint or better" of the 5–7% long-term EPS CAGR through 2028. The more important signal isn't the print — it's the rhetorical pivot: management used the call to argue PJM's capacity market is structurally failing to deliver supply, and is positioning Exelon to build or contract regulated generation across Maryland, Pennsylvania, Delaware, and New Jersey. The 17 GW large-load pipeline is "holding firm" with another 16 GW in study, and a $10–15B incremental transmission opportunity sits beyond the already-committed $38B 2024–2028 capex plan.
Headline numbers
EPS
Q2 FY2025
$0.39
Revenue
Q2 FY2025
$5.43B
+1.2% YoY
Operating margin
Q2 FY2025
17.1%
Key financials
Q2 FY2025| Metric | Q2 FY2025 | YoY |
|---|---|---|
| Revenue | $5.43B | +1.2% |
| EPS | $0.39 | — |
| Operating margin | 17.1% | — |
Guidance
Prior quarter data unavailable — comparison not possible.
Segment KPIs
Q2 FY2025| Segment | Q2 FY2025 | YoY |
|---|---|---|
| ComEd | $1.836B | -11.7% |
| PECO | $1B | +12.2% |
| BGE | $1.029B | +10.9% |
| PHI | $1.579B | +7.3% |
Other KPIs
Q2 FY2025| Segment | Q2 FY2025 |
|---|---|
| ComEd Adjusted Operating Earnings | $228 million |
| PECO Adjusted Operating Earnings | $136 million |
| BGE Adjusted Operating Earnings | $55 million |
| PHI Adjusted Operating Earnings | $144 million |
| Total Electric Customers | 7.8 million |
| Total Natural Gas Customers | 2.9 million |
| Operating Margin | 17.1% |
| FY2025 EPS Guidance | $2.64-$2.74 |
Management tone
Capacity market posture has flipped from accommodation to confrontation. For years Exelon's framing of PJM was that the wholesale market would, eventually, price in scarcity and pull supply forward. This quarter management explicitly broke from that view: "despite higher prices we are not seeing the market respond fast enough... States have an opportunity to proactively bring control, certainty, and cost benefits by pursuing options outside of the capacity market, including regulated generation." That's a regulated utility holding company telling its state regulators that the deregulated market they sit inside of is broken — and offering to fill the gap. It signals management has decided the political window for utility-owned generation is open, and they intend to walk through it.
Large load has moved from "opportunity" to "imperative." The 17 GW pipeline number has been disclosed before, but the language around it sharpened materially: "Time remains of the essence in adding supply to the grid." Management paired this with a new ComEd cluster study window closing in August (several incremental GW indicated) and a separate quantum computing campus anchored by SciQuantum that is already attracting co-location interest — explicitly flagged as upside not in current guidance. The shift is from steady-state queue management to active demand orchestration.
Capex framing has gone transformational. Management is now layering a $10–15B incremental transmission opportunity on top of the committed $38B 2024–2028 plan, with transmission capex growth running ~30% versus a historical 8–10%. The Q4 plan refresh will fold cluster study results, transmission, and new business into a single updated multi-year view. This is no longer rate-base growth from steady reinvestment; it's a build-out narrative.
The midpoint-or-better commitment is unusually firm. "By earning a fair return on equity of 9% to 10% on a rate base growing at 7.4%, through 2028... we expect to grow our earnings at an annualized rate of 5% to 7%, with the expectation of delivering at the midpoint or better of that range." Most regulated utilities guide to a range and leave it at that. Explicitly committing to midpoint-or-better is a confidence statement that constrains management's own optionality.
Weather has been re-categorized from operational noise to planning constraint. The $0.03 PECO storm hit and repeated framing of "increasingly unpredictable and volatile weather" suggest extreme weather is now an input to capex planning rather than a quarterly variance item.
Recurring themes management leaned on this quarter:
Risks management surfaced:
Q&A highlights
Paul A. Zimbardo · Jefferies
Which jurisdiction is most ripe for further action on utility-owned generation, energy efficiency, or storage? And could Maryland opportunities be ready for Q4 refresh given the October procurement deadline?
Management highlighted Maryland's 3,000 MW procurement (decision by October) as the key near-term trigger for potential utility-owned generation action. Pennsylvania, Maryland, and Delaware all have active legislative processes. Three requirements identified: certainty, state control over customer benefits, and diverse short/mid/long-term solutions. Timing for Q4 refresh depends on procurement outcomes; clarity expected sometime next year with no speculation until confirmed.
Anthony Crodell · Mizuho
Timing for $10-15 billion transmission opportunity to move into base plan; equity financing assumptions; and upside from Illinois quantum computing campus beyond data center thematic?
Transmission will be incorporated into Q4 2024 plan update via cluster studies (fall clarity), ComEd grid plan (filed 2026), and BGE filings. Transmission capex has grown ~30% vs. historical 8-10% growth rate. 40% equity financing rule of thumb applied. Quantum computing campus (SciQuantum anchor tenant) represents separate upside opportunity not yet built into guidance; additional interest already arriving from other companies wanting to co-locate.
David Arcaro · Morgan Stanley
Willingness to build regulated or contracted generation; data center discussions progress and timeline for firming up megawatts; tariff changes and cluster study timeline?
Company willing to pursue regulated generation if structured correctly (policy matters). Three requirements: certainty, state control/benefits, and customer value. Views regulated and competitive market as 'and' not 'or.' Half of PJM states already use hybrid approach. Data center activity spans Illinois, Pennsylvania, Maryland. Cluster studies in Illinois and mid-Atlantic expect results Q3/Q4 2024. ComEd filed tariff changes for projects 50+ MW to provide certainty for new customers while protecting existing base.
Carly Davenport · Goldman Sachs
Timeline and gating factors for large load pipeline phases; BGE bill impacts from PJM capacity auction results and shifts in customer bill rhetoric?
Large load progression: 10% online by 2028, one-third by 2030, three-fourths by 2034. Phases designed to reflect project confidence levels; do not expect material barriers. BGE bill impact ~$1.50 per month; system-wide impacts range $1.50-$4 per month. Previous BGE auction results lower than prior auction. Acknowledges broader recognition that supply costs drive bills; states and commissions need to engage on complementary solutions (efficiency, demand response) beyond PJM market.
Paul A. Zimbardo · Jefferies
Follow-up: Could Maryland storage/generation opportunities be ready for Q4 refresh given short timeline to procurement decision?
Management deferred specific Q4 timing, stating clarity will come 'sometime next year' depending on procurement outcomes. Emphasized deliberate, transparent approach; will not speculate before clarity confirmed. Promised to share timelines as soon as internally determined.
What to watch into next quarter
Maryland 3,000 MW procurement decision (October) — concrete trigger for whether Exelon enters a utility-owned generation contract. A win here would be the first tangible execution of the regulated-generation pivot.
ComEd August cluster study window close and Q3/Q4 mid-Atlantic cluster results — these convert the 16 GW "under study" pipeline into either firm commitments or attrition. Watch whether the 17 GW firm pipeline number moves up materially.
Q4 plan refresh: how much of the $10–15B transmission opportunity moves into the base $38B plan, and whether the 2024–2028 EPS CAGR floor moves up from 5–7% midpoint-or-better to something tighter.
Open regulatory cases — Delmarva, Atlantic City Electric, ComEd reconciliation, and Maryland MYP. Watch for ROE awards relative to the 9–10% range management is underwriting in the EPS algorithm.
Q3 EPS — management guided to ~29% of FY midpoint, implying roughly $0.78. A miss here would force a tougher Q4 to hold the $2.64–$2.74 range.
Storm cost trajectory — after $0.03 PECO drag this quarter, watch whether storm-related O&M starts pressuring the FY guide if Q3 hurricane season is active.
Sources
- Exelon Q2 2025 earnings press release (Exhibit 99.1, filed 2025-07-31): https://www.sec.gov/Archives/edgar/data/1109357/000110935725000167/exc-20250731ex991.htm
- Exelon Q2 2025 earnings call commentary (as captured in extraction inputs)
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