AEE

Utilities

Ameren

Price Chart

Market Data

Financials

XBRL · SEC EDGAR

2007–2025(19yr)

Revenue

Net Income

Free CF

Metric	FY 2007	FY 2008	FY 2009	FY 2010	FY 2011	FY 2012	FY 2013	FY 2014	FY 2015	FY 2016	FY 2017	FY 2018	FY 2019	FY 2020	FY 2021	FY 2022	FY 2023	FY 2024	FY 2025Latest	YoY
Revenue	$7.6B	$7.8B	$7.1B	$7.6B	$7.5B	$6.8B	$5.8B	$6.1B	$6.1B	$6.1B	$6.2B	$6.3B	$5.9B	$5.8B	$6.4B	$8.0B	$7.5B	$7.6B	$8.8B	+15.4%
Operating Income	$1.4B	$1.4B	$1.4B	$916.0M	$1.2B	-$1.2B	$1.2B	$1.3B	$1.3B	$1.4B	$1.5B	$1.4B	$1.3B	$1.3B	$1.3B	$1.5B	$1.6B	$1.5B	$2.0B	+33.6%
Operating Margin	18.0%	17.4%	19.8%	12.0%	16.5%	-18.2%	20.3%	20.7%	20.6%	22.7%	23.6%	21.6%	21.4%	22.4%	20.8%	19.0%	20.8%	19.9%	23.0%	+3.1pp
Net Income	$618.0M	$605.0M	$612.0M	$139.0M	$519.0M	-$974.0M	$289.0M	$586.0M	$630.0M	$653.0M	$523.0M	$821.0M	$834.0M	$877.0M	$995.0M	$1.1B	$1.2B	$1.2B	$1.5B	+23.1%
Net Margin	8.2%	7.7%	8.6%	1.8%	6.9%	-14.3%	5.0%	9.7%	10.3%	10.7%	8.5%	13.1%	14.1%	15.1%	15.6%	13.6%	15.4%	15.6%	16.6%	+1.0pp
Free Cash Flow	-$273.0M	-$372.0M	$257.0M	$781.0M	$848.0M	$450.0M	$314.0M	-$234.0M	$100.0M	$47.0M	-$28.0M	-$116.0M	-$241.0M	-$942.0M	-$1.3B	-$1.1B	-$1.0B	-$1.6B	-$775.0M	+50.2%
FCF Margin	-3.6%	-4.7%	3.6%	10.2%	11.3%	6.6%	5.4%	-3.9%	1.6%	0.8%	-0.5%	-1.8%	-4.1%	-16.3%	-20.2%	-13.7%	-13.8%	-20.4%	-8.8%	+11.6pp
EPS (Diluted)	$2.98	$2.85	$2.58	$0.58	$2.15	$-4.01	$1.18	$2.40	$2.59	$2.68	$2.14	$3.32	$3.35	$3.50	$3.84	$4.14	$4.38	$4.42	$5.35	+21.0%

Total Debt$19.4B

Cash & Equiv.$13.0M

Net Debt$19.4B

4 min read

1. THE BIG PICTURE

Ameren is a high-margin utility machine currently trading its near-term cash flow for long-term rate-base growth through a $33.1 billion capital plan. While Ameren leads its peer group in operating and net margins, its success is less a product of market competition and more a result of navigating the complex regulatory frameworks of Missouri, Illinois, and the FERC. The central tension for Ameren is whether it can maintain its premium profitability while managing the operational and political risks of a massive, multi-year infrastructure overhaul.

2. WHERE THE RISKS HIT HARDEST

Ameren’s "strong strategic capital allocation" is directly threatened by regulatory rate recovery risks because its financial results are "largely outside of [its] control" (10-K Item 1). If the Missouri Public Service Commission or the Illinois Commerce Commission denies full recovery of the $33.1 billion in planned investments, Ameren's ability to earn its allowed return on equity would be severely impaired.

Furthermore, the "diverse fuel portfolio" management cites as a strength is increasingly a liability. The reliance on coal-fired generation creates substantial environmental risks; if Ameren Missouri cannot recover the costs of complying with the Clean Air Act or the CCR Rule through rates, it faces potential asset impairments that would undermine the very infrastructure growth driving its current valuation (Risks).

3. WHAT THE NUMBERS SAY TOGETHER

The financial data reveals a "utility paradox": Ameren boasts the highest net margin (18.1%) and operating margin (24.5%) in its peer group, yet it produces a negative free cash flow (FCFFCFFree Cash Flow — cash left after paying for operations and capital investments; what the company can actually spend, save, or return to shareholders) margin of -10.5% (XBRL). This discrepancy highlights that while the business is fundamentally profitable on an accounting basis, it is currently a cash-burning enterprise due to the scale of its infrastructure build-out.

Ameren’s revenue growth of 15.4% (TTMTTMTrailing Twelve Months — the most recent full year of financial data, updated on a rolling basis each quarter) is the second-highest among its peers, significantly outpacing PPL’s 6.9% and FE’s 12.0%. This growth is being driven by new electric service rates and infrastructure investments, particularly in the Ameren Missouri and Ameren Transmission segments, which saw GAAPGAAPGenerally Accepted Accounting Principles — the standard U.S. accounting rules all public companies must follow earnings rise to $747 million and $415 million, respectively, in 2025 (8-K). However, rising interest expenses—which contributed to a $145 million loss at the Ameren Parent level—signal that the cost of financing this growth is increasing. Short interest stands at 3.4% of the float, suggesting a modest level of market skepticism regarding Ameren's ability to maintain this trajectory without further straining its balance sheet.

4. IS IT WORTH IT AT THIS PRICE?

At a 19.1x forward P/EP/EPrice-to-Earnings ratio — share price divided by annual earnings per share; how much investors pay per dollar of profit. Higher P/E = higher growth expectations, the market is pricing in approximately 2.2% long-term growth (CAPM analysis). This valuation represents a 6% premium to the peer median of 17.9x. This premium appears justified by Ameren’s superior margin profile—its 18.1% net margin is double that of DTE (9.2%) and ES (8.8%).

The 2.2% implied growth rate is conservative relative to Ameren’s recent 15.4% revenue growth, suggesting the market is already accounting for the "regulatory lag" and the potential for cost disallowances. If growth were to align more closely with GDP at 2.5%, the justified multiple would rise to 20.3x. However, the primary factor that could compress this multiple is a shift in the regulatory climate; if regulators become less permissive of rate hikes to fund the $33.1 billion CapExCapExCapital Expenditures — money spent on physical assets like factories, servers, or infrastructure plan, investors will likely demand a higher yield, pushing the price down.

5. WHAT WOULD CHANGE THIS VIEW?

Cautious if the 2025 Change to the 2023 PRP encounters significant delays or if the Big Hollow Battery Energy Storage Project faces cost overruns that regulators refuse to subsidize.
Cautious if interest expenses at the Ameren Parent level continue to widen, indicating that the cost of debt is eroding the returns from infrastructure investments.
Constructive if the "large load customer rate plan" results in signed contracts with data centers that exceed current load growth projections, providing a non-regulatory catalyst for revenue.

6. BOTTOM LINE

Structural Advantage: A regulated monopoly position reinforced by an integrated transmission system that experiences the least amount of regulatory lag within Ameren's portfolio. Bottom Line: Ameren is a premium-margin utility whose valuation is fairly tethered to its ability to execute a massive, regulator-approved building spree.

Source: Synthesis · LLM Analysis

4 min read

1. Top 5 Material Risks

Regulatory Rate Recovery: Ameren’s results are heavily dependent on rates determined by the MoPSC, ICC, and FERC. Regulatory lag, cost disallowances, and the potential for regulators to deny full recovery of prudently incurred costs threaten Ameren's ability to earn its allowed return on equity (ROEROEReturn on Equity — net income as a percentage of shareholder equity; how efficiently a company uses the capital investors have put in).
Capital Expenditure Execution: Ameren plans to invest up to $33.1 billion from 2026 through 2030. Failure to complete these projects within projected schedules and budgets—or failure to secure regulatory approval for cost recovery—could adversely affect liquidity and financial position.
Environmental Compliance: Compliance with the Clean Air Act, Clean Water Act, and CCR Rule requires significant capital expenditures. If Ameren Missouri cannot recover these costs through rates, it faces potential asset impairments and reduced revenues, particularly regarding its coal-fired energy centers.
Aging Infrastructure: A significant portion of Ameren’s generation, transmission, and distribution assets are aging, increasing the risk of unplanned outages and higher maintenance expenses. Ameren faces the risk that regulators may not allow the recovery of remaining investments or decommissioning costs upon the retirement of these assets.
Energy Demand Volatility: While Ameren projects growth from data centers and electrification, actual demand may fall short of forecasts. If large load customers terminate agreements or reduce capacity, Ameren may struggle to fully recover its investments in assets built specifically to serve that demand.

2. Company-Specific Risks

Nuclear Generation Liabilities: Ownership of the Callaway Energy Center subjects Ameren to unique risks, including the long-term storage of spent nuclear fuel, potential retrospective insurance premium assessments, and the need for costly seismic risk updates.
Illinois MYRP Reconciliation Cap: Ameren Illinois’ electric distribution rates are subject to a 105% reconciliation cap under its Multi-Year Rate Plan (MYRP), which may prevent the full recovery of actual costs if they exceed the ICC-approved revenue requirement.
Coal Supply Concentration: Approximately 96% of Ameren Missouri’s coal is sourced from the Powder River Basin, making Ameren vulnerable to supply disruptions caused by rail congestion, derailments, or supplier financial hardship.
PISA Revenue Limitations: Ameren Missouri’s ability to increase its annual revenue requirement via Plant In-Service Accounting (PISA) deferrals is capped at 2.25% (prorated monthly for requirements approved after August 2025), limiting the recovery of incremental capital expenditures.

3. Regulatory/Legal Risks

FERC Penalties: Ameren is subject to mandatory NERC reliability standards; violations can result in civil penalties of approximately $1.6 million per violation per day.
Illinois Ethics Compliance: Under the CEJA, the ICC can investigate the use of customer funds for ethical violations, potentially imposing penalties of up to $0.5 million per violation and requiring customer refunds.
Rate Order Appeals: Regulatory rate orders are subject to intervention and appeal, creating uncertainty regarding the final rates Ameren is permitted to charge.
Emissions Limits: Ameren Missouri’s natural gas-fired energy centers in Illinois face mandatory emission reductions under the CEJA, which could force the closure of the Venice Energy Center by 2029 and others by 2040.

4. Financial Impact Map

Regulatory Rate Recovery → Results of Operations/Liquidity → Impacts the ability to earn allowed ROEROEReturn on Equity — net income as a percentage of shareholder equity; how efficiently a company uses the capital investors have put in and recover prudently incurred costs.
Capital Expenditure Execution → Liquidity and Capital Resources → Requires significant financing; failure to recover costs through rates impacts the balance sheet and cash flow.
Environmental Compliance → Results of Operations/Asset Impairment → Potential for significant capital expenditures and write-downs if costs are not recoverable through base rates.
Aging Infrastructure → Maintenance Expense/Rate Base → Higher operating costs and potential for unrecovered investment upon early retirement of assets.
Energy Demand Volatility → Revenue/Rate Base → Risk of stranded costs and under-recovery of revenue requirements if forecasted demand does not materialize.

Source: 10-K Item 1A · LLM Analysis

Recent Filings

Form	Filed	Period
10-K	Feb 2026	Dec 2025
8-K	Feb 2026	—
10-Q	Nov 2025	Sep 2025
14A	Mar 2025	—