AEE — Q2 2026 Financial Report Analysis

Revenue fell 6%, EPS rose 12% — the gap is a capacity-price collapse, not a demand problem

Ameren's second-quarter 2026 revenue dropped 5.8% to $2,092 million while diluted earnings per share rose 11.9% to $1.13. Those two numbers point in opposite directions for a reason that has almost nothing to do with how the business performed: the price the regional grid operator paid for generating capacity fell from $720 per megawatt-day in 2025 to $70 per megawatt-day in 2026, a 90% drop, and roughly the same amount vanished from both the revenue line and the fuel line.

Ameren Missouri's "off-system sales, capacity, transmission, and FAC revenues, net" fell $333 million in the quarter. Its fuel and purchased power energy costs fell $334 million. The two effectively cancel. This happens because Missouri's fuel adjustment clause (FAC) — a regulatory mechanism that passes prudently incurred energy costs through to customers rather than letting them hit shareholder earnings — recovers or refunds 95% of the difference between actual net energy costs and the amount baked into base rates. When wholesale energy and capacity prices swing, Ameren's top line swings with them and its profit largely does not.

Strip that out and the quarter was a fairly ordinary regulated-utility result: rate increases and rate base growth pushed earnings up, while operations and maintenance spending, depreciation and interest all grew faster than the underlying business.

Reported results

Utility-specific drivers:

Note on the term: operating margin is the share of revenue left after the costs of running the business, before interest and taxes. Ameren's margin jumped 3.4 points not because it got more efficient but because the shrinking revenue base had an equal-sized cost stripped out of it. On a dollar basis, operating income rose $48 million — that's the number that matters.

The two-thirds of revenue that is not a pass-through behaved normally. Natural gas revenue rose 12%, driven at Ameren Illinois by the November 2025 Illinois Commerce Commission order that raised annual gas delivery revenues by $79 million effective December 2, 2025. Ameren Illinois Electric Distribution revenue rose 10%, and Ameren Transmission revenue rose 10%, both on higher recoverable costs and a return on a larger asset base.

Where the $39 million of extra profit actually came from

The segment breakdown is more interesting than the consolidated figure.

The single largest contributor to the quarter was not a utility. The parent-company loss narrowed by $17 million — 44% of the total increase — and management attributes that mainly to a $28 million pre-tax increase in income from equity method investments "primarily associated with investments to advance innovative energy technologies," which swung from a net loss in 2025 to a gain in 2026. In the company's own per-share bridge, that item is worth 8 cents of the 12-cent EPS increase.

That deserves flagging. These are minority stakes in ventures outside the regulated utilities. They are not rate base, they earn no allowed return, and their mark-to-market contribution is lumpy by nature — the year-ago quarter was a loss. Two-thirds of the headline EPS growth in Q2 came from a line that could just as easily reverse. Over the six-month period the distortion is much smaller: the same item contributed 9 cents of a 33-cent increase, or 27%. The first quarter, in other words, was the cleaner one.

The genuinely repeatable earnings growth is in the other four segments, and it totals $22 million. Its sources, per management's per-share bridge for the quarter:

• 8 cents from higher allowance for equity funds used during construction (AFUDC) plus base-rate recovery of previously deferred interest under Missouri's PISA mechanism. AFUDC is an accounting credit utilities book for the cost of capital tied up in projects still under construction — it is non-cash earnings today that converts into cash once the asset enters rates. With Ameren Missouri's construction-work-in-progress balances climbing, this line is growing fast.
• 4 cents from higher Missouri electric base rates under the April 2025 rate order effective June 1, 2025, partly offset by the higher depreciation and interest those same rates now recover.
• 5 cents from the equity return on a larger rate base at Ameren Transmission and Ameren Illinois Electric Distribution. Rate base is the value of assets regulators let a utility earn a return on; growing it is how a regulated utility grows earnings.
• 1 cent from the absence of a 2025 revenue deferral tied to the retired Rush Island Energy Center, and 1 cent from the September 2025 Missouri gas rate increase.

Against that, four items went the other way: 11 cents from higher operations and maintenance spending at Ameren Missouri that falls outside any recovery rider, 3 cents from share issuance, 2 cents from higher financing costs, and 1 cent from milder weather.

Costs are growing faster than the rate base that funds them

The 11-cent O&M drag is the one to watch. Other operations and maintenance expense rose $61 million in the quarter and $67 million over six months, with Ameren Missouri accounting for $44 million and $58 million of that. The named causes are specific and mostly deliberate: $13 million more on non-nuclear generation reliability work at the Labadie and Sioux energy centers, $10 million more on tree trimming and other transmission and distribution work, $7 million more in amortized Callaway nuclear costs from the spring 2025 refueling outage, and $5 million more in injury and damage claims. A $4 million decline in storm costs partly offset it.

The problem is not the spending itself, it is the timing. Costs at Ameren Missouri that are not covered by a rider or tracker sit exposed until the next rate case resets base rates — the delay utilities call regulatory lag. Missouri's PISA mechanism solves this for capital investment (it lets Ameren defer and later recover 85% of depreciation on qualifying new plant and earn a return on 85% of the associated rate base between rate cases) but it does nothing for operating expense. Ameren Missouri absorbs this O&M until new rates take effect, which the pending case puts at June 2027 at the earliest.

Financing costs are compounding the same way. Interest charges rose $22 million in the quarter and $51 million over six months. At Ameren Missouri alone, $12 million of the quarterly increase came from debt issued in February 2026 and April 2025, and a further $5 million from the fact that interest previously deferred under PISA is now recovered in base rates instead of accruing as a deferral. Total debt stood at $21.8 billion at June 30 against $13.7 billion of common equity.

The regulatory book: one large case pending, the rest settled

In June 2026 Ameren Missouri filed for a $343 million annual electric revenue increase. The request is built on a 10.25% return on equity, a capital structure of 52% common equity, a $16.7 billion rate base, and a test year ended March 31, 2026 with a true-up expected through December 31, 2026. A Missouri Public Service Commission decision is expected by May 2027, with new rates effective by June 2027. Allowed ROE is the profit rate regulators permit on the equity portion of rate base; the requested 10.25% is above what Ameren currently earns in Illinois, and rate cases are typically settled or decided below the filed ask, so the eventual outcome is the largest single open variable in the 2027 earnings picture.

The rest of the book is comparatively quiet, and recent rulings have gone Ameren's way:

• In May 2026 the Illinois Appellate Court upheld the ICC's December 2024 multi-year rate plan order, which set electric distribution revenue requirements of $1,367 million for 2026 and $1,421 million for 2027. Ameren Illinois withdrew a related appeal in July 2026 as a result.
• The 2025 electric distribution reconciliation filing is proceeding toward a recommended $31 million recovery, with an ICC decision due by December 2026 and collection in 2027.
• Ameren Illinois' 2026 electric distribution allowed ROE is 8.72% — low relative to the sector, and a structural drag on that segment's returns.
• Ameren Illinois' appeal of the November 2025 gas rate order, which challenges a $75 million capital-plan reduction, remains pending with no court deadline.

Demand: 2.8 GW contracted, and none of it hits 2026

Ameren has now executed electric service agreements with large load customers representing 2.8 gigawatts of demand under Ameren Missouri's modified large primary service tariff, with construction agreements signed for 3.4 GW in total. That demand begins materializing in the second half of 2027 and reaches full capacity by the end of 2029. The company states plainly that it expects no material 2026 impact.

For scale, Ameren Missouri's own resource plan assumes total load growth of 1.5 GW by 2032 and 2.5 GW by 2040 — so 2.8 GW of signed agreements arriving by 2029 is ahead of the plan's own trajectory, which is why the capital program keeps expanding. The company also disclosed a $43 million increase in collateral posted by these large load customers, so the contracts carry credit protection.

Nothing in this quarter's numbers reflects any of it. Anyone buying AEE on the data-center demand story is buying 2028 and beyond.

The capital plan and how it gets paid for

Ameren invested $2.7 billion in its rate-regulated businesses in the first half, with capital expenditures up $523 million year over year, largely from the February 2026 acquisition of the Split Rail Solar Project for roughly $0.6 billion (placed in service in June 2026). The 2026–2030 plan calls for up to $33.1 billion — $22.2 billion at Ameren Missouri, $8.3 billion at Ameren Illinois, $2.6 billion at ATXI.

The cash math is the constraint. Over the first six months, operating cash flow was $1,191 million (down $102 million year over year, mostly a $223 million decline in tax credit transfers), investing used $2,706 million, and dividends took $414 million. That leaves a gap of roughly $1.9 billion in six months, filled with $1.8 billion of long-term debt issuance and $577 million of net commercial paper. Management states outright that it expects capital spending and dividends to exceed operating cash flow "over the next several years."

The equity side of the funding is largely pre-arranged, which limits near-term dilution risk. Ameren held forward sale agreements on 16.0 million shares at June 30 and added 1.4 million in July — a forward sale agreement locks in a share price today for issuance later, so the company has fixed its price without yet issuing the stock. Of these, 6.4 million shares settle in 2026 and roughly 11 million fund needs beyond 2026. Total planned equity issuance is about $4 billion from 2026 through 2030, and $417 million remains available under the at-the-market program. No shares were issued under that program during the first half.

Guidance and trajectory

Ameren reaffirmed 2026 diluted EPS guidance of $5.25 to $5.45, assuming normal temperatures for the last six months of the year.

That reaffirmation is more conservative than it looks. Ameren earned $5.35 in diluted EPS for full-year 2025. The 2026 guidance midpoint is also $5.35 — zero growth. And because first-half 2026 EPS of $2.41 is already 33 cents ahead of the $2.08 earned in the first half of 2025, the arithmetic implies a materially weaker second half:

Even the top of the range implies second-half EPS 7% below the year-ago second half. Several disclosed items point that way: the Callaway nuclear refueling and maintenance outage is scheduled for the fall of 2026, which raises deferred maintenance costs and purchased power needs; 6.4 million forward-sale shares settle this year, adding dilution that was only partly present in the first half; the elevated non-rider O&M at Ameren Missouri continues; and the equity method investment gains that carried two-thirds of the second quarter are not the kind of item a company builds into guidance. Guidance also assumes normal weather, whereas 2025 results were not weather-normalized.

Takeaway: The headline revenue decline is noise — a pass-through capacity-price collapse that costs Ameren almost nothing. The number that actually matters is buried in the guidance arithmetic: reaffirming $5.25–$5.45 after a first half that ran 33 cents ahead of last year commits Ameren to second-half EPS 7% to 13% below the prior-year second half, and roughly flat full-year earnings against 2025's $5.35. A regulated utility guiding to zero growth while spending $33 billion is telling you that the earnings from this capital cycle arrive after 2026, not during it.

Our view on trajectory. The investment case here is a timing question, not a quality question. The asset base is growing at a genuine clip — transmission rate base up 10% year over year, $2.7 billion deployed in six months, 2.8 GW of contracted large-load demand landing from late 2027 — and the regulatory constructs in both states (PISA in Missouri, formula and multi-year plans in Illinois) are designed to convert that spending into earnings with less lag than a traditional rate case. But three things sit between the plan and the payoff.

First, the Missouri rate case. A $343 million request at a 10.25% ROE will not be granted in full, and until new rates land in June 2027, Ameren Missouri absorbs the O&M inflation already visible in this quarter's 11-cent drag. That segment grew net income only 4.7% year over year despite carrying the largest share of the capital program.

Second, the funding gap. A $1.9 billion half-year shortfall between operating cash flow and capital-plus-dividends, funded with debt at rising rates, is why interest expense grew 11.8% while the business itself grew far less. The pre-arranged forward equity sales mitigate dilution risk but do not close the gap; the leverage does the rest. Cash flow coverage metrics are the thing to watch for credit-rating pressure, and management flagged working capital deficits at all three registrants at June 30.

Third, earnings quality. When a $28 million pre-tax swing on non-regulated venture investments supplies two-thirds of a quarter's EPS growth, the underlying regulated engine is running slower than the headline suggests. Four regulated segments added $22 million of net income on a $41.4 billion net plant base.

None of this is deterioration. It is a utility in the expensive middle of a build cycle, with the demand contracts signed and the cash costs arriving first. The guidance is honest about that. Investors should expect the second half to look worse than the first, and should judge the story on the May 2027 Missouri rate order and the 2027 arrival of large-load revenue rather than on anything in the next two quarters.

---

Source: Ameren Corporation Form 10-Q for the quarterly period ended June 30, 2026 (filed August 3, 2026, accession 0001002910-26-000023) and the Q2 2026 earnings release furnished on Form 8-K (filed July 30, 2026, accession 0001002910-26-000020). Full-year 2025 diluted EPS is as reported in Ameren's Form 10-K for the year ended December 31, 2025 (accession 0001002910-26-000009). Second-half figures labeled "implied" are computed from reported first-half results and the reaffirmed guidance range, and are not company projections for that period.