Ameren (AEE) Risk Analysis

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Public companies are required to disclose risks that can affect the business and impact the stock. These disclosures are known as “Risk Factors”. Companies disclose these risks in their yearly (Form 10-K), quarterly earnings (Form 10-Q), or “foreign private issuer” reports (Form 20-F). Risk factors show the challenges a company faces. Investors can consider the worst-case scenarios before making an investment. TipRanks’ Risk Analysis categorizes risks based on proprietary classification algorithms and machine learning.

Ameren disclosed 19 risk factors in its most recent earnings report. Ameren reported the most risks in the “Production” category.

Risk Overview Q2, 2025

Risk Distribution

42% Production

32% Legal & Regulatory

11% Ability to Sell

11% Macro & Political

5% Finance & Corporate

0% Tech & Innovation

Finance & Corporate - Financial and accounting risks. Risks related to the execution of corporate activity and strategy

This chart displays the stock's most recent risk distribution according to category. TipRanks has identified 6 major categories: Finance & corporate, legal & regulatory, macro & political, production, tech & innovation, and ability to sell.

Risk Change Over Time

2022

S&P500 Average

Sector Average

Risks removed

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Risks changed

Ameren Risk Factors

New Risk (0)

Risk Changed (0)

Risk Removed (0)

No changes from previous report

The chart shows the number of risks a company has disclosed. You can compare this to the sector average or S&P 500 average.

The quarters shown in the chart are according to the calendar year (January to December). Businesses set their own financial calendar, known as a fiscal year. For example, Walmart ends their financial year at the end of January to accommodate the holiday season.

Risk Highlights Q2, 2025

Main Risk Category

Production

With 8 Risks

Production

With 8 Risks

Number of Disclosed Risks

No changes from last report

S&P 500 Average: 31

No changes from last report

S&P 500 Average: 31

Recent Changes

0Risks added

0Risks removed

0Risks changed

Since Jun 2025

0Risks added

0Risks removed

0Risks changed

Since Jun 2025

Number of Risk Changed

No changes from last report

S&P 500 Average: 3

No changes from last report

S&P 500 Average: 3

See the risk highlights of Ameren in the last period.

Risk Word Cloud

The most common phrases about risk factors from the most recent report. Larger texts indicate more widely used phrases.

Risk Factors Full Breakdown - Total Risks 19

Production

Total Risks: 8/19 (42%)Above Sector Average

Manufacturing2 | 10.5%

Manufacturing - Risk 1

Our electric generation and electric and natural gas transmission and distribution facilities, including natural gas storage facilities, are subject to operational risks.

Our financial performance depends on the successful operation of electric generation and electric and natural gas transmission and distribution facilities, including natural gas storage facilities. Operation of these facilities involves many risks, including: - facility shutdowns due to operator error, or a failure of equipment or processes;- longer-than-anticipated maintenance outages;- failures of equipment that can result in unanticipated liabilities or unplanned outages;- aging infrastructure that may require significant expenditures to operate and maintain;- natural gas leaks or explosions near populated areas, including residential areas, business centers, industrial sites, and other public gathering places;- lack of adequate water required for cooling plant operations and to operate hydroelectric energy centers;- labor disputes;- disruptions in the delivery of electricity and natural gas to our customers;- inability to maintain reliability of our electric utility services as coal-fired energy centers are retired and renewable energy generation is placed in service, as well as our ability to meet generation capacity obligations;- disruptions to the global supply chain as a result of shortages for labor, materials, or equipment, tariffs and international trade relations, geopolitical conflict, delivery delays, and economic pressures, including elevated interest rates and inflation, among other things;- suppliers and contractors who do not perform as required under their contracts, including those obligations that are affected by supply chain disruptions;- failure of other operators' facilities and the effect of that failure on our electric and natural gas systems and customers;- inability to comply with regulatory requirements or obtain permits, including those relating to environmental laws;- handling, storage, and disposition of CCR;- unusual or adverse weather conditions or other natural disasters, including but not limited to those that may result from climate change, such as severe storms, droughts, wildfires, floods, tornadoes, earthquakes, icing, sustained high or low temperatures, solar flares, and electromagnetic pulses;- the level of wind and solar resources;- inability to operate wind generation facilities at full capacity resulting from requirements to protect natural resources, including wildlife, or other conditions limiting full capacity, such as the 2024 collapse of three turbines at the High Prairie Energy Center; pending the results of an ongoing investigation, approximately 90% of the turbines of the High Prairie Energy Center remain idle and the timing and costs necessary to return the energy center to full capacity are uncertain;- the occurrence of catastrophic events such as fires, explosions, acts of sabotage, which have increased in frequency and severity within the utility industry, acts of terrorism, civil unrest, pandemic health events, or other similar events;- accidents that might result in injury or loss of life, extensive property damage, or environmental damage;- ineffective vegetation management programs;- cybersecurity risks, including loss of operational control of Ameren Missouri's energy centers and our transmission and distribution systems and loss of data, including sensitive customer, employee, financial, and operating system information, through insider or outsider actions;- limitations on amounts of insurance available to cover losses that might arise in connection with operating our electric generation facilities, electric and natural gas transmission and distribution facilities, and natural gas storage facilities;- inability to implement or maintain information systems;- failure to keep pace with and the ability to adapt to rapid technological change; and - other unanticipated operations and maintenance expenses and liabilities. The foregoing risks could affect the operations of our facilities, impede our ability to meet regulatory requirements, or expose us to an increase in litigation, which could increase operating costs, increase our capital requirements and costs, reduce our revenues, or have an adverse effect on our liquidity.

Manufacturing - Risk 2

Ameren Missouri's ownership and operation of a nuclear energy center creates business, financial, and waste disposal risks.

Ameren Missouri's ownership of the Callaway Energy Center subjects it to risks associated with nuclear generation, including: - potential harmful effects on the environment and human health resulting from radiological releases associated with the operation of nuclear facilities and the storage, handling, and disposal of radioactive materials;- continued uncertainty regarding the federal government's plan to permanently store spent nuclear fuel and, as a result, the need to provide for long-term storage of spent nuclear fuel at the Callaway Energy Center;- limitations on the amounts and types of insurance available to cover losses that might arise in connection with the Callaway Energy Center or other United States nuclear facilities;- uncertainties about contingencies and retrospective insurance premium assessments relating to claims at the Callaway Energy Center or other United States nuclear facilities;- public and governmental concerns about the safety and adequacy of security at nuclear facilities;- limited availability of fuel supply and our reliance on licensed fuel assemblies from primarily one NRC-licensed supplier of Callaway Energy Center's assemblies;- costly and extended outages for scheduled or unscheduled maintenance and refueling;- uncertainties about the technological and financial aspects of decommissioning nuclear facilities at the end of their licensed lives;- the ability to continue to attract and retain qualified labor to operate the Callaway Energy Center;- the adverse effect of poor market performance and other economic factors on the asset values of nuclear decommissioning trust funds and the corresponding increase, upon MoPSC approval, in customer rates to fund the estimated decommissioning costs; and - potential adverse effects of a natural disaster, acts of sabotage or terrorism, including a cyber attack, or any accident leading to a radiological release. The NRC has broad authority under federal law to impose licensing and safety requirements for nuclear facilities. In the event of noncompliance, the NRC has the authority to impose fines or to shut down a unit, or both, depending upon its assessment of the severity of the situation, until compliance is achieved. Revised safety requirements promulgated from time to time by the NRC could necessitate substantial capital expenditures at the Callaway Energy Center. In addition, if a serious nuclear incident were to occur and result in serious injury, loss of human life, significant damage to property, environmental impacts, and impairment of our operations, it would adversely affect Ameren's and Ameren Missouri's results of operations, financial condition, and liquidity. A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation of any domestic nuclear unit and could also cause the NRC to impose additional conditions or requirements on the industry, which could increase costs and result in additional capital expenditures. While the Callaway Energy Center is in compliance with the current NRC standards relating to seismic design and risk, these standards also require Ameren Missouri to address periodic changes to seismic hazard data and evaluation methods for the impact of an earthquake on its Callaway Energy Center due to its proximity to a fault line, which could require seismic risk evaluation updates and installation of additional capital equipment.

Employment / Personnel1 | 5.3%

Employment / Personnel - Risk 1

We are subject to employee workforce factors that could adversely affect our operations.

Our businesses depend upon our ability to employ and retain key officers and other skilled professional and technical employees. Certain specialized knowledge that focuses on skilled-craft and STEM-related disciplines is required to construct and operate generation, transmission, and distribution assets. Further, a significant portion of our work force is nearing retirement. As of December 31, 2024, approximately 23% of Ameren's, Ameren Missouri's, and Ameren Illinois' total employees were 55 years old or older. We are also party to collective bargaining agreements that collectively represent about 46%, 59%, and 55% of Ameren's, Ameren Missouri's and Ameren Illinois' total employees, respectively. The Ameren Missouri collective bargaining unit contracts expire in 2025 and 2026, and cover 4% and 96% of represented employees, respectively. The Ameren Illinois collective bargaining unit contracts expire in 2026 and 2027, and cover 92% and 8% of represented employees, respectively. Certain events, such as significant delays in finding appropriate replacement talent, inadequately trained replacement employees, a mismatch of skill sets to future needs, or any work stoppage experienced in connection with negotiations of collective bargaining agreements could adversely affect our operations.

Supply Chain1 | 5.3%

Supply Chain - Risk 1

Ameren Missouri's ability to obtain an adequate supply of coal could limit operation of its coal-fired energy centers.

Ameren Missouri owns and operates coal-fired energy centers. About 97% of Ameren Missouri's coal is purchased from the Powder River Basin in Wyoming, which has a limited number of suppliers. Deliveries from the Powder River Basin have occasionally been restricted because of rail congestion, staffing and equipment issues, infrastructure maintenance, derailments, weather, and supplier financial hardship. As of December 31, 2024, coal inventory at the Labadie and Sioux energy centers were at targeted levels. Delays or disruptions in the delivery of coal, failure of our coal suppliers to provide adequate quantities or quality of coal, or lack of adequate inventories of coal, including low-sulfur coal used to comply with environmental regulations, could have adverse effects on Ameren Missouri's electric generation operations. If Ameren Missouri is unable to obtain an adequate supply of coal under existing agreements, it may be required to purchase coal at higher prices or be forced to reduce generation at its coal-fired energy centers, which could adversely affect Ameren's and Ameren Missouri's results of operations, financial position, and liquidity.

Costs4 | 21.1%

Costs - Risk 1

The construction and acquisition of, and capital improvements to, electric and natural gas utility infrastructure, along with Ameren Missouri's ability to implement its Smart Energy Plan and its 2025 Change to the 2023 PRP, involve substantial risks.

We expect to make significant capital expenditures to maintain and improve our electric and natural gas utility infrastructure and to comply with existing environmental regulations. We estimate that we will invest up to $27.4 billion (Ameren Missouri – up to $17.5 billion; Ameren Illinois – up to $7.0 billion; ATXI – up to $2.9 billion) of capital expenditures from 2025 through 2029. For additional information on these estimates, see Liquidity and Capital Resources – Capital Expenditures in Management's Discussion and Analysis of Financial Condition and Results of Operations under Part II, Item 7, of this report. Investments in Ameren's rate-regulated operations are expected to be recoverable from customers, but they are subject to prudence reviews and are exposed to regulatory lag of varying degrees by jurisdiction. Our ability to complete construction projects successfully within projected estimates, including schedule, performance, and/or cost, and to implement Ameren Missouri's Smart Energy Plan, which may include acquisition of generation facilities after they are constructed, is contingent upon many factors and subject to substantial risks. These factors include, but are not limited to, the following: project management expertise; the ability of suppliers, contractors, and developers to meet contractual commitments and timely complete projects, which is dependent upon the availability of necessary labor, materials, and equipment; escalating costs, including but not limited to changes to tariffs on materials or government actions; changes in the scope and timing of projects; the ability to obtain required regulatory, project, and permit approvals; the ability to obtain necessary rights-of-way, easements, and transmission connection agreements at an acceptable cost in a timely fashion; unsatisfactory performance by the projects when completed; the inability to earn an adequate return on invested capital; the ability to raise capital on reasonable terms; geopolitical conflict and other events beyond our control, including delays arising from government shutdowns or construction delays due to weather. With respect to the transition of Ameren Missouri's generation fleet that will be included in its 2025 Change to the 2023 PRP and carbon emission reduction targets, factors also include Ameren Missouri's ability to obtain CCNs from the MoPSC, and any other required approvals for the addition of renewable resources, battery storage, or nuclear or natural gas-fired generation, retirement of energy centers, and new or continued customer energy-efficiency programs; the ability to enter into agreements for renewable, natural gas-fired, or nuclear generation and acquire or construct that generation at a reasonable cost; the ability to obtain NRC approval for an extension of the operating license for the Callaway Energy Center beyond its current 2044 expiration date; the continued existence and ability to qualify for, and use or transfer, federal production or investment tax credits; the cost of wind, solar, and other renewable generation and battery storage technologies; the cost of natural gas or hydrogen CT technologies; the cost of nuclear generation; the ability to maintain system reliability during and after the transition to clean energy generation; new and/or changes in environmental regulations, including those related to CO2 and other greenhouse gas emissions; energy prices; and demand. Any of these risks could result in higher costs, the inability to complete anticipated projects, or facility closures, and could adversely affect our results of operations, financial position, and liquidity.

Costs - Risk 2

In 2024 through at least 2027, electric distribution rates for Ameren Illinois are established through an MYRP, which are subject to ongoing regulatory and judicial proceedings and associated risks, and are subject to a reconciliation cap. Additionally, Ameren Illinois is subject to certain performance metrics that if not achieved would result in a reduction to the company's allowed ROE.

The CEJA resulted in changes to the regulatory framework applicable to Ameren Illinois' electric distribution business by giving Ameren Illinois the option to file an MYRP with the ICC or establish rates through a traditional regulatory rate review, among other things. An MYRP establishes rates for a four-year period, and Ameren Illinois has the option to file for an MYRP every four years. Ameren Illinois elected to file an MYRP for rates effective in 2024 through 2027. Under the MYRP, Ameren Illinois is allowed to reconcile its actual electric distribution revenue requirement, as adjusted for certain cost variations, to the ICC-approved revenue requirement on an annual basis, subject to a reconciliation cap. The reconciliation cap limits the annual adjustment to 105% of the annual revenue requirement approved by the ICC. Certain variations from forecasted costs are excluded from the reconciliation cap, including those associated with major storms; new business and facility relocations; changes in the timing of certain expenditures or investments into or out of the applicable calendar year; and changes in interest rates, income taxes, taxes other than income taxes, pension and other post-retirement benefits costs, and amortization of certain assets. The reconciliation cap also excludes costs recovered outside of base rates through riders. The actual revenue requirement for a particular year incorporates Ameren Illinois' year-end rate base and actual capital structure for such year, provided that the resulting revenue requirement does not exceed the 105% reconciliation cap and the common equity ratio in such capital structure may not exceed that approved by the ICC in the MYRP. Ameren Illinois' existing riders continue to be effective under the MYRP. In addition, the ICC determines the ROE applicable to each year of the four-year period. Economic conditions could result in the annual predetermined ROE becoming inadequate over the four-year period. Ameren Illinois has filed an appeal of the ICC-determined ROE for 2024 through 2027 to the Illinois Appellate Court for the Fifth Judicial District. For additional information on the appeal see Note 2 – Rate and Regulatory Matters under Part II, Item 8, of this report. Failure to limit capital expenditures and operation and maintenance expenses to amounts that maintain revenue requirements under the reconciliation cap limit would adversely affect Ameren's and Ameren Illinois' results of operations, financial position, and liquidity. Ameren Illinois' electric distribution service business is also subject to performance metrics. Failure to achieve the metrics would result in a reduction in the company's allowed ROE calculated under the MYRP. In 2022, the ICC issued an order approving total ROE incentives and penalties of 24 basis points under the MYRP, allocated among seven performance metrics. These performance metrics include improvements in service reliability in both the frequency and duration of outages, a reduction in peak loads, an increased percentage of spend with diverse suppliers, a reduction in disconnections for certain customers, and improved timeliness in response to customer requests for interconnection of distributed energy resources. These performance metrics apply annually from 2024 through 2027 under the MYRP, and the impact of any incentives and penalties will be excluded from the reconciliation cap described above. In addition, the allowed ROE on energy-efficiency investments can be increased or decreased up to 200 basis points, depending on the achievement of annual energy savings goals. Any adjustments to the allowed ROE for energy-efficiency investments will depend on annual performance for a historical period relative to energy savings goals.

Costs - Risk 3

Significant portions of our electric generation, transmission, and distribution facilities and natural gas transmission and distribution facilities are aging. This aging infrastructure may require significant additional maintenance or replacement. Ameren Missouri could be adversely affected if it is unable to recover the remaining investment, if any, and decommissioning costs associated with the retirement of an energy center, as well as the ability to earn a return on that remaining investment and those decommissioning costs.

Our aging infrastructure may pose risks to system reliability and expose us to expedited or unplanned significant capital expenditures and operating costs. Both of Ameren Missouri's coal-fired energy centers were constructed prior to 1978, and the Callaway Energy Center began operating in 1984. The age of these energy centers increases the risks of unplanned outages, reduced generation output, and higher maintenance expense. Further, Ameren Missouri would be adversely affected if the MoPSC does not allow recovery of the remaining investment and decommissioning costs associated with the retirement of an energy center, as well as the ability to earn a return on that remaining investment and those decommissioning costs. Aging transmission and distribution facilities are more prone to failure than new facilities, which results in higher maintenance expense and the need to replace these facilities with new infrastructure. Even when the system is properly maintained, its reliability may ultimately deteriorate and negatively affect our ability to serve our customers, which could result in increased costs subject to regulatory recovery risk. The frequency and duration of customer outages are among the CEJA performance standards. Any failure to achieve these standards will result in a reduction in Ameren Illinois' allowed ROE on electric distribution assets. The higher maintenance costs associated with aging infrastructure and capital expenditures for new or replacement infrastructure, compounded by high interest rates and inflationary pressures, could cause additional rate volatility for our customers, resistance by our regulators to allow customer rate increases, and/or regulatory lag in some of our jurisdictions, any of which could adversely affect our results of operations, financial position, and liquidity.

Costs - Risk 4

Significant increases in prices of labor, services, materials and supplies and other costs, including costs associated with our defined benefit retirement and postretirement plans, health care plans, and other employee benefits, could adversely affect our results of operations, financial position, or liquidity.

A part of our core strategy focuses on disciplined cost management, including prudently monitoring all of our expenses. Higher than expected inflation levels could continue to put pressure on the prices of labor, services, materials and supplies, and other costs. Elevated inflation levels, as well as elevated interest rates, tariffs, trade wars, or a recession could impact our ability to control costs, to make substantial investments in our businesses, to recover costs and investments, to earn our allowed ROEs within frameworks established by our regulators, and/or to maintain affordability of our services for our customers. In addition, these various economic pressures could adversely affect our customers' usage of, or payment for, our services. Additionally, volatility in the commodities market could increase collateral postings and prepayments. Also, market volatility could significantly affect the investment performance of Ameren's COLI. Significant increases in our costs could increase our financing needs and otherwise adversely affect our results of operations, financial position, and liquidity. Related to benefits, Ameren has defined benefit pension plans covering substantially all of its employees and has postretirement benefit plans covering non-union employees hired before October 2015 and union employees hired before January 2020. Assumptions related to future costs, returns on investments, interest rates, timing of employee retirements, and mortality, as well as other actuarial matters, have a significant impact on our customers' rates and our plan funding requirements. Ameren's total pension and postretirement benefit plans were overfunded by $734 million as of December 31, 2024. Ameren expects to fund its pension plans at a level equal to the greater of the pension cost or the legally required minimum contribution. Based on its assumptions at December 31, 2024, its investment performance in 2024, and its pension funding policy, Ameren does not expect to make material contributions in 2025 and expects to make aggregate contributions of $170 million in 2026 through 2029. Ameren Missouri and Ameren Illinois estimate that their portion of the future funding requirements will be 40% and 50%, respectively. These estimated contributions may change based on actual investment performance, changes in interest rates, changes in our assumptions, changes in government regulations, and any voluntary contributions. In addition to the costs of our pension plans, the costs of providing health care benefits to our employees and retirees have increased in recent years. We believe that our employee benefit costs, including costs of health care plans for our employees and former employees, will continue to rise. Future legislative changes related to health care could also significantly change our benefit programs and costs.

Legal & Regulatory

Total Risks: 6/19 (32%)Above Sector Average

Regulation3 | 15.8%

Regulation - Risk 1

We are subject to extensive regulation of our businesses.

We are subject to federal, state, and local regulation. The extensive regulatory frameworks, some of which are more specifically identified in the following risk factors, regulate, among other matters, the electric and natural gas utility industries; the rate and cost structure of utilities, including an allowed ROE; the operation of nuclear power plants; the construction and operation of generation, transmission, and distribution facilities; the acquisition, disposal, depreciation and amortization of assets and facilities; the electric transmission system reliability; and wholesale and retail competition. In the planning and management of our operations, we must address the effects of existing and proposed laws and regulations and potential changes in our regulatory frameworks, including reinterpretation of such regulations, as well initiatives by federal and state legislatures, RTOs, utility regulators, and taxing authorities, and actions by local jurisdictions that may affect the constructing or siting of facilities. Significant changes in the nature of the regulation of our businesses, including expiration or discontinuation of, or significant changes to, existing regulatory mechanisms, and the current federal administration's approach to United States energy policy and resultant changes in regulatory enforcement priorities, and/or evolving interpretations of existing regulatory requirements, could require changes to our business planning, strategy and management of our businesses and could adversely affect our results of operations, financial position, and liquidity. Failure to obtain adequate rates or regulatory approvals in a timely manner; failure to obtain necessary licenses or permits from regulatory authorities; the impact of new or modified laws, regulations, standards, interpretations, or other legal requirements; or increased compliance costs could adversely affect our results of operations, financial position, and liquidity.

Regulation - Risk 2

The electric and natural gas rates that we are allowed to charge are determined through regulatory proceedings, which are subject to intervention and appeal. Rates are also subject to legislative actions, which are largely outside of our control. Certain events could prevent us from recovering our costs in a timely manner or at all, or from earning adequate returns on our investments.

The rates that we are allowed to charge for our utility services significantly influence our results of operations, financial position, and liquidity. The electric and natural gas utility industry is highly regulated. The utility rates charged to customers are determined by governmental entities, including the MoPSC, the ICC, and the FERC. Decisions by these entities are influenced by many factors, including the cost of providing service, the prudency of expenditures, the quality of service, regulatory staff knowledge and experience, customer intervention, and economic conditions, as well as social and political views. Decisions made by these governmental entities regarding customer rates are largely outside of our control. We are exposed to regulatory lag, including the impact of inflationary pressures, and cost disallowances to varying degrees by jurisdiction, which, if unmitigated, could adversely affect our results of operations, financial position, and liquidity. Rate orders are also subject to appeal, which creates additional uncertainty as to the rates that we will ultimately be allowed to charge for our services. From time to time, our regulators may approve riders or other recovery mechanisms that allow electric or natural gas rates to be adjusted without a traditional regulatory rate review. These mechanisms could be changed or terminated. Ameren Missouri's electric and natural gas utility rates and Ameren Illinois' natural gas utility rates are typically established in regulatory proceedings that take up to 11 months to complete. Ameren Missouri's electric and natural gas utility rates established in those proceedings are based on historical costs, revenues, and sales volumes. Ameren Illinois' natural gas rates established in those proceedings are based on estimated future costs, revenues, and sales volumes. Effective for rates in 2024 through at least 2027, Ameren Illinois' electric distribution rates have been established through an MYRP as discussed in the following risk factor. An MYRP includes a revenue requirement reconciliation, which may not allow for full recovery of actual costs due to a reconciliation cap. Thus, the rates that we are allowed to charge for utility services may not match our actual costs at any given time. Rates include an allowed return on investments established by the regulator, including a return at the applicable WACC on rate base, and an amount for income taxes based on the currently applicable statutory income tax rates and amortization associated with excess deferred income taxes. Although rate regulation is premised on providing an opportunity to earn a reasonable rate of return on rate base, there can be no assurance that the regulator will determine that our costs were prudently incurred or that the regulatory process will result in rates that will produce full recovery of such costs or provide for an opportunity to earn a reasonable return on those investments. Ameren Missouri and Ameren Illinois, and the utility industry generally, have an increased need for cost recovery and to earn a return on investments, primarily driven by capital investments, which is likely to continue in the future. The resulting increase to the revenue requirement needed to recover such costs and earn a return on investments could result in more frequent regulatory rate reviews and requests for cost recovery mechanisms. Additionally, increasing rates could result in regulatory or legislative actions, as well as competitive or political pressures, all of which could adversely affect our results of operations, financial position, and liquidity. In addition, in June 2024, the MoPSC issued a financing order authorizing the issuance of securitized utility tariff bonds by a wholly owned, special purpose subsidiary of Ameren Missouri to finance approximately $476 million of costs related to the accelerated retirement of the Rush Island Energy Center, which included the remaining unrecovered net plant balance associated with the facility, among other costs. Ameren Missouri will collect the amounts necessary to repay the bonds over approximately 15 years from the date of bond issuance. The securitized tariff bonds were issued in December 2024. The financing order also included a determination that the decision to retire the Rush Island Energy Center was reasonable and prudent. The MoPSC did not make a determination regarding the prudency of Ameren Missouri's prior actions that resulted in the adverse ruling in the NSR and Clean Air Act litigation discussed in Note 14 – Commitments and Contingencies under Part II, Item 8, of this report, however, claims regarding such actions could be considered in future regulatory proceedings. If future regulatory proceedings result in revenue reductions based on Ameren Missouri's prior actions that resulted in the adverse ruling in the NSR and Clean Air Act litigation, it could have a material adverse effect on the results of operations, financial position, and liquidity of Ameren and Ameren Missouri.

Regulation - Risk 3

We are subject to regulatory compliance and proceedings, which could result in increasing costs, regulatory penalties, and/or other sanctions.

We are subject to FERC regulations, rules, and orders, including standards required by the NERC. As owners and operators of bulk power transmission systems and electric energy centers, we are subject to mandatory NERC reliability standards, including cybersecurity standards. In addition, our natural gas transmission, distribution, and storage facilities systems are subject to PHMSA rules and regulations. Compliance with these reliability standards, rules, and regulations may subject us to higher operating costs and may result in increased capital expenditures. We may also incur higher operating costs to comply with potential new executive orders, regulations, or reinterpretations of existing regulations issued by these regulatory bodies. If we were found not to be in compliance with these mandatory NERC reliability standards, PHMSA rules and regulations, or FERC regulations, rules, and orders, we could incur substantial monetary penalties and other sanctions, which could adversely affect our results of operations, financial position, and liquidity. The FERC can impose civil penalties of approximately $1.6 million per violation per day for violation of its regulations, rules, and orders, including mandatory NERC reliability standards. The FERC also conducts audits and reviews of Ameren Missouri's, Ameren Illinois', and ATXI's accounting records to assess the accuracy of their respective formula ratemaking process, and it can require refunds to be issued to customers for previously billed amounts, with interest. Additionally, pursuant to the CEJA, Illinois utilities are subject to requirements and provisions related to ethical conduct, including submitting an annual ethics and compliance report to the ICC. The law authorizes the ICC to initiate an investigation into how customer funds were used if a violation of the law is determined to have occurred at an Illinois utility, potentially requiring the utility to issue refunds and imposing a penalty of up to $0.5 million per violation.

Taxation & Government Incentives1 | 5.3%

Taxation & Government Incentives - Risk 1

As a result of the election to use the PISA, Ameren Missouri's electric service business is subject to a limitation on increasing the annual revenue requirement due to the inclusion of incremental PISA deferrals in the revenue requirement.

Pursuant to a Missouri law, Ameren Missouri's PISA election was extended through December 2028 and an additional extension through December 2033 is allowed if requested by Ameren Missouri and approved by the MoPSC, among other things. This law also established a 2.5% annual limit on increases to the electric service revenue requirement used to set customer rates, compared to the revenue requirement established in the immediately preceding rate order, due to the inclusion of incremental PISA deferrals in the revenue requirement. The limitation is effective for revenue requirements approved by the MoPSC after January 1, 2024. Increased capital expenditures could cause incremental PISA deferrals to exceed the 2.5% limitation, and such amounts exceeding the 2.5% limitation would be excluded from recovery under future revenue requirements. Failure to limit capital investments to an amount which maintains PISA deferrals under the 2.5% limitation could adversely affect Ameren's and Ameren Missouri's results of operations, financial position, and liquidity.

Environmental / Social2 | 10.5%

Environmental / Social - Risk 1

We are subject to various environmental and permitting laws. Significant capital expenditures may be required to achieve and to maintain compliance with these environmental laws. Failure to comply with these laws could result in the closing of facilities, alterations to the manner in which these facilities operate, increased operating costs, delays and increased costs of building new facilities, and exposure to fines and liabilities.

Our electric generation, transmission, and distribution and natural gas distribution and storage operations must comply with a variety of statutes and regulations relating to the protection of the environment and human health and safety, including permitting programs implemented by federal, state, and local authorities. Such environmental laws regulate air emissions; protect water bodies; manage the handling and disposal of hazardous substances and waste materials; siting and land use requirements; and potential ecological impacts. Complex and lengthy processes are required to obtain and renew approvals, permits, and licenses for new, existing, or modified energy-related facilities. Additionally, the use and handling of various chemicals or hazardous materials require release prevention plans and emergency response procedures. Further, we are subject to risks from changing or conflicting interpretations of existing laws, modifications to existing laws, new laws, new or modified permit terms, and enforcement of environmental laws and permits by federal, state, and local authorities. We are also subject to liability under environmental laws that address the remediation of environmental contamination on property currently or formerly owned by us or by our predecessors, as well as property contaminated by hazardous substances that we generated. Such properties include MGP sites, substations, and third-party sites, such as landfills. Additionally, individuals and non-governmental organizations may seek to enforce environmental laws against us, allege injury from exposure to hazardous materials, allege a failure to comply with environmental laws, seek to compel remediation of environmental contamination, or seek to recover damages resulting from purported contamination. Environmental regulations have a significant impact on the electric utility industry and compliance with these regulations could be costly for Ameren Missouri, which operates coal-fired and natural gas-fired energy centers. As of December 31, 2024, Ameren Missouri's coal-fired energy centers represented 6% and 11% of Ameren's and Ameren Missouri's rate base, respectively. Compliance obligations under the Clean Air Act include the NSPS, the MATS, emission allowance programs and the CSAPR, and the National Ambient Air Quality Standards, which are subject to periodic review for certain pollutants. Collectively, these regulations cover a variety of pollutants, such as SO2, particulate matter, NOx, mercury, toxic metals and acid gases, and CO2 emissions. Regulations implementing the Clean Water Act govern potential impacts from our operations on water bodies including wetlands subject to the Act, as well as evaluation of the ecological and biological impact of those operations. Implementation of the Clean Air Act and the Clean Water Act requirements typically occurs through the issuance of permits by state regulators or resource agencies, and capital expenditures associated with compliance could be significant. Coal-fired energy centers must comply with management and disposal requirements for coal ash under the Resource Conservation and Recovery Act and federal regulations known as the CCR Rule. Surface impoundments at Ameren Missouri's coal-fired energy centers are subject to closure and groundwater monitoring requirements and the implementations of corrective measures if necessary. The individual or combined effects of compliance with existing and new environmental regulations could result in significant capital expenditures, increased operating costs, or the closure or alteration of operations at some of Ameren Missouri's energy centers. In April 2024, the EPA issued a final rule that sets CO2 emission standards for existing coal-fired and new natural gas-fired power plants based on the emissions expected from adoption of carbon capture technology and/or natural gas co-firing for coal-fired power plants and carbon capture technology for new natural gas-fired power plants. Affected power plants are required to comply with the rule through a phased-in approach or retire. Compliance with the new rule could be required as early as 2030 for certain existing coal-fired power plants and 2032 for certain new natural gas-fired power plants. In December 2024, the United States Court of Appeals for the District of Columbia Circuit heard arguments from various stakeholders including the EPA, environmental organizations, state attorney generals, and industry groups regarding the legal merits of the final rule. In February 2025, the EPA requested that the appellate court suspend the case for 60 days and not issue an opinion so the EPA can decide how to proceed. Ameren and Ameren Missouri estimate capital expenditures of approximately $580 million may be necessary to comply with the final rule assuming it is not revised or overturned. Ameren and Ameren Missouri are monitoring the legal challenges and assessing the impacts of the final rule and, at this time, cannot predict the final impacts on their results of operations, financial position, and liquidity. Currently as required by the CEJA, Ameren Missouri's natural gas-fired energy centers in Illinois are subject to annual limits on emissions, including CO2 and NOx. Further reductions to emissions limits will become effective between 2030 and 2040, resulting in the closure of the Venice Energy Center by the end of 2029. The reductions could also limit the operations of Ameren Missouri's four other natural gas-fired energy centers located in the state of Illinois, and will result in their closure by 2040. These energy centers are utilized to support peak loads. Subject to conditions in the CEJA, these energy centers may be allowed to exceed the emissions limits in order to maintain reliability of electric utility service. Ameren and Ameren Missouri have incurred, and expect to incur, significant costs with respect to environmental compliance and site remediation. New or revised environmental regulations, enforcement initiatives, or legislation could result in a significant increase in capital expenditures and operating costs, decreased revenues, penalties or fines, reduced operations or closure of some of Ameren Missouri's coal-and natural gas-fired energy centers, which, in turn, could lead to increased liquidity and financing needs, and higher financing costs. Actions required to ensure that Ameren Missouri's facilities and operations are in compliance with environmental laws could be prohibitively expensive for Ameren Missouri if the costs are not fully recovered through rates. Environmental laws could require Ameren Missouri to close or to alter significantly the operations of its energy centers. If Ameren Missouri requests recovery of capital expenditures and costs for environmental compliance through rates, the MoPSC could deny recovery of all or a portion of these costs, prevent timely recovery, or make changes to the regulatory framework in an effort to minimize rate volatility and customer rate increases. Capital expenditures and costs to comply with future legislation or regulations could result in Ameren Missouri closing coal-fired energy centers earlier than planned. If these costs are not recoverable through base rates or other regulatory mechanisms, it could lead to an impairment of assets and reduced revenues. Any of the foregoing could have an adverse effect on our results of operations, financial positions, and liquidity.

Environmental / Social - Risk 2

We are subject to business and financial risks related to the impact of climate change legislation, regulation, and emission reduction initiatives.

There is concern and activism among various external stakeholders, both nationally and internationally, about climate change, including public concerns about the potential environmental impacts from the combustion of fossil fuels, as well as pressure from public interest groups regarding limiting the use of natural gas. Also, state and local authorities have proposed restrictions on the use of natural gas, and the ICC is conducting a future of gas proceeding to explore issues involved with decarbonization of the natural gas distribution system in the state of Illinois. Further, federal, state, and local authorities, including the United States Congress, have considered initiatives to further restrict greenhouse gases to address global climate change, and the EPA previously announced plans to implement new climate change programs, including regulation of greenhouse gas emissions from the utility industry. Additionally, international agreements have in the past, and could again, lead to future federal or state legislation or regulations. In 2015, the United Nations Framework Convention on Climate Change reached consensus among approximately 190 nations on an agreement, known as the Paris Agreement, that establishes a framework for greenhouse gas mitigation actions by all countries, with a goal of holding the increase in global average temperature to below 2 degrees Celsius above pre-industrial levels and an aspiration to limit the increase to 1.5 degrees Celsius. In accordance with the new presidential administration's approach to United States energy policy, in January 2025, the United States withdrew from the Paris Agreement. The current federal administration is expected to review, and has already revised, compliance requirements under a number of federal environmental regulatory programs; however, differences in energy policy priorities adopted by future federal administrations could result in additional greenhouse gas reduction requirements in the United States. As a result of our diverse fuel portfolio, our emissions of greenhouse gases vary among our energy centers, but coal-fired power plants are significant sources of CO2 emissions. Future federal and state legislation or regulations that mandate limits on the emission of, or impose taxation on, greenhouse gases could result in a significant increase in capital expenditures and operating costs, decreased revenues, penalties or fines, or reduced operations of some of Ameren Missouri's coal- and natural gas-fired energy centers, which, in turn, could lead to increased liquidity and financing needs, and higher financing costs. Moreover, to the extent Ameren Missouri requests recovery of these costs through rates, its regulators might deny some or all of, or defer timely recovery of, these costs. Excessive costs to comply with future legislation or regulations related to climate change might force Ameren Missouri to close its remaining coal-fired energy centers earlier than planned, which could lead to possible loss on abandonment and reduced revenues. As a result, mandatory limits could have a material adverse impact on Ameren's and Ameren Missouri's results of operations, financial position, and liquidity. Ameren is targeting net-zero carbon emissions by 2045, as well as a 60% reduction by 2030 and an 85% reduction by 2040 based on 2005 levels in a safe, reliable, and affordable manner. Ameren's goals include both reduction of direct emissions from operations (scope 1), as well as electricity usage at Ameren buildings (scope 2), including other greenhouse gas emissions of methane, nitrous oxide, and sulfur hexafluoride. Achievement of these targets is dependent on many factors, including the pace and extent of development and deployment of low- to zero-carbon energy technologies and carbon capture technologies, the cost of those technologies, and support of such technologies by regulators; natural gas prices; new transmission infrastructure; the ability to maintain system reliability during and after the transition to clean energy generation; and constructive energy and economic policies, including those that address investment in energy infrastructure, global climate change, incentives for clean energy technologies, and environmental regulations. Additional factors associated with operational risks for the construction and acquisition of electric and natural gas infrastructure may also affect the achievement of these goals, as further discussed below. The strategy to achieve these goals also relies on continuing to pursue a diverse portfolio, including low-carbon and carbon-free resources and energy-efficiency resources; continuing to participate in efforts to help advance the development of technologies such as carbon capture and sequestration; the use of hydrogen fuel for electric production and energy storage, next generation nuclear, and large-scale long-cycle battery energy storage; and constructively engaging with legislators, regulators, investors, customers, and other stakeholders to support outcomes leading to a net-zero future.

Ability to Sell

Total Risks: 2/19 (11%)Above Sector Average

Demand1 | 5.3%

Demand - Risk 1

Forecasted energy demand from potential new customers and electrification might not be realized. Energy conservation, energy efficiency, distributed generation, energy storage, technological advances, and other factors could reduce energy demand from our existing customers.

The Ameren Companies have experienced minimal growth in energy demand for the past two decades. Recent industry projections reflect the potential for significant growth in energy demand over the next decade, primarily arising from data centers to support artificial intelligence and further augmented by onshoring and electrification of manufacturing and an increase in transportation electrification. The Ameren Companies may or may not experience energy demand growth depending on the decisions of potential new customers about whether to locate their operations within our service territories. If new customers elect to locate operations within our service territories, the Ameren Companies may not be able to provide the necessary electric service within the time periods required by those customers. The Ameren Companies may need to accelerate new generation build within current plans, and construct or obtain new generation sources and expand transmission and distribution facilities that are not currently within their plans. The Ameren Companies may not be able to plan, receive regulatory approvals, and execute those plans in a timely manner. Future demand from these customers may not be realized at the current projected pace as a result of increased efficiency in computing, and these new customers may be transitory and exit our service territory. Significant uncertainty exists regarding future increases in energy demand within the Ameren Companies' service territory, and whether and how the Ameren Companies will construct or obtain the assets necessary to timely serve that additional demand. Without a regulatory mechanism to ensure recovery, declines in energy usage could result in an under-recovery of our revenue requirement or an increase in our customer rates, as the revenue requirement would be spread over less sales volumes, which could adversely affect our results of operations, financial position, and liquidity. Such declines could occur due to a number of factors, including: - customer energy-efficiency programs that are designed to reduce energy demand;- energy-efficiency efforts by customers not related to our energy-efficiency programs;- increased customer use of distributed generation sources, such as solar panels and other technologies, which have become more cost-competitive, with decreasing costs expected in the future, as well as the use of energy storage technologies; and - macroeconomic factors resulting in low economic growth or contraction within our service territories, which could reduce energy demand. Decreased use of our generation, transmission, and distribution services might result in stranded costs, which ultimately might not be recovered through rates, and therefore could lead to an impairment or abandonment of assets.

Brand / Reputation1 | 5.3%

Brand / Reputation - Risk 1

Customers', investors', legislators', regulators', creditors', and rating agencies' opinions of us are affected by many factors, including system safety and reliability, implementation of our strategic plan, protection of customer information, rates, media coverage, and company policies or practices, as well as actions by other utility companies. Negative opinions developed by customers, investors, legislators, regulators, creditors, and rating agencies could harm our reputation.

Our results are influenced by the expectations of our customers, investors, legislators, regulators, creditors and ratings agencies. Those expectations are based, in part, on the reliability and affordability of our utility services. Service interruptions and facility shutdowns can occur due to failures of equipment as a result of severe or destructive weather or other causes. The ability of Ameren Missouri and Ameren Illinois to prevent, mitigate, or respond promptly to such failures can affect customer satisfaction or potentially subject us to litigation. In addition to system reliability issues, the success of modernization efforts, our ability to safeguard sensitive customer information and protect our systems from physical or cyber attacks, and other actions can affect customer satisfaction. The level of rates, the timing and magnitude of rate increases, and the volatility of rates can also affect regulator and customer satisfaction. Our ability to successfully execute our strategic plan, including the transition of Ameren Missouri's generation fleet that will be included in its 2025 Change to the 2023 PRP, may affect customers', investors', legislators', regulators', creditors', and rating agencies' opinions and actions. Additionally, negative perceptions or publicity resulting from increasing scrutiny of company policies or practices could negatively impact our reputation, investment in our common stock, or our access to capital and credit markets. Customers', investors', legislators', regulators', creditors', and rating agencies' opinions of us can also be affected by media coverage, including social media, which may include information, whether factual or not, that damages our brand and reputation. If customers, investors, legislators, regulators, creditors or rating agencies have or develop a negative opinion of us and our utility services, this could result in increased costs associated with regulatory oversight and could affect the ROEs we are allowed to earn, as well as the access to, and the cost of, capital. Additionally, negative opinions about us or other utility companies could make it more difficult for our businesses to achieve favorable legislative or regulatory outcomes. Negative opinions could also result in sales volume reductions or increased use of distributed generation by our customers. Any of these consequences could adversely affect our results of operations, financial position, and liquidity.

Macro & Political

Total Risks: 2/19 (11%)Below Sector Average

Natural and Human Disruptions1 | 5.3%

Natural and Human Disruptions - Risk 1

Our operations are subject to acts of sabotage, terrorism, cyber attacks, and other disruptive acts.

Like other electric and natural gas utilities, our energy centers, fuel storage facilities, transmission and distribution facilities, and enterprise information systems may be affected by malicious acts, terrorist activities and other intentionally disruptive acts, including physical and cyber attacks, which could disrupt our ability to produce or distribute our energy products or subject us to significant liability. In the industry, there continues to be attacks on energy infrastructure, such as substations and related assets. The threat landscape continues to expand, which may result in more attacks in the future. Any such incident could limit our ability to generate, purchase, or transmit power or natural gas and could have significant regional economic consequences. Any such disruption could result in a significant decrease in revenues, a significant increase in costs including those for repair, physical harm or loss of life, or adversely affect economic activity in our service territory which, in turn, could adversely affect our results of operations, financial position, and liquidity. There has been an increase in the number and sophistication of physical and cyber attacks across all industries worldwide. Physical attacks could include sabotaging, vandalizing, or burglarizing transmission and distribution facilities, which are unmanned, widely dispersed, and often in isolated areas, or the theft of physical data and information. Cyber attacks could include viruses, malicious or destructive code, phishing or quishing attacks, denial of service attacks, supply chain attacks, ransomware and other extortion-based attacks, improper access by third parties, attacks on email systems, and attacks leading to data loss, operational control, or exploitation of vulnerabilities specific to internally developed systems or to those provided and/or maintained by our suppliers, including those attacks arising from or generated by artificial intelligence, among various other security breaches. In addition, the increasingly widespread adoption of artificial intelligence technologies, including generative artificial intelligence, may increase cyber attacks and other operational, legal, privacy, and reputational risks in our industry and worldwide. Also, remote working arrangements could increase our data security risks, including loss of data related to sensitive customer, employee, financial, and operating system information, through insider or outsider actions. A security breach of our physical assets or in our information systems could affect the reliability of the transmission and distribution system, disrupt electric generation, including nuclear generation, and/or subject us to financial harm resulting from theft or the inappropriate release or destruction of certain types of information, including sensitive customer, employee, financial, and operating system information. Many of our suppliers, vendors, contractors, and information technology providers leverage systems that support our operations and maintain customer and employee data. An interruption of these third-party systems could adversely affect our business as if it was a disruption of our own system. If a significant breach or other interruption occurred, whether due to an intentional or unintentional act, our reputation could be adversely affected, customer confidence could be diminished, availability of our services could be impacted, and/or we could be subject to increased costs associated with regulatory oversight, fines or legal claims, any of which could result in a significant decrease in revenues or significant costs for remedying the impacts of such a disruption. Our generation, transmission, and distribution systems are part of an interconnected grid. Therefore, a breach or other disruption caused by a physical or cyber incident at another utility, electric generator, RTO, or commodity supplier could also adversely affect our businesses. Insurance might not be adequate to cover losses that arise in connection with these events. In addition, new regulations could require changes in our security measures and result in increased costs. The occurrence of any of these events could adversely affect our results of operations, financial position, and liquidity.

Capital Markets1 | 5.3%

Capital Markets - Risk 1

Our businesses are dependent on our ability to access the capital and credit markets successfully. We might not have access to sufficient capital on reasonable terms, and in the amounts and at the times needed.

We rely on the issuance of short-term and long-term debt and equity as significant sources of liquidity and funding for capital requirements not satisfied by our operating cash flow, as well as to refinance existing long-term debt. The inability to raise debt or equity capital on reasonable terms, or at all, could negatively affect our ability to maintain or to expand our businesses. General economic factors beyond our control might create uncertainty that could increase our cost of capital or impair or eliminate our ability to access the debt, equity, or credit markets, including our ability to draw on bank credit facilities. These factors include depressed economic conditions, a recession,increasing interest rates, inflation, sanctions, trade restrictions, tariffs or trade wars, political instability, war, terrorism, and extreme volatility in the debt, equity, or credit markets. In addition, volatility in stock prices of perceived significant energy consumers, such as technology companies involved with artificial intelligence or cryptocurrency, or other significant developments with such companies, could cause increased volatility in stock prices of energy utility companies such as Ameren. Any adverse change in our credit ratings could reduce access to capital and trigger collateral postings and prepayments. Such changes could also increase the cost of borrowing and the costs of fuel, power, and natural gas supply, among other things, which could adversely affect our results of operations, financial position, and liquidity.

Finance & Corporate

Total Risks: 1/19 (5%)Below Sector Average

Accounting & Financial Operations1 | 5.3%

Accounting & Financial Operations - Risk 1

Ameren's holding company structure could limit its ability to pay common stock dividends and to service its debt obligations.

Ameren is a holding company; therefore, its primary assets are its investments in the common stock of its subsidiaries, including Ameren Missouri, Ameren Illinois, and ATXI. As a result, Ameren's ability to pay dividends on its common stock depends on the earnings of its subsidiaries and the ability of its subsidiaries to pay dividends or otherwise transfer funds to Ameren. Similarly, Ameren's ability to service its debt obligations is dependent upon the earnings of its operating subsidiaries and the distribution of those earnings and other payments, including payments of principal and interest under affiliate indebtedness. The payment of dividends to Ameren by its subsidiaries in turn depends on the subsidiaries' results of operations, and other items affecting retained earnings, and available cash. Ameren's subsidiaries are separate and distinct legal entities and have no obligation, contingent or otherwise, to pay any dividends or make any other distributions (except for payments required pursuant to the terms of affiliate borrowing arrangements and cash payments under the tax allocation agreement) to Ameren. Under the IRA, a 15% minimum tax on adjusted financial statement income, as defined in the law, is assessed against corporations whose average annual adjusted financial statement income exceeds $1 billion for three consecutive preceding tax years effective for tax years beginning after December 31, 2022. Once a corporation exceeds this three-year average annual adjusted financial statement income threshold, it will be subject to the minimum tax for all future tax years. As Ameren files a consolidated income tax return, it is reliant on its subsidiaries to pay the minimum tax once the threshold is exceeded. The payments related to the minimum tax by Ameren Missouri, Ameren Illinois, and ATXI are expected to be recovered, subject to approval by their respective regulators. In addition, interpretations, regulations, amendments, or technical corrections that affect the amount and timing of income tax payments, credits available, or the transferability of production and investment tax credits could adversely affect our liquidity. Certain financing agreements, corporate organizational documents, and certain statutory and regulatory requirements may impose restrictions on the ability of Ameren Missouri, Ameren Illinois, and ATXI to transfer funds to Ameren in the form of cash dividends, loans, or advances.

See a full breakdown of risk according to category and subcategory. The list starts with the category with the most risk. Click on subcategories to read relevant extracts from the most recent report.

FAQ

What are “Risk Factors”?

Risk factors are any situations or occurrences that could make investing in a company risky.

The Securities and Exchange Commission (SEC) requires that publicly traded companies disclose their most significant risk factors. This is so that potential investors can consider any risks before they make an investment.

They also offer companies protection, as a company can use risk factors as liability protection. This could happen if a company underperforms and investors take legal action as a result.

It is worth noting that smaller companies, that is those with a public float of under $75 million on the last business day, do not have to include risk factors in their 10-K and 10-Q forms, although some may choose to do so.

How do companies disclose their risk factors?

Publicly traded companies initially disclose their risk factors to the SEC through their S-1 filings as part of the IPO process.

Additionally, companies must provide a complete list of risk factors in their Annual Reports (Form 10-K) or (Form 20-F) for “foreign private issuers”.

Quarterly Reports also include a section on risk factors (Form 10-Q) where companies are only required to update any changes since the previous report.

According to the SEC, risk factors should be reported concisely, logically and in “plain English” so investors can understand them.

How can I use TipRanks risk factors in my stock research?

Use the Risk Factors tab to get data about the risk factors of any company in which you are considering investing.

You can easily see the most significant risks a company is facing. Additionally, you can find out which risk factors a company has added, removed or adjusted since its previous disclosure. You can also see how a company’s risk factors compare to others in its sector.

Without reading company reports or participating in conference calls, you would most likely not have access to this sort of information, which is usually not included in press releases or other public announcements.

A simplified analysis of risk factors is unique to TipRanks.

What are all the risk factor categories?

TipRanks has identified 6 major categories of risk factors and a number of subcategories for each. You can see how these categories are broken down in the list below.

1. Financial & Corporate

Accounting & Financial Operations - risks related to accounting loss, value of intangible assets, financial statements, value of intangible assets, financial reporting, estimates, guidance, company profitability, dividends, fluctuating results.
Share Price & Shareholder Rights – risks related to things that impact share prices and the rights of shareholders, including analyst ratings, major shareholder activity, trade volatility, liquidity of shares, anti-takeover provisions, international listing, dual listing.
Debt & Financing – risks related to debt, funding, financing and interest rates, financial investments.
Corporate Activity and Growth – risks related to restructuring, M&As, joint ventures, execution of corporate strategy, strategic alliances.

2. Legal & Regulatory

Litigation and Legal Liabilities – risks related to litigation/ lawsuits against the company.
Regulation – risks related to compliance, GDPR, and new legislation.
Environmental / Social – risks related to environmental regulation and to data privacy.
Taxation & Government Incentives – risks related to taxation and changes in government incentives.

3. Production

Costs – risks related to costs of production including commodity prices, future contracts, inventory.
Supply Chain – risks related to the company’s suppliers.
Manufacturing – risks related to the company’s manufacturing process including product quality and product recalls.
Human Capital – risks related to recruitment, training and retention of key employees, employee relationships & unions labor disputes, pension, and post retirement benefits, medical, health and welfare benefits, employee misconduct, employee litigation.

4. Technology & Innovation

Innovation / R&D – risks related to innovation and new product development.
Technology – risks related to the company’s reliance on technology.
Cyber Security – risks related to securing the company’s digital assets and from cyber attacks.
Trade Secrets & Patents – risks related to the company’s ability to protect its intellectual property and to infringement claims against the company as well as piracy and unlicensed copying.

5. Ability to Sell

Demand – risks related to the demand of the company’s goods and services including seasonality, reliance on key customers.
Competition – risks related to the company’s competition including substitutes.
Sales & Marketing – risks related to sales, marketing, and distribution channels, pricing, and market penetration.
Brand & Reputation – risks related to the company’s brand and reputation.

6. Macro & Political

Economy & Political Environment – risks related to changes in economic and political conditions.
Natural and Human Disruptions – risks related to catastrophes, floods, storms, terror, earthquakes, coronavirus pandemic/COVID-19.
International Operations – risks related to the global nature of the company.
Capital Markets – risks related to exchange rates and trade, cryptocurrency.