Evergy EVRG Form 10-Q filing Q3 FY2025

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ITEM 1. FINANCIAL STATEMENTS

The accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Kansas Central included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Kansas Central included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Kansas Central included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Kansas Central included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Kansas Central included in the accompanying Unaudited Notes to Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Metro included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Metro included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Metro included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Metro included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

The disclosures regarding Evergy Metro included in the accompanying Notes to Unaudited Consolidated Financial Statements are an integral part of these statements.

EVERGY, INC.

EVERGY KANSAS CENTRAL, INC.

EVERGY METRO, INC.

Combined Notes to Unaudited Consolidated Financial Statements

The notes to unaudited consolidated financial statements that follow are a combined presentation for Evergy, Inc., Evergy Kansas Central, Inc. and Evergy Metro, Inc., all registrants under this filing. The terms "Evergy," "Evergy Kansas Central," "Evergy Metro" and "Evergy Companies" are used throughout this report. "Evergy" refers to Evergy, Inc. and its consolidated subsidiaries, unless otherwise indicated. "Evergy Kansas Central" refers to Evergy Kansas Central, Inc. and its consolidated subsidiaries, unless otherwise indicated. "Evergy Metro" refers to Evergy Metro, Inc. and its consolidated subsidiaries, unless otherwise indicated. "Evergy Companies" refers to Evergy, Evergy Kansas Central and Evergy Metro, collectively, which are individual registrants within the Evergy consolidated group.

1. ORGANIZATION AND BASIS OF PRESENTATION

Organization

Evergy is a public utility holding company incorporated in 2017 and headquartered in Kansas City, Missouri. Evergy operates primarily through the following wholly-owned direct subsidiaries listed below.

• Evergy Kansas Central, Inc. (Evergy Kansas Central) is an integrated, regulated electric utility that provides electricity to customers in the state of Kansas. Evergy Kansas Central has one active wholly-owned subsidiary with significant operations, Evergy Kansas South, Inc. (Evergy Kansas South).
• Evergy Metro, Inc. (Evergy Metro) is an integrated, regulated electric utility that provides electricity to customers in the states of Missouri and Kansas.
• Evergy Missouri West, Inc. (Evergy Missouri West) is an integrated, regulated electric utility that provides electricity to customers in the state of Missouri.
• Evergy Transmission Company, LLC (Evergy Transmission Company) owns 13.5% of Transource Energy, LLC (Transource) with the remaining 86.5% owned by AEP Transmission Holding Company, LLC, a subsidiary of American Electric Power Company, Inc. (AEP). Transource is focused on the development of competitive electric transmission projects. Evergy Transmission Company accounts for its investment in Transource under the equity method.

Evergy Kansas Central also owns a 50% interest in Prairie Wind Transmission, LLC (Prairie Wind), which is a joint venture between Evergy Kansas Central and subsidiaries of AEP and Berkshire Hathaway Energy Company. Prairie Wind owns a 108-mile, 345 kilovolt (kV) double-circuit transmission line that provides transmission service in the Southwest Power Pool, Inc. (SPP). Evergy Kansas Central accounts for its investment in Prairie Wind under the equity method.

Evergy Kansas Central, Evergy Kansas South, Evergy Metro and Evergy Missouri West conduct business in their respective service territories using the name Evergy. Collectively, the Evergy Companies have approximately 15,800 megawatts (MWs) of owned generating capacity and renewable power purchase agreements and engage in the generation, transmission, distribution and sale of electricity to approximately 1.7 million customers in the states of Kansas and Missouri.

Basis of Presentation

These unaudited consolidated financial statements have been prepared in accordance with generally accepted accounting principles (GAAP) for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these unaudited consolidated financial statements do not include all of the information and notes required by GAAP for annual financial statements and should be read in conjunction with the consolidated financial statements in the Evergy Companies' combined 2024 Form 10-K.

These unaudited consolidated financial statements, in the opinion of management, reflect all normal recurring adjustments necessary to fairly present the unaudited consolidated financial statements for each of the Evergy Companies for these interim periods. In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates.

Principles of Consolidation

Each of Evergy's, Evergy Kansas Central's and Evergy Metro's unaudited consolidated financial statements includes the accounts of their subsidiaries and the variable interest entities (VIEs) of which Evergy and Evergy Kansas Central are the primary beneficiaries. Undivided interests in jointly-owned generation facilities are included on a proportionate basis. Intercompany transactions have been eliminated. The Evergy Companies assess financial performance and allocate resources on a consolidated basis (i.e., operate in one segment).

Cash, Cash Equivalents and Restricted Cash

Cash equivalents consist of highly liquid investments with original maturities of three months or less at acquisition. Evergy has restricted cash included in Other Current Assets and Other Non-current Assets on Evergy's consolidated balance sheet to facilitate the servicing of Evergy Missouri West Storm Funding I, LLC's debt and the funding requirements for a jointly-owned generation facility. The following table summarizes the cash, cash equivalents and restricted cash included on Evergy's consolidated balance sheet.

Fuel Inventory and Supplies

The Evergy Companies record fuel inventory and supplies at average cost. The following table separately states the balances for fuel inventory and supplies.

Property, Plant and Equipment

The following tables summarize the property, plant and equipment of Evergy, Evergy Kansas Central and Evergy Metro.

(a) As of December 31, 2024, represents the planned retirement of Evergy Kansas Central analog meters prior to the end of their remaining useful lives.

Investments in Early-Stage Clean Energy and Energy Solution Companies

From time to time, Evergy has made limited non-regulated equity and debt investments in early-stage clean energy and energy solution companies. These investments are recorded in Other Assets - Long-Term on Evergy’s consolidated balance sheets and as of September 30, 2025, and December 31, 2024, the total value of these investments was $95.7 million and $121.4 million, respectively. These investments have historically not had a significant impact on Evergy’s results of operations.

Year to date September 30, 2025, Evergy recorded unrealized losses and impairment losses of $29.0 million, which are included in investment earnings (loss) on Evergy's consolidated statements of income and comprehensive income as a result of a decrease in the value of these investments.

Evergy has initiated a process to dispose of these investments and could experience additional losses or gains on these investments as a result of further changes in their value or upon their ultimate liquidation.

Other Income and Other Expense

The tables below show the detail of other income and other expense, respectively, for each of the Evergy Companies.

Earnings Per Share

To compute basic earnings per common share (EPS), Evergy divides net income attributable to Evergy, Inc. by the weighted average number of common shares outstanding. Diluted EPS includes the effect of issuable common shares resulting from restricted share units (RSUs), convertible notes, a warrant and forward sale agreements entered into through Evergy's at-the-market (ATM) equity offering program. Evergy computes the dilutive effects of potential issuances of common shares using the treasury stock method, the contingently issuable share method or the if-converted method, as applicable.

The following table reconciles Evergy's basic and diluted EPS.

The effect of dilutive securities for the three months ended and year to date September 30, 2025, included 3.0 million shares and 2.1 million shares, respectively, resulting from Evergy's convertible notes. There was no dilution resulting from Evergy's convertible notes for the three months ended and year to date September 30, 2024.

The table below summarizes the anti-dilutive securities excluded from the computation of diluted EPS.

Supplemental Cash Flow Information

Dividends Declared

In October 2025, Evergy's Board of Directors (Evergy Board) declared a quarterly dividend of $0.6950 per share on Evergy's common stock. The common dividend is payable on December 19, 2025, to shareholders of record as of November 21, 2025.

In October 2025, Evergy Kansas Central's Board of Directors and Evergy Metro's Board of Directors each declared a cash dividend to Evergy of up to $50.0 million and $125.0 million, respectively, and payable on or before December 18, 2025.

Missouri Legislation

In April 2025, Missouri Senate Bill (SB) 4 was signed into law by the Governor of Missouri. Most notably, SB 4 establishes new mechanisms for Missouri electric utilities to recover the costs associated with the construction of new natural gas-fired generating units. The utilities will be able to include certain costs of construction work in progress (CWIP) in rate base. The inclusion of CWIP will be in lieu of allowance for funds used during construction (AFUDC) applicable to the construction of the new natural gas-fired generating units. The Public Service Commission of the State of Missouri (MPSC) will determine the amount of CWIP that may be included in rate base. Additionally, amounts collected arising from the inclusion of CWIP in rate base are subject to refund under certain circumstances. These provisions are scheduled to expire at the end of 2035.

Additionally, the law extends Missouri's existing plant-in service accounting (PISA) provisions to include certain natural gas-fired generating units as qualifying electric plants and extends the sunset date of these provisions through the end of 2035. These provisions allow electric utilities to defer to a regulatory asset for recovery in a subsequent general rate case 85% of depreciation expense and the associated return on investment for qualifying electric plant rate base additions for assets placed in-service between general rate cases.

Natural Gas Plant Investments

The Evergy Companies use a triennial integrated resource plan (IRP), a detailed analysis that estimates factors that influence the future supply and demand for electricity, to inform the manner in which they supply electricity. The most recent IRPs incorporate the latest SPP resource adequacy requirements and anticipated load growth. Based on these and other factors, the IRP indicated the addition of new supply side resources, including combined and simple cycle natural gas plants, would be needed.

In October 2024, Evergy announced its plan to construct two combined-cycle natural gas plants located in Kansas. Evergy Kansas Central and Evergy Missouri West will jointly-own each plant and expect each plant to have an initial generating capacity of approximately 705 MW. The first plant is expected to begin operations by summer of 2029 and the second plant is expected to begin operations by summer of 2030.

Additionally, Evergy Missouri West plans to construct a 440 MW simple-cycle natural gas plant located in Missouri. The plant is expected to begin operations in 2030.

See "Applications for Predetermination" and "Requests for Certificate of Convenience and Necessity" in Note 4 for information regarding Evergy Kansas Central's and Evergy Missouri West's applications for predetermination and a Certificate of Convenience and Necessity (CCN) for their investments in these natural gas plants.

Renewable Plant Investments

Evergy Kansas Central intends to construct and own an approximately 159 MW solar generation facility to be located in Kansas called Kansas Sky. Kansas Sky is expected to begin operations by summer of 2027 and construction is subject to the granting by the Kansas Corporation Commission (KCC) of predetermination with reasonably acceptable terms and other closing conditions. See "Applications for Predetermination" in Note 4 for additional information regarding Evergy Kansas Central's application for predetermination for its investment in this renewable generating plant.

In 2024, Evergy Missouri West entered into agreements to own two solar generation facilities currently under development. The first facility, to be called Sunflower Sky, is a solar generation facility to be located in Kansas with an expected generating capacity of approximately 65 MW. In September 2025, Evergy Missouri West acquired the Sunflower Sky solar facility assets from the developer and will complete construction of the facility. The second facility, to be called Foxtrot, is a solar generation facility to be located in Missouri with an expected generating capacity of approximately 100 MW. In November 2025, Evergy Missouri West acquired the Foxtrot solar facility assets from the developer and will complete construction of the facility. The solar generation facilities are expected to begin operations by summer of 2027. The agreements are subject to regulatory approvals and closing conditions, including the granting by the MPSC of a CCN with reasonably acceptable terms. See "Requests for Certificate of Convenience and Necessity" in Note 4 for information regarding Evergy Missouri West's application for a CCN for its investment in these renewable generating plants.

2. REVENUE

Evergy's, Evergy Kansas Central's and Evergy Metro's revenues disaggregated by customer class are summarized in the following tables.

3. RECEIVABLES

The Evergy Companies' receivables are detailed in the following table.

The Evergy Companies' other receivables as of September 30, 2025, and December 31, 2024, consisted primarily of receivables from partners in jointly-owned electric utility plants, wholesale sales receivables and receivables related to alternative revenue programs. The Evergy Companies' other receivables also included receivables from contracts with customers as summarized in the following table.

The change in the Evergy Companies' allowance for credit losses is summarized in the following table.

Sale of Accounts Receivable

Evergy Kansas Central, Evergy Metro and Evergy Missouri West sell an undivided percentage ownership interest in their retail electric accounts receivable to independent outside investors. These sales are accounted for as secured borrowings with accounts receivable pledged as collateral and a corresponding short-term collateralized note payable recognized on the balance sheets. The Evergy Companies' accounts receivable pledged as collateral and the corresponding short-term collateralized note payable are summarized in the following table.

In April 2025, Evergy Kansas Central, Evergy Metro and Evergy Missouri West extended the expiration of each receivable sale facility from November 2025 to April 2028. Evergy Kansas Central's facility allows up to

$185.0 million in aggregate outstanding principal amount to be borrowed at any time. To the extent Evergy Kansas Central has qualifying accounts receivable and subject to the lender's discretion, Evergy Kansas Central's facility allows for an additional $65.0 million in aggregate outstanding principal amount to be borrowed at any time. Evergy Metro's facility allows up to $130.0 million in aggregate outstanding principal amount to be borrowed at any time. To the extent Evergy Metro has qualifying accounts receivable and subject to the lender's discretion, Evergy Metro's facility allows for an additional $70.0 million in aggregate outstanding principal amount to be borrowed at any time. Evergy Missouri West's facility allows up to $50.0 million in aggregate outstanding principal amount to be borrowed at any time. To the extent Evergy Missouri West has qualifying accounts receivable and subject to the lender's discretion, Evergy Missouri West's facility allows for an additional $65.0 million in aggregate outstanding principal amount to be borrowed at any time.

4. RATE MATTERS AND REGULATION

KCC Proceedings

Evergy Kansas Central's 2025 Rate Case Proceeding

In January 2025, Evergy Kansas Central filed an application with the KCC to request an increase to its retail revenues of approximately $196 million. Evergy Kansas Central's request reflected a return on equity of 10.5% (with a capital structure composed of 52% equity) and increases related to the recovery of infrastructure investments made to improve reliability and enhance customer service and the update of expenses to current levels of spend.

In July 2025, Evergy Kansas Central, KCC staff and other intervenors reached a unanimous settlement agreement to settle all issues in the case. The unanimous settlement agreement provides for an increase to retail revenues of $128.0 million after rebasing property tax expense and not including costs recoverable through KCC-approved riders for Evergy Kansas Central. As part of the settlement agreement, Evergy Kansas Central agreed to participate in an earnings review surveillance report for each calendar year beginning 2025 through the time Evergy Kansas Central files its next general rate case and new base rates become effective as a result of that case. Under this mechanism, Evergy Kansas Central’s jurisdiction is required to refund customers 50% of annual earnings in excess of a 9.7% return on equity. In September 2025, the KCC approved the unanimous settlement agreement and new rates took effect in October 2025.

As of September 30, 2025, Evergy Kansas Central estimates its 2025 annual earnings will not result in a refund obligation under the earnings review mechanism. Evergy Kansas Central expects to file its 2025 earnings calculation with the KCC in March 2026. The final refund obligation for 2025, if any, will be decided by the KCC and could vary from the current estimate.

Applications for Predetermination

The KCC uses a process referred to as ‘predetermination’ to establish ratemaking principles and treatments for certain utility investments before they are included in a utility’s rate base. The process helps balance the interest of utilities and customers by ensuring broad agreement to the reasonableness of the investment and regulatory certainty regarding the recovery of costs associated with the investment. Investment in utility projects may be dependent on acceptable regulatory treatment determined in the predetermination process.

In November 2024, Evergy Kansas Central requested predetermination from the KCC for its planned natural gas plant investments and Kansas Sky solar investment. In April 2025, Evergy Kansas Central and intervenors in the case reached a non-unanimous partial settlement agreement regarding its planned natural gas plant investments and a unanimous partial settlement agreement regarding the Kansas Sky solar investment.

In July 2025, the KCC approved the non-unanimous partial settlement agreement for the natural gas plant investments establishing that Evergy Kansas Central's investment in its planned natural gas plants is prudent. This agreement will permit Evergy Kansas Central to implement a CWIP rider one year after construction of each plant begins and Evergy Kansas Central will recover through the CWIP rider the return on up to 100% of amounts recorded to CWIP for each plant, not to exceed definitive cost estimates established by the KCC unless otherwise ordered by the KCC. Evergy Kansas Central will be permitted to update rates charged through the CWIP rider every six months. Evergy Kansas Central will be permitted to collect these amounts through the CWIP rider until new base rates reflecting Evergy Kansas Central's investment in the natural gas plants take effect. Evergy Kansas

Central will not be able to accrue AFUDC on these amounts once the CWIP rider becomes effective and is included in customer rates. When new base rates reflecting Evergy Kansas Central's investment in each plant take effect, those base rates will include a deferral for depreciation expense incurred and carrying costs on any unrecovered portion of Evergy Kansas Central's investment in natural gas plants incurred between the time the natural gas plants are placed in service and the time the investment in the natural gas plants is included in base rates. Investments above certain amounts established in the settlement agreement will be subject to a prudence review.

In July 2025, the KCC approved the unanimous partial settlement agreement for the Kansas Sky solar investment. After the investment is placed in service and prior to the effective date of rates that include the investment, Evergy Kansas Central will be permitted to defer to a regulatory asset and recover over the remaining life of the Kansas Sky solar investment depreciation expense, carrying costs and other costs incurred. Thereafter, Evergy Kansas Central’s investment in Kansas Sky will be recovered through a levelized revenue requirement for the first thirty years of the life of the generation site, after which the levelized revenue requirement will be reevaluated.

Evergy Kansas Central 2025 Transmission Delivery Charge (TDC)

In April 2025, the KCC issued an order adjusting Evergy Kansas Central's retail prices to include updated transmission costs as reflected in the Federal Energy Regulatory Commission (FERC) transmission formula rate (TFR). The new prices were effective in May 2025 and are expected to increase Evergy Kansas Central's annual retail revenues by $54.8 million when compared to 2024.

Evergy Metro 2025 TDC

In April 2025, the KCC issued an order adjusting Evergy Metro's retail prices to include updated transmission costs as reflected in the FERC TFR. The new prices were effective in May 2025 and are expected to increase Evergy Metro's annual retail revenues by $4.8 million when compared to 2024.

MPSC Proceedings Evergy Missouri West's 2024 Rate Case Proceeding

In January 2025, Evergy Missouri West implemented new rates approved by the MPSC in December 2024 providing for an increase to Evergy Missouri West's retail revenues of approximately $55 million after lowering base rates for fuel and purchased power expense of approximately $49 million and rebasing property tax expense.

Requests for Certificate of Convenience and Necessity

Missouri utilities must request a CCN from the MPSC to authorize them to build certain utility projects. The CCN process authorizes utilities to build projects and can provide assurance that the project is prudent and necessary. Investment in projects is dependent upon the granting by the MPSC of a CCN with reasonably acceptable terms.

In 2024, Evergy Missouri West filed applications for CCNs for its planned renewable and natural gas plant investments. In May 2025, Evergy Missouri West entered into a unanimous stipulation and agreement with the MPSC staff and other intervenors that would grant Evergy Missouri West’s CCNs to construct, install, own, operate, maintain and otherwise control and manage Sunflower Sky and Foxtrot solar generating facilities. In May 2025, Evergy Missouri West entered into a non-unanimous stipulation and agreement with the MPSC staff and other intervenors that would grant Evergy Missouri West’s CCNs to construct, install, own, operate, maintain and otherwise control and manage its planned natural gas plant investments.

In July 2025, the MPSC approved the unanimous stipulation and agreement for Sunflower Sky and Foxtrot solar generating facilities granting Evergy Missouri West's CCN request for its planned renewable plant investments. Evergy Missouri West plans to utilize PISA, as applicable, for its planned renewable plant investments.

In July 2025, the MPSC approved the non-unanimous stipulation and agreement for the natural gas plant investments granting Evergy Missouri West's CCN and establishing that Evergy Missouri West’s planned investments in the natural gas plants are decisionally prudent. Evergy Missouri West intends to utilize the SB 4 CWIP inclusion provision and PISA, as applicable, for its planned investments in the natural gas plants.

FERC Proceedings

In October of each year, Evergy Kansas Central and Evergy Metro post an updated TFR that includes projected transmission capital expenditures and operating costs for the following year. This rate is the most significant component in the retail rate calculation for Evergy Kansas Central's and Evergy Metro's annual request with the KCC to adjust retail prices to include updated transmission costs through the TDC.

Evergy Kansas Central TFR Annual Update

Most recently, the updated TFR is expected to increase Evergy Kansas Central's annual transmission revenues by approximately $21.6 million, effective in January 2026.

Evergy Kansas Central TFR Formal Complaint

In February 2023, certain Evergy Kansas Central TFR customers submitted a formal complaint with FERC requesting the refund of over-collections related to the capital structure calculation in determining Evergy Kansas Central's Annual Transmission Revenue Requirement for the 2018 and 2019 rate years. As of September 30, 2025, and December 31, 2024, Evergy and Evergy Kansas Central had recorded a regulatory liability of $9.5 million and $7.1 million, respectively, related to the 2018 and 2019 rate year refund request. Evergy and Evergy Kansas Central are awaiting a response from FERC.

Evergy Metro TFR Annual Update

Most recently, the updated TFR is expected to decrease Evergy Metro's annual transmission revenues by approximately $2.4 million, effective in January 2026.

5. GOODWILL

GAAP requires goodwill to be tested for impairment annually and when an event occurs indicating the possibility that an impairment exists. Evergy's impairment test for the $2,336.6 million of goodwill that was recorded as a result of the merger that created Evergy was conducted as of May 1, 2025. The goodwill impairment test consists of comparing the fair value of a reporting unit to its carrying amount, including goodwill, to identify potential impairment. In the event that the carrying amount exceeds the fair value of the reporting unit, an impairment loss is recognized for the difference between the carrying amount of the reporting unit and its fair value. Evergy's consolidated operations are considered one reporting unit for assessment of impairment, as management assesses financial performance and allocates resources on a consolidated basis. The determination of fair value of the reporting unit consisted of two valuation techniques: an income approach consisting of a discounted cash flow analysis and a market approach consisting of a determination of reporting unit invested capital using a market multiple derived from the historical earnings before interest, income taxes, depreciation and amortization and market prices of the stock of peer companies. The results of the two techniques were evaluated and weighted to determine a point within the range that management considered representative of fair value for the reporting unit. The fair value of the reporting unit exceeded the carrying amount, including goodwill. As a result, there was no impairment of goodwill.

6. PENSION PLANS AND POST-RETIREMENT BENEFITS

Evergy and certain of its subsidiaries maintain, and Evergy Kansas Central and Evergy Metro participate in, qualified non-contributory defined benefit pension plans covering the majority of Evergy Kansas Central's and Evergy Metro's employees as well as certain non-qualified plans covering certain active and retired officers.

For the majority of employees, pension benefits under these plans reflect the employees' compensation, years of service and age at retirement. However, for the plan covering Evergy Kansas Central's employees, the benefits for non-union employees hired between 2002 and the second quarter of 2018 and union employees hired beginning in 2012 are derived from a cash balance account formula. The plan was closed to future non-union employees in 2018. For the plans covering Evergy Metro's employees, the benefits for union employees hired beginning in 2014 are derived from a cash balance account formula and the plans were closed to future non-union employees in 2014.

Evergy and its subsidiaries also provide certain post-retirement health care and life insurance benefits for substantially all retired employees of Evergy Kansas Central and Evergy Metro and their respective shares of Wolf Creek Generating Station's (Wolf Creek) post-retirement benefit plans.

The Evergy Companies record pension and post-retirement expense in accordance with rate orders from the KCC and MPSC that allow the difference between pension and post-retirement costs under GAAP and costs for ratemaking to be recognized as a regulatory asset or liability. This difference between financial and regulatory accounting methods is due to timing and will be eliminated over the life of the plans.

The following tables provide the components of net periodic benefit costs prior to the effects of capitalization and sharing with joint owners of power plants.

The components of net periodic benefit costs other than the service cost component are included in other expense on the Evergy Companies' consolidated statements of income and comprehensive income.

Year to date September 30, 2025, Evergy, Evergy Kansas Central and Evergy Metro made cash pension contributions of $61.7 million, $31.7 million and $30.0 million, respectively. Evergy expects to make additional cash pension contributions of $4.3 million, paid by Evergy Metro, in 2025 to satisfy the Employee Retirement Income Security Act of 1974, as amended, funding requirements and KCC and MPSC rate orders.

Year to date September 30, 2025, Evergy, Evergy Kansas Central and Evergy Metro made post-retirement benefit contributions of $0.3 million, $0.2 million and $0.1 million, respectively. Evergy, Evergy Kansas Central and Evergy Metro expect to make additional contributions in 2025 of $0.2 million, $0.1 million and $0.1 million, respectively, to the post-retirement benefit plans.

7. SHORT-TERM BORROWINGS AND SHORT-TERM BANK LINES OF CREDIT

The Evergy Companies' $2.5 billion master credit facility expires in 2028. Evergy, Evergy Kansas Central, Evergy Metro and Evergy Missouri West have borrowing capacity under the master credit facility with specific sublimits for each borrower. These sublimits can be unilaterally adjusted by Evergy for each borrower provided the sublimits remain within minimum and maximum sublimits as specified in the facility. The applicable interest rates and commitment fees of the facility are also subject to changes in ratings by the credit rating agencies.

A default by any borrower under the facility or one of its significant subsidiaries on other indebtedness totaling more than $100.0 million constitutes a default by that borrower under the facility. Under the terms of this facility, each of Evergy, Evergy Kansas Central, Evergy Metro and Evergy Missouri West is required to maintain a total indebtedness to total capitalization ratio, as defined in the facility, of not greater than 0.65 to 1.00. As of September 30, 2025, Evergy, Evergy Kansas Central, Evergy Metro and Evergy Missouri West were in compliance with this covenant.

The following table summarizes the committed credit facilities (excluding receivable sale facilities discussed in Note 3) available to the Evergy Companies as of September 30, 2025, and December 31, 2024.

8. LONG-TERM DEBT

Mortgage Bonds

In March 2025, Evergy Kansas Central issued, at a discount, $300.0 million of 5.25% First Mortgage Bonds, maturing in 2035. Proceeds were used to pay down commercial paper and for general corporate purposes.

In August 2025, Evergy Metro issued, at a discount, $400.0 million of 5.125% Mortgage Bonds, maturing in 2035. Proceeds were used to repay its 3.65% Senior Notes at maturity and for general corporate purposes.

Notes and Senior Notes

In March 2025, Evergy Kansas Central issued, at a discount, $300.0 million of 4.70% Notes, maturing in 2028. Proceeds were used to pay down commercial paper and for general corporate purposes.

In August 2025, Evergy Metro repaid its $350.0 million of 3.65% Senior Notes at maturity.

In August 2025, Evergy Missouri West repaid its $36.0 million of 3.49% Senior Notes at maturity.

Pollution Control Bonds

In July 2025, Evergy Metro remarketed its unsecured Series 2008 Environmental Improvement Revenue Refunding (EIRR) bonds maturing in 2038 totaling $23.4 million at a fixed rate of 4.05% through June 2030.

9. DERIVATIVE INSTRUMENTS

Commodity Price Risk

The Evergy Companies engage in the wholesale and retail sale of electricity as part of their regulated electric operations. These activities expose the Evergy Companies to market risks associated with the price of electricity, natural gas and other energy-related products. Management has established risk management policies and strategies to reduce the potentially adverse effects that the volatility of the markets may have on the Evergy Companies' operating results. The Evergy Companies' commodity risk management activities, which are subject to the management, direction and control of an internal risk management committee, utilize derivative instruments to reduce the effects of fluctuations in wholesale sales and fuel and purchased power expense caused by commodity price volatility.

Interest Rate Risk

The Evergy Companies are also exposed to market risks arising from changes in interest rates and may use derivative instruments to manage these risks. The Evergy Companies' interest rate risk management activities have included using derivative instruments to hedge against future interest rate fluctuations on anticipated debt issuances. From time to time, this may include entering into interest rate swap agreements to mitigate exposure to interest rate fluctuations associated with forecasted debt transactions.

Trading

The Evergy Companies also engage in non-regulated energy marketing activity for trading purposes, primarily at Evergy Kansas Central, which focuses on seizing market opportunities to create value driven by expected changes in the market prices of commodities, primarily electricity and natural gas.

Accounting for Derivative Instruments

The Evergy Companies consider various qualitative factors, such as contract and marketplace attributes, in designating derivative instruments at inception. The Evergy Companies may elect the normal purchases and normal sales (NPNS) exception, which requires the effects of the derivative to be recorded when the underlying contract settles under accrual accounting. The Evergy Companies account for derivative instruments that are not designated as NPNS as (i) economic hedges or trading contracts (non-hedging derivatives) or (ii) cash flow hedges, which are recorded as assets or liabilities on the consolidated balance sheets at fair value. See Note 10 for additional information on the Evergy Companies' methods for assessing the fair value of derivative instruments.

Changes in the fair value of derivative instruments designated as economic hedges (non-hedging derivatives) that are related to the Evergy Companies' regulated operations are deferred to a regulatory asset or regulatory liability when determined to be probable of future recovery or refund from/to customers. Recovery of the actual costs incurred by regulated activities will not impact earnings but will impact cash flows due to the timing of the recovery mechanism.

Changes in the fair value of derivative instruments designated as trading contracts (non-hedging derivatives) are recorded in operating revenues on the Evergy Companies' statements of income and comprehensive income.

Changes in the fair value of interest rate swaps designated as cash flow hedges are initially recorded in Other Comprehensive Income (OCI). These amounts are subsequently reclassified into earnings as an adjustment to interest expense over the same period that the hedged interest payments affect earnings. The Evergy Companies classify cash flows from derivative instruments accounted for as a cash flow hedge in the same category as the cash flows from the items being hedged.

The Evergy Companies offset fair value amounts recognized for derivative instruments under master netting arrangements, which include rights to reclaim cash collateral (a receivable), or the obligation to return cash collateral (a payable).

The gross notional contract amount by commodity type for non-hedging derivative instruments is summarized in the following table.

The fair values of Evergy's open non-hedging derivative positions and balance sheet classifications are summarized in the following tables. The fair values below are gross values before netting agreements and netting of cash collateral.

The following tables present the line items on the Evergy Companies' consolidated balance sheets where non-hedging derivative assets and liabilities are reported. The gross amounts offset in the tables below show the effect of master netting arrangements and include collateral posted to offset the net position.

The following table summarizes the amounts of gain (loss) recognized in income for the change in fair value of derivatives not designated as hedging instruments for the Evergy Companies.

The following table summarizes the gross notional contract amount by type for hedging derivative instruments.

The fair value of Evergy's open hedging derivative positions and balance sheet classifications are summarized in the following table. The fair values represent both the gross and net impact of netting agreements and the netting of cash collateral.

Credit risk of the Evergy Companies' derivative instruments relates to the potential adverse financial impact resulting from non-performance by a counterparty of its contractual obligations. The Evergy Companies maintain credit policies and employ credit risk mitigation, such as collateral requirements or letters of credit, when necessary to minimize their overall credit risk and monitor exposure. Substantially all of the Evergy Companies' counterparty credit risk associated with derivative instruments relates to Evergy Kansas Central's non-regulated energy marketing activities. As of September 30, 2025, if counterparty groups completely failed to perform on contracts, Evergy's and Evergy Kansas Central's maximum exposure related to derivative assets was $33.1 million. As of September 30, 2025, the potential loss after the consideration of applicable master netting arrangements and collateral received for Evergy and Evergy Kansas Central was $25.2 million.

Certain of the Evergy Companies' derivative instruments contain collateral provisions that are tied to the Evergy Companies' credit ratings and may require the posting of collateral for various reasons, including if the Evergy Companies' credit ratings were to fall below investment grade. Substantially all of these derivative instruments relate to Evergy Kansas Central's non-regulated energy marketing activities. The aggregate fair value of all derivative instruments with credit-risk-related contingent features that were in a liability position as of September 30, 2025, was $36.5 million for which Evergy and Evergy Kansas Central have posted $2.5 million collateral in the normal course of business. If the credit-risk-related contingent features underlying these agreements were triggered as of September 30, 2025, Evergy and Evergy Kansas Central could be required to post an additional $32.6 million of collateral to their counterparties.

10. FAIR VALUE MEASUREMENTS

Values of Financial Instruments

GAAP establishes a hierarchical framework for disclosing the transparency of the inputs utilized in measuring assets and liabilities at fair value. Management's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the classification of assets and liabilities within the fair value hierarchy levels. In addition, the Evergy Companies measure certain investments that do not have a readily determinable fair value at net asset value (NAV), which are not included in the fair value hierarchy. Further explanation of these levels and NAV is summarized below.

Level 1 – Quoted prices are available in active markets for identical assets or liabilities. The types of assets and liabilities included in Level 1 are highly liquid and actively traded instruments with quoted prices, such as equities listed on public exchanges or exchange-traded derivative instruments.

Level 2 – Pricing inputs are not quoted prices in active markets but are either directly or indirectly observable. The types of assets and liabilities included in Level 2 are certain marketable debt securities, financial instruments traded in less than active markets, non-exchange traded derivative instruments with observable forward curves and options contracts.

Level 3 – Significant inputs to pricing have little or no transparency. The types of assets and liabilities included in Level 3 are those with inputs requiring significant management judgment or estimation. The types of assets and liabilities included in Level 3 are non-exchange traded derivative instruments for which observable market data is not available to corroborate the valuation inputs and transmission congestion rights (TCRs) in the SPP Integrated Marketplace.

NAV - Investments that do not have a readily determinable fair value are measured at NAV. These investments do not consider the observability of inputs and, therefore, they are not included within the fair value hierarchy. The Evergy Companies include in this category investments in private equity, real estate and alternative investment funds that do not have a readily determinable fair value. The underlying alternative investments include collateralized debt obligations, mezzanine debt and a variety of other investments.

The Evergy Companies record cash and cash equivalents, accounts receivable and short-term borrowings on their consolidated balance sheets at cost, which approximates fair value due to the short-term nature of these instruments.

Fair Value of Long-Term Debt

The Evergy Companies measure the fair value of long-term debt using Level 2 measurements available as of the measurement date. The book value and fair value of the Evergy Companies' long-term debt are summarized in the following table.

(a) Includes current maturities.

(b) Book value as of September 30, 2025, and December 31, 2024, includes $77.5 million and $81.7 million, respectively, of fair value adjustments recorded in connection with purchase accounting for the merger that created Evergy, which are not part of future principal payments and will amortize over the remaining life of the associated debt instrument.

Recurring Fair Value Measurements

The following tables include balances of financial assets and liabilities measured at fair value on a recurring basis.

(a)With the exception of investments measured at NAV, fair value is based on quoted market prices of the investments held by the trust and/or valuation models.

(b)Derivative instruments classified as Level 1 consist of exchange-traded derivative instruments with fair value based on quoted market prices. Derivative instruments classified as Level 2 consist of non-exchange traded derivative instruments with observable forward curves and option contracts priced with models using observable inputs. Derivative instruments classified as Level 3 consist of non-exchange traded derivative instruments for which observable market data is not available to corroborate the valuation inputs and TCRs valued at the most recent auction price in the SPP Integrated Marketplace.

(c)Fair value is based on quoted market prices of the investments held by the trust. Debt securities classified as Level 1 are comprised of U.S. Treasury securities. Debt securities classified as Level 2 are comprised of corporate bonds, U.S. Agency, state and local obligations, and other asset-backed securities.

Certain Evergy and Evergy Kansas Central investments included in the table above are measured at NAV as they do not have readily determinable fair values. In certain situations, these investments may have redemption restrictions. The following table provides additional information on these Evergy and Evergy Kansas Central investments.

(a)This investment is in four long-term private equity funds that do not permit early withdrawal. Investments in these funds cannot be distributed until the underlying investments have been liquidated, which may take years from the date of initial liquidation. All funds have begun to make distributions.

(b)There is a holdback on final redemptions.

The Evergy Companies hold equity and debt investments classified as securities in various trusts including for the purposes of funding the decommissioning of Wolf Creek and for the benefit of certain retired executive officers of Evergy Kansas Central. The Evergy Companies record net realized and unrealized gains and losses on the nuclear decommissioning trusts in regulatory liabilities on their consolidated balance sheets and record net realized and unrealized gains and losses on the Evergy Companies' rabbi trusts in the consolidated statements of income and comprehensive income.

The following table summarizes the net unrealized gains (losses) for the Evergy Companies' nuclear decommissioning trusts and rabbi trusts.

11. COMMITMENTS AND CONTINGENCIES

Environmental Matters

Set forth below are descriptions of contingencies related to environmental matters that may impact the Evergy Companies' operations or their financial results. Management's assessment of these contingencies, which are based on federal and state statutes and regulations, and regulatory agency and judicial interpretations and actions, has evolved over time. These laws, regulations, interpretations and actions can also change, restrict or otherwise impact

the Evergy Companies' operations or financial results. The failure to comply with these laws, regulations, interpretations and actions could result in the assessment of administrative, civil and criminal penalties and the imposition of remedial requirements. The Evergy Companies believe that all their operations are in substantial compliance with current federal, state and local environmental standards.

There are a variety of final and proposed laws and regulations that could have a material adverse effect on the Evergy Companies' operations and consolidated financial results. Due in part to the complex nature of environmental laws and regulations, the Evergy Companies are unable to assess the impact of potential changes that may develop with respect to the environmental contingencies described below.

Ozone Interstate Transport State Implementation Plans (ITSIP)

In 2015, the Environmental Protection Agency (EPA) lowered the Ozone National Ambient Air Quality Standards (NAAQS) from 75 ppb to 70 ppb. States were required to submit ITSIPs in 2018 to comply with the "Good Neighbor Provision" of the Clean Air Act (CAA) as it applies to the revised NAAQS. The EPA did not act on these ITSIP submissions by the deadline established in the CAA and entered consent decrees establishing deadlines for the EPA to take final action on various ITSIPs. In February 2022, the EPA published a proposed rule to disapprove the ITSIPs submitted by nineteen states including Missouri and Oklahoma. In April 2022, the EPA published an approval of the Kansas ITSIP in the Federal Register. The Missouri Department of Natural Resources (MDNR) submitted a supplemental ITSIP to the EPA in November 2022. In February 2023, the EPA published a final rule disapproving the ITSIPs submitted by nineteen states, including the final disapproval of the Missouri and Oklahoma ITSIPs. In April 2023, the Attorneys General of Missouri and Oklahoma filed Petitions for Review in the U.S. Court of Appeals for the Eighth Circuit (Eighth Circuit) and the U.S. Court of Appeals for the Tenth Circuit (Tenth Circuit), respectively, challenging the EPA's disapproval. In May 2023, the Eighth Circuit granted a stay of the EPA's disapproval of the Missouri ITSIP. Similarly, in July 2023, the Tenth Circuit granted a stay of the EPA's disapproval of the Oklahoma ITSIP. In August 2024, the EPA published in the Federal Register a proposed rule to disapprove the supplemental ITSIP that Missouri submitted in November 2022. In January 2024, the EPA proposed to disapprove the previously-approved ITSIP for Kansas and ITSIPs submitted by four other states. To date, the EPA has not taken final action in this rulemaking. Disapproval of ITSIPs provides the EPA with authority to implement an interstate transport federal implementation plan (ITFIP) to replace them. As described below, the EPA's ITFIP has been stayed and may be withdrawn. In the event that the ITSIPs for Missouri, Oklahoma and Kansas were disapproved and the EPA's ITFIP took effect, the impact on the Evergy Companies' operations and the cost to comply could be material.

Ozone Interstate Transport Federal Implementation Plans

In April 2022, the EPA published in the Federal Register the proposed ITFIP to resolve outstanding "Good Neighbor" obligations with respect to the 2015 Ozone NAAQS for twenty-six states including Missouri and Oklahoma. This ITFIP would establish a revised Cross-State Air Pollution Rule (CSAPR) ozone season nitrogen oxide (NOx) emissions trading program for Electric Generating Units (EGUs) beginning in 2023 and would limit ozone season NOx emissions from certain industrial stationary sources beginning in 2026. The proposed rule would also establish a new daily backstop NOx emissions rate limit for applicable coal-fired units larger than 100 MW, as well as unit-specific NOx emission rate limits for certain industrial emission units and would feature "dynamic" adjustments of emission budgets for EGUs beginning with ozone season 2025. The proposed ITFIP included reductions to the state ozone season NOx budgets for Missouri and Oklahoma beginning in 2023 with additional reductions in future years. The Evergy Companies provided formal comments as part of the rulemaking process. In March 2023, the EPA issued the final ITFIPs for twenty-three states, including Missouri and Oklahoma, which included reduced ozone season NOx budgets for EGUs in Missouri, Oklahoma and other states, and included other features and requirements that were in the proposed version of the rule. Because the EPA's authority to impose an ITFIP for a state is triggered by the state's failure to submit an ITSIP addressing NAAQS by the statutory deadline or disapproval of an ITSIP, the EPA lacks authority under the CAA to impose an ITFIP on a state for which an ITSIP disapproval has been stayed by the courts. Accordingly, the EPA issued interim final rules staying the effectiveness of the ITFIP in both Missouri and Oklahoma while the stays issued by the Eighth and Tenth Circuits in the ITSIP disapproval cases remain in place. During this time, both states will continue to operate under the existing CSAPR program. While Kansas was not originally included in the ITFIP, in January 2024, the EPA issued a proposal to include Kansas in the ITFIP. In June 2024, the U.S. Supreme Court issued an order granting

emergency motions for stay filed by state and industry petitioners of the final ITFIP pending further review of the ITFIP by the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit). In March 2025, the EPA announced plans to end the Good Neighbor Rule for the 2015 Ozone NAAQS. In April 2025, the D.C. Circuit granted an EPA request to hold all challenges to the ITFIP in indefinite abeyance. If the ITFIP ultimately takes effect as promulgated for Missouri, Kansas and Oklahoma following the pending litigation or the EPA is unable to end the program as announced, the impact on the Evergy Companies' operations and the cost to comply could be material.

Particulate Matter National Ambient Air Quality Standards

In March 2024, the EPA published in the Federal Register the final rule which strengthens the primary annual PM2.5 (particulate matter less than 2.5 microns in diameter) NAAQS by lowering the primary annual PM2.5 NAAQS from 12.0 µg/m3 (micrograms per cubic meter) to 9.0 µg/m3. The final rule took effect in May 2024. In August 2024, the EPA released the PM2.5 ambient monitor design values for calendar years 2021 through 2023. These design values are to be used by each state governor for recommending to the EPA attainment designations for their states. In February 2025, the Kansas Governor sent recommendations to the EPA to designate the entire state of Kansas as either attainment or attainment/unclassifiable for the 2024 annual PM2.5 NAAQS. In March 2025, the EPA announced it plans to reconsider the 2024 PM2.5 NAAQS. As a result of the EPA's plans to reconsider this NAAQS, the Missouri Governor delayed submitting area designations to the EPA. While the EPA is required to issue final designations for all states, including Kansas and Missouri, by February 2026, the issuance of final designations is in question based on the EPA's plans to reconsider this NAAQS. Due to the uncertainty of the attainment status of portions of the service territory and potential reconsideration of the NAAQS, the Evergy Companies are unable to accurately assess the impacts on their operations or consolidated financial results, but the cost to comply with lower PM2.5 NAAQS could be material.

Regional Haze Rule

In 1999, the EPA finalized the Regional Haze Rule which aims to restore national parks and wilderness areas to pristine conditions. The rule requires states in coordination with the EPA, the National Park Service, the U.S. Fish and Wildlife Service, the U.S. Forest Service, and other interested parties to develop and implement air quality protection plans to reduce the pollution that causes visibility impairment. There are 156 "Class I" areas across the U.S. that must be restored to pristine conditions by the year 2064. There are no Class I areas in Kansas, whereas Missouri has two: the Hercules-Glades Wilderness Area and the Mingo Wilderness Area. States must submit revisions to their Regional Haze Rule state implementation plans (SIPs) every ten years and the first round was due in 2007. For the second ten-year implementation period, the EPA issued a final rule revision in 2017 that allowed states to submit their SIP revisions by July 2021.

The Missouri SIP revision does not require any additional reductions from the Evergy Companies' generating units in the state. MDNR submitted the Missouri SIP revision to the EPA in August 2022, however, they failed to do so by the EPA's revised submittal deadline in August 2022. As a result, in August 2022, the EPA published "finding of failure" with respect to Missouri and fourteen other states for failing to submit their Regional Haze SIP revisions by the applicable deadline. This finding of failure established a two-year deadline for the EPA to issue a Regional Haze federal implementation plan (FIP) for each state unless the state submits and the EPA approves a revised SIP that meets all applicable requirements before the EPA issues the FIP. In July 2024, the EPA published in the Federal Register a proposal to partially approve and partially disapprove Missouri's Regional Haze SIP revision.

The Kansas SIP revision did not include any additional emission reductions by electric utilities based on the significant reductions that were achieved during the first implementation period. The Kansas Department of Health and Environment (KDHE) submitted the Kansas SIP revision in July 2021. In August 2024, the EPA issued the final disapproval of the Kansas SIP revision for failing to conduct a four-factor analysis for at least two emission sources in Kansas. In response to the August 2024 final disapproval, in October 2025, KDHE placed a supplemental Kansas SIP revision on public notice. In this supplement, the KDHE performed additional analyses for two Kansas emission sources, including Evergy's La Cygne Station, and determined no additional requirements should be necessary for any Kansas emission source.

In March 2025, the EPA announced plans to restructure the Regional Haze Program and in October 2025, the EPA published a Notice of Proposed Advanced Rulemaking requesting comments to assist in the development of regulatory changes to the current Regional Haze Program. Due to uncertainty regarding the status of the Regional Haze Program and when or if a Kansas or Missouri revised SIP or FIP is finalized, the overall costs of implementing the rules could be material to the Evergy Companies.

Greenhouse Gases

Burning coal and other fossil fuels releases carbon dioxide (CO2) and other gases referred to as greenhouse gases (GHG). Various regulations under the CAA limit CO2 and other GHG emissions, and in addition, other measures are being imposed or offered by individual states, municipalities and regional agreements with the goal of reducing GHG emissions. In April 2024, the EPA finalized the GHG regulations and GHG guidelines that apply to new and existing fossil-fuel fired EGUs. The final GHG regulation establishes CO2 limitations on emissions from new and reconstructed stationary combustion turbines. The GHG guidelines set CO2 emission limitations for existing coal, oil and gas-fired steam generating units. For new and reconstructed stationary combustion turbines, the emission limitations were developed by applying the Best System of Emission Reduction (BSER) to three distinct subcategories (low load, intermediate load and base load) taking into consideration the annual capacity factor of the stationary combustion turbine. For intermediate and base load stationary combustion turbines, BSER is assumed to be the utilization of highly efficient combustion turbine technology. Base load stationary combustion turbines are also required to consider the emissions reduction associated with the application of carbon capture and sequestration (CCS) beginning in 2032. For existing coal-fired EGUs, the emission limitations were established by applying the BSER to two subcategories (medium and long-term). For medium-term existing coal-fired units, which are units retiring between 2032 and 2038, the BSER established emission limitation is based on co-firing natural gas beginning in 2030. For units operating in 2039 and after, BSER is the application of CCS starting in 2032. In July 2024, the D.C. Circuit denied motions of stay filed by various states, industry and trade organizations; however, the D.C. Circuit has ordered expedited review of the challenges to the final regulations and guidelines. In December 2024, a three-judge panel of the D.C. Circuit heard oral arguments on challenges to the merits of the rule. In March 2025, the EPA announced it plans to reconsider the GHG regulation and guidelines. While the EPA reconsiders the GHG regulation and guidelines, the D.C. Circuit granted an unopposed motion to hold the case challenging the merits of the rule in abeyance. In June 2025, the EPA published a proposed rule to repeal both the 2015 GHG emission standards for new fossil-fuel fired EGUs and the April 2024 GHG emission standards for new and existing fossil-fuel fired EGUs. In the same June 2025 proposed rule, the EPA included an alternative proposal to repeal the most burdensome requirements of the 2024 rule including the elimination of CCS as BSER. In July 2025, the EPA proposed to rescind the 2009 GHG Endangerment Finding (Endangerment Finding). The Endangerment Finding applies to GHG emissions from new motor vehicles and also provides justification for declaring GHG emissions as a threat to public health and welfare, thereby establishing the basis for regulating GHG emission under the CAA. If the Endangerment Finding is rescinded there would be no justification for regulating GHG emissions from the power sector.

Due to uncertainty regarding which of these proposed rules will be finalized and the ongoing judicial review, in addition to the uncertainty regarding the potential rescission of the Endangerment Finding, the Evergy Companies are unable to accurately assess the impacts on their operations or consolidated financial results, but the cost to comply could be material.

Regulation of Coal Combustion Residuals (CCRs)

In the course of operating their coal generation plants, the Evergy Companies produce CCRs, including fly ash, gypsum and bottom ash. The EPA published a rule to regulate CCRs in April 2015 that requires additional CCR handling, processing and storage equipment and closure of certain ash disposal units. In January 2022, the EPA published proposed determinations for facilities that filed closure extensions for unlined or clay-lined CCR units. These proposed determinations include various interpretations of the CCR regulations and compliance expectations that may impact all owners of CCR units. These interpretations could require modified compliance plans such as different methods of CCR unit closure. Additionally, more stringent remediation requirements for units that are in corrective action or forced to go into corrective action are possible. The cost to comply with these proposed determinations by the EPA could be material.

In April 2024, the EPA finalized an expansion to the CCR regulations focused on legacy surface impoundments and historic placements of CCR. This regulation expands applicability of the 2015 CCR regulation to inactive landfills

and beneficial use sites not previously regulated. Litigation could impact the timing or cost to comply. In March 2025, the EPA announced its plans to update regulations of CCRs, and in July 2025, issued a proposed rulemaking extending deadlines for compliance with various aspects of the CCR legacy rule. The EPA has indicated a second rulemaking modifying CCR requirements should be anticipated later in 2025 or 2026, however specific details of any planned revisions have not been provided.

The Evergy Companies have recorded asset retirement obligations (AROs) for their current estimates for the closure of ash disposal ponds, landfills and other historical placements of CCR. The revision of these AROs may be required in the future due to information collected in the April 2024 CCR regulation's Facility Evaluation Reports (FERs), changes in existing CCR regulations, the results of groundwater monitoring of CCR units, changes in interpretation of existing CCR regulations or changes in the timing or cost to close ash disposal ponds and landfills. The revision of AROs for regulated operations has no income statement impact due to the deferral of the adjustments through a regulatory asset. If revisions to these AROs are necessary, the impact on the Evergy Companies' operations or consolidated financial results could be material.

Montrose Station CCRs

In 2025, three lawsuits, including one seeking class certification, were filed in the Circuit Court of Henry County, Missouri against Evergy Metro and two other defendants alleging unspecified damages resulting from the defendants' alleged unlawful and negligent spreading of CCRs associated with the Montrose Station coal ash landfill. Montrose Station was a coal-fired generating facility which was operated by Evergy Metro until its closure in 2018. The cases are at preliminary stages and Evergy and Evergy Metro are unable to assess the outcome or reasonably estimate any possible damages with respect to the claims. However, Evergy and Evergy Metro believe the claims are without merit and intend to vigorously defend themselves.

Nuclear Antitrust Class Action

In July 2025, a class action complaint was filed in the U.S. District Court for the District of Maryland alleging violations of the Sherman Antitrust Act in establishing wages for employees at nuclear facilities since 2003. The complaint names 28 defendants, including all 26 owner operators of nuclear facilities in the United States, or affiliated entities, including Wolf Creek Nuclear Operating Corporation, which owns and operates Wolf Creek, a nuclear facility in Kansas. Evergy indirectly owns 94% of Wolf Creek, with Evergy Kansas Central and Evergy Metro each owning 47% of the nuclear facility. This case is at a preliminary stage and the Evergy Companies are unable to assess the outcome or reasonably estimate any possible damages with respect to the claims.

12. RELATED PARTY TRANSACTIONS AND RELATIONSHIPS

In the normal course of business, Evergy Kansas Central, Evergy Metro and Evergy Missouri West engage in related party transactions with one another. In addition, Evergy Kansas Central, Evergy Metro and Evergy Missouri West are engaging in the construction of jointly-owned generation facilities. A summary of these related party transactions and the amounts associated with them is provided below.

Jointly-Owned Plants and Shared Services

Employees of Evergy Kansas Central and Evergy Metro manage Evergy Missouri West's business and operate its facilities at cost, including Evergy Missouri West's 18% ownership interest in Evergy Metro's Iatan Nos. 1 and 2. Employees of Evergy Kansas Central manage Jeffrey Energy Center (JEC) and operate its facilities at cost, including Evergy Missouri West's 8% ownership interest in JEC. Employees of Evergy Metro manage La Cygne Station and operate its facilities at cost, including Evergy Kansas Central's 50% interest in La Cygne Station. Employees of Evergy Metro and Evergy Kansas Central also provide one another with shared service support, including costs related to human resources, information technology, accounting and legal services.

The operating expenses and capital costs billed for jointly-owned plants and shared services are detailed in the following table.

Related Party Net Receivables and Payables

The following table summarizes Evergy Kansas Central's and Evergy Metro's related party net receivables and payables.

Money Pool

Evergy Kansas Central, Evergy Metro and Evergy Missouri West are authorized to participate in the Evergy, Inc. money pool, which is an internal financing arrangement in which funds may be lent on a short-term basis between Evergy Kansas Central, Evergy Metro, Evergy Missouri West and Evergy, Inc. Evergy, Inc. can lend but not borrow under the money pool.

As of September 30, 2025, Evergy Kansas Central had money pool receivables of $3.6 million and $8.7 million from Evergy Metro and Evergy Missouri West, respectively. As of December 31, 2024, Evergy Kansas Central and Evergy Metro had no outstanding receivables or payables under the money pool.

Tax Allocation Agreement

Evergy files a consolidated federal income tax return as well as unitary and combined income tax returns in several state jurisdictions with Kansas and Missouri being the most significant. Income taxes for consolidated or combined subsidiaries are allocated to the subsidiaries based on separate company computations of income or loss. The following table summarizes Evergy Kansas Central's and Evergy Metro's income taxes receivable from (payable to) Evergy.

13. SHAREHOLDERS' EQUITY

ATM Program

In May 2025, Evergy entered into an equity distribution agreement, pursuant to which Evergy may sell, from time to time, up to an aggregate of $1.2 billion of its common stock through an ATM Program, which may utilize forward sales agreements. Evergy subsequently entered into forward sale agreements under the ATM program and as of September 30, 2025, the ATM Program had approximately $1.1 billion of common stock available for issuance.

The forward sale agreements outstanding as of September 30, 2025, can be settled at Evergy’s discretion on or prior to dates ranging from March 2027 to October 2027. On a settlement date or dates, if Evergy elects to physically settle a forward sale agreement, Evergy will issue shares of common stock to the counterparties at the then-applicable forward sale price. The initial forward sale price for the outstanding agreements ranged from $71.29 to $72.76, with a weighted average initial forward sale price of $72.08. The initial forward sale price is subject to adjustment on a daily basis based on an interest rate factor and decreased on certain dates by predetermined amounts to reflect expected dividend payments. The forward sale agreements will be physically settled unless Evergy elects to settle in cash or to net share settle. At September 30, 2025, Evergy could have settled the forward sale agreements with physical delivery of 1.5 million shares of common stock to the respective counterparties in exchange for cash of $108.7 million. Alternatively, the forward sale agreements could have also been settled at September 30, 2025, with delivery of approximately $5.4 million of cash or approximately 0.1 million shares of common stock to the counterparties, if Evergy elected net cash or net share settlement, respectively.

Evergy completed an additional forward sale transaction in October 2025 resulting in a $72.50 weighted average initial forward sale price for all outstanding agreements and 1.7 million shares that would be issued if all outstanding agreements were physically settled.

Evergy has not received any proceeds related to the outstanding forward sale agreements. The forward sale agreements have been classified as equity transactions.

14. TAXES

Effective Income Tax Rates

Effective income tax rates reflected in the financial statements and the reasons for their differences from the statutory federal rates are detailed in the following tables.