AEP · Q3 2025 Earnings

Bullish

American Electric Power

Reported October 29, 2025

30-second summary

30-second take: AEP delivered Q3 operating EPS of $1.80 on revenue of $6.01B (+10.9% YoY) and reaffirmed FY2025 operating earnings at the upper half of $5.75–$5.95. The real news is forward: management raised the long-term operating EPS growth rate from 6–8% to 7–9% through 2030, initiated FY2026 EPS guidance at $6.15–$6.45 (midpoint $6.30, ~8% above the FY2025 guidance midpoint of $5.85 and squarely inside the new long-term range), expanded the five-year capital plan to $72B (from ~$70B last quarter), and lifted contracted load growth to 28 GW (from 24 GW). This is a structurally bigger, faster-growing AEP than the one investors owned ninety days ago — and the company is asserting it without flagging an equity raise as imminent.

Headline numbers

EPS

Q3 FY2025

$1.80

Revenue

Q3 FY2025

$6.01B

+10.9% YoY

Key financials

Q3 FY2025

Metric	Q3 FY2025	YoY	Q2 FY2025	QoQ
Revenue	$6.01B	+10.9%	$5.09B	+18.1%
EPS	$1.80	—	$1.43	+25.9%

Guidance

AEP reaffirms FY2025 EPS guidance but raises long-term growth outlook to 7–9%, increases capex plan to $72B, and discloses higher load growth (28 GW) and rate base expansion targets.

Guidance is issued for the full year only, refreshed each quarter. Prior and new below are the same FY updated this quarter.

New guidance

Metric	Period	Guide	YoY
Operating EPS (Non-GAAP)	FY2026	$6.15–$6.45	—
Rate Base Growth Target (CAGR 2026–2030)	FY2025	10% CAGR to $128 billion by 2030	—
Residential Customer Rate Increases	FY2025	~3.5% annually over 5-year period	—

Changes to prior guidance

Metric	Period	Prior guide	New guide	Δ	Result
Long-term Operating EPS Growth Rate	FY2025	6%–8%	7%–9%	+100 basis points at both low and high end	Raised
Capital Expenditure Plan (5-Year)	FY2025	~$70 billion	$72 billion	+$2 billion	Raised
Expected Load Growth (by 2030)	FY2025	24 GW (backed by signed customer agreements)	28 GW (backed by customer agreements)	+4 GW	Raised

Reaffirmed unchanged this quarter: Operating EPS (Non-GAAP) ($5.75–$5.95)

Other KPIs

Q3 FY2025

Segment	Q3 FY2025
Total Retail Electric (Vertically Integrated Utilities)	25,348 million kWh
Total Retail Electric (Transmission & Distribution Utilities)	28,084 million kWh
Commercial Load Growth (T&D)	30.4%
Expected Load Growth to 2030	28 GW (backed by customer agreements)
Peak System Demand Growth (2030)	65 GW (vs 37 GW current)
5-Year Capital Plan	$72 billion
Expected Rate Base CAGR (2026-2030)	10%
Long-Term Operating EPS Growth Rate	7-9% (through 2030)

Management tone

Q2-2025 capital plan preview (~$70B, contracted 24 GW load) → Q3-2025 plan upsize and growth-rate raise (7–9%, $72B, 28 GW)

Last quarter management previewed a 30% capital plan expansion with no equity announcement; this quarter they not only ratified it at $72B but layered on a 100-basis-point increase to the long-term growth rate, an FY2026 guide that brackets ~$6.30 midpoint, and a 10% rate base CAGR target. "We are extremely excited to announce our new increased long-term operating earnings growth rate of 7% to 9% for 2026 to 2030, with an expected 9% compounded annual growth rate over the five-year period." Utilities almost never raise long-term growth ranges without a multi-quarter setup; AEP did it one quarter after previewing the bigger plan. The signal: management has materially more confidence in execution than they had ninety days ago.

Load growth posture has hardened from "signed customer agreements" to a contracted hierarchy with explicit conservatism. Last quarter the 24 GW figure was framed as "signed customer agreements protecting us from usage volatility." This quarter management explicitly distinguished LOAs (with financial commitments) from ESAs (more binding) and stated they excluded LOAs unlikely to convert to ESAs from the 28 GW. "These incremental 28 gigawatts, up from our formerly reported 24 gigawatts, are backed by electric service agreements or letters of agreement, protecting us and our customers from changes in planned usage." Adding 4 GW while tightening the disclosure standard is the opposite of pulling forward marginal contracts to look bigger.

Capital discipline language has sharpened from "no immediate equity needs" to a more explicit framework. "We are applying a ruthless capital allocation lens to every dollar we deploy." Management disclosed that ~90% of the $72B plan is recovered through reduced-lag mechanisms, that the $5.9B of growth equity is back-loaded to 2027–2030, and that credit metrics are above the 13% Moody's downgrade threshold targeting 14% by end of 2026. The Q2 narrative ("we have optionality") is now Q3's structured financing plan with disclosed metric targets.

SMR posture moved from active-development to conditional-go. Last quarter SMR work was described as budgeted with $125M of Virginia regulatory recovery. This quarter the framing tightened: "Our moving forward with SMR considerations will require strong capital investment protections, safeguards for our balance sheet and credit metric strength, and clear regulatory and governmental support." This is not a retreat — it's a public statement that AEP will not commit capital without recovery certainty, which is what investors should want.

The CEO's positioning language has escalated. "This is a transformative moment for our industry, and I'm proud that AEP is standing out among our peers as one of the fastest-growing, high-quality, pure-play electric utilities." Q2's superlatives were about the industry environment ("growth I haven't seen in my 45-year career"); Q3's superlatives are explicit claims of peer outperformance. That is rare from a regulated utility CEO and worth weighing against execution risk on a plan that has expanded 33% in two quarters (from $54B to $72B).

Recurring themes management leaned on this quarter:

AI and hyperscaler-driven data center demand as primary load growth driverUltra-high voltage 765kV transmission superiority as competitive moat and customer attractorRegulatory framework improvements (formula rates, forward-looking test years, trackers) reducing lagLoad growth from 37 GW baseline to 65 GW peak demand by 2030 (76% system-wide growth)Disciplined capital allocation with 90% of $72B plan recovered through reduced-lag mechanismsCustomer affordability maintained at 3.5% annual residential rate increases vs 4% historical inflation

Risks management surfaced:

Regulatory lag risk in West Virginia (reconsideration filing pending on ROE, capital structure, rate base)Equity dilution risk mitigated by back-loading $5.9B growth equity to 2027-2030SMR execution requires strong capital investment protections and clear governmental supportMoody's credit rating pressure (currently above 13% downgrade threshold, targeting 14% by end of 2026)Grid reliability pressure from unprecedented demand growth requiring balanced generation and transmission investments

Q&A highlights

Ross Faller · Bank of America

What are the drivers of the significant earnings step-up in 2027-2028 shown on slide 14, and what is the schedule and timing for rate case filings?

Earnings driven primarily by capital plan peaking at $17 billion in mid-plan period (2027-2028). Positive regulatory outcomes include forward-looking test in Ohio, HB 5247 in Texas, and SB 998 in Oklahoma, all helping to narrow ROE gaps. Company confident of being at or above high end of 5.85%-6.30% growth range in back three years of plan with 9% TAGR overall.

Capital plan peaks at $17 billion mid-plan9% TAGR for overall earningsGrowth from 5.85%-6.30% midpoint in 2025-2026At or above high end of range in 2028-2030

Steve Fleishman · Wolfe Research

Is the 9% or better growth rate in 2028-2030 consistent/flat across those three years, and what is the difference between LOAs and ESAs for load growth projections?

2028-2030 growth modeled as pretty flat at or above 9% per year. LOAs (Letters of Agreement) are first step with financial obligations; ESAs (Energy Service Agreements) are more binding. In Texas ERCOT, only LOAs exist. Management emphasizes being conservative on the 28 GW figure by not including all signed LOAs, only those likely to convert to ESAs. 190 GW pipeline expected to ultimately generate 28 GW of incremental load.

2028-2030 modeled as flat, at or above 9% year-over-year28 GW of incremental load growth (up from 24 GW)190 GW in various stages of discussion backing the 28 GWLOAs have financial commitments but ESAs are more binding

Jeremy Tonnet · JPMorgan

What is the DPS CAGR in the dividend plan, particularly in the back part of the plan? Is the high-end guidance for 2028-2030 year-over-year or CAGR?

Board raised dividend by 2% going forward with target 50%-60% payout ratio due to robust capital plan. Dividends modeled as increasing with share count growth, with board discretionary increases. Board supportive of growing dividends over time; 115 consecutive years of dividend payments. EPS high-end guidance for 2028-2030 is year-over-year growth, not CAGR.

2% dividend increase announcedTarget payout ratio 50%-60%115 consecutive years of dividend paymentsDividends grow with share count in plan model

David Ocaro · Morgan Stanley

What is the current transmission capacity constraint situation for data center connections, wait times to connect customers, and how much of the transmission CapEx is dedicated to opening additional capacity?

Data center demand is 80% of 28 GW load growth (20% industrial). 75% T&D-related, 25% vertically integrated utilities. By RTO: ~50% ERCOT, 40% PJM, 10% SPP. Company working with customers on available transmission sites and behind-the-meter solutions (Bloom). AEP's 765 KV transmission network provides competitive advantage. Transmission CapEx will open additional opportunities from the 190 GW pipeline.

28 GW incremental load: 80% data centers, 20% industrial75% transmission/distribution, 25% vertically integrated~50% ERCOT, 40% PJM, 10% SPP distribution190 GW pipeline in various stages

Carly Davenport · Goldman Sachs

Are there LOAs outside of Texas included in the 28 GW plan, and what defines the gating factors differentiating those in the 28 GW vs. those not included? Also, does the transmission budget assume recent PJM open window opportunities?

LOAs exist across all RTOs: PJM has 100% LOA and ~80% ESA; SPP has 100% LOA with some ESA; ERCOT has 100% LOA only. All LOAs contain financial commitments. Transmission plan incorporates PJM open window opportunities and known existing transmission investments. Additional upside exists from incremental transmission investments beyond new transmission lines.

PJM: 100% LOA, ~80% ESASPP: 100% LOA, partial ESAERCOT: 100% LOA onlyAll LOAs have financial commitments

Answers to last quarter's watch list

Formal $70B capital plan announcement — Resolved upward at $72B (+$2B vs. the ~$70B preview). Plan peaks at $17B in 2027–2028. Management disclosed ~90% recovery through reduced-lag mechanisms and $5.9B growth equity back-loaded to 2027–2030. Status: Resolved positively

Equity issuance language — Management specified $5.9B of growth equity back-loaded to 2027–2030, not framed as an imminent ATM or block. Credit metric target of 14% by end of 2026 against the 13% Moody's downgrade threshold provides the operating constraint. Status: Resolved positively

24 GW signed load conversion — Raised to 28 GW (+4 GW) with a tightened disclosure standard (ESAs plus LOAs likely to convert to ESAs only). 190 GW pipeline remains the funnel. Status: Resolved positively

FY2025 EPS landing zone — Reaffirmed upper half of $5.75–$5.95, with YTD operating EPS of $4.78 implying Q4 operating EPS of roughly $1.07–$1.17. No further tightening of the range. Status: Continue monitoring

Treasury renewable tax credit guidance impact — Not addressed in the press release or in the Q&A excerpts. Status: Continue monitoring

SMR site permit progression — Management reframed SMRs as conditional on "strong capital investment protections, safeguards for our balance sheet, and clear regulatory and governmental support." No specific Indiana/Virginia milestones disclosed. Status: Continue monitoring

What to watch into next quarter

FY2025 Q4 landing — YTD operating EPS of $4.78 against an upper-half midpoint of $5.90 implies Q4 operating EPS of ~$1.12; watch whether AEP lands at or above $5.90 to validate the "upper half" framing

FY2026 guidance trajectory — The $6.15–$6.45 range (midpoint $6.30) implies ~8% growth off the FY2025 guidance midpoint of $5.85, consistent with the new 7–9% range; watch whether Q4 commentary tightens FY2026 upward as load conversions progress

West Virginia regulatory reconsideration outcome — Management flagged a pending reconsideration on ROE, capital structure, and rate base; this is the highest-profile near-term regulatory risk and will materially affect the earned-ROE gap narrative

Moody's credit metric trajectory — Currently above the 13% downgrade threshold targeting 14% by end of 2026; watch whether Q4 commentary tightens timing or if any incremental hybrids/junior subordinated debt are disclosed to defend the metric

Load conversion from 190 GW pipeline — Watch whether contracted load moves from 28 GW toward 30+ GW and whether ERCOT (currently LOA-only) develops a more binding contract structure

SMR governance update — Specifically watch for clarity on what "strong capital investment protections" means in practice — pre-approval mechanisms, CWIP recovery, or partnership structures

Sources

AEP Q3 2025 8-K press release, filed 2025-10-29: https://www.sec.gov/Archives/edgar/data/4904/000000490425000169/a3q20258kpressreleaseex991.htm
AEP Q3 2025 earnings call commentary (prepared remarks and Q&A)

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