GEORGIA POWER CO 10-Q

so-20260630 Table of Contents Index to Financial Statements UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 FORM 10-Q ☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the quarterly period ended June 30, 2026 OR ☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from to Commission File Number Registrant, State of Incorporation, Address and Telephone Number I.R.S. Employer Identification No. 1-3526 The Southern Company 58-0690070 (A Delaware Corporation) 30 Ivan Allen Jr. Boulevard, N.W. Atlanta , Georgia 30308 ( 404 ) 506-5000 1-3164 Alabama Power Company 63-0004250 (An Alabama Corporation) 600 North 18th Street Birmingham , Alabama 35203 ( 205 ) 257-1000 1-6468 Georgia Power Company 58-0257110 (A Georgia Corporation) 241 Ralph McGill Boulevard, N.E. Atlanta , Georgia 30308 ( 404 ) 506-6526 001-11229 Mississippi Power Company 64-0205820 (A Mississippi Corporation) 2992 West Beach Boulevard Gulfport , Mississippi 39501 ( 228 ) 864-1211 001-37803 Southern Power Company 58-2598670 (A Delaware Corporation) 30 Ivan Allen Jr. Boulevard, N.W. Atlanta , Georgia 30308 ( 404 ) 506-5000 1-14174 Southern Company Gas 58-2210952 (A Georgia Corporation) 725 W. Peachtree Street, N.E. Atlanta , Georgia 30308 ( 404 ) 584-4000 Table of Contents Index to Financial Statements Securities registered pursuant to Section 12(b) of the Act: Registrant Title of Each Class Trading Symbol(s) Name of Each Exchange on Which Registered The Southern Company Common Stock, par value $0.01 per share SO New York Stock Exchange (NYSE) The Southern Company Series 2017B 5.25% Junior Subordinated Notes due 2077 SOJC NYSE The Southern Company Series 2020A 4.95% Junior Subordinated Notes due 2080 SOJD NYSE The Southern Company Series 2020C 4.20% Junior Subordinated Notes due 2060 SOJE NYSE The Southern Company Series 2021B 1.875% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due 2081 SO 81 NYSE The Southern Company Series 2025A 6.50% Junior Subordinated Notes due 2085 SOJF NYSE The Southern Company 2025 Series A Corporate Units SOMN NYSE Georgia Power Company Series 2017A 5.00% Junior Subordinated Notes due 2077 GPJA NYSE Southern Power Company Series 2016B 1.850% Senior Notes due 2026 SO/26A NYSE Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes þ No ¨ Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). Yes þ No ¨ Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act. Registrant Large Accelerated Filer Accelerated Filer Non-accelerated Filer Smaller Reporting Company Emerging Growth Company The Southern Company X Alabama Power Company X Georgia Power Company X Mississippi Power Company X Southern Power Company X Southern Company Gas X If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐ Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No þ (Response applicable to all registrants.) Registrant Description of Common Stock Shares Outstanding at June 30, 2026 The Southern Company Par Value $0.01 Per Share 1,150,362,966 Alabama Power Company Par Value $40 Per Share 30,537,500 Georgia Power Company Without Par Value 9,261,500 Mississippi Power Company Without Par Value 1,121,000 Southern Power Company Par Value $0.01 Per Share 1,000 Southern Company Gas Par Value $0.01 Per Share 100 This combined Form 10-Q is separately filed by The Southern Company, Alabama Power Company, Georgia Power Company, Mississippi Power Company, Southern Power Company, and Southern Company Gas. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrants. 2 Table of Contents Index to Financial Statements TABLE OF CONTENTS Page Definitions 4 Cautionary Statement Regarding Forward-Looking Information 7 PART I—FINANCIAL INFORMATION Item 1. Financial Statements (Unaudited) 9 Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations 90 Item 3. Quantitative and Qualitative Disclosures about Market Risk 139 Item 4. Controls and Procedures 139 PART II—OTHER INFORMATION Item 1. Legal Proceedings 140 Item 1A. Risk Factors 140 Item 2. Unregistered Sales of Equity Securities and Use of Proceeds Inapplicable Item 3. Defaults Upon Senior Securities Inapplicable Item 4. Mine Safety Disclosures Inapplicable Item 5. Other Information 140 Item 6. Exhibits 140 Signatures 144 3 Table of Contents Index to Financial Statements DEFINITIONS Term Meaning 2022 ARP Georgia Power's Alternate Rate Plan approved by the Georgia PSC in 2022 for the years 2023 through 2025 2023 IRP Update Georgia Power's updated IRP filed in 2023 and approved by the Georgia PSC in 2024 as modified by a stipulation among Georgia Power, the staff of the Georgia PSC, and certain intervenors 2024 ELG Rule Final rule published by the EPA in 2024 revising the steam effluent guidelines AFUDC Allowance for funds used during construction AGL Services Company AGL Services Company, Inc., the Southern Company Gas system service company and a wholly-owned subsidiary of Southern Company Gas Alabama Power Alabama Power Company ARO Asset retirement obligation Atlanta Gas Light Atlanta Gas Light Company, a wholly-owned subsidiary of Southern Company Gas CAMT Corporate alternative minimum tax CCR Coal combustion residuals Chattanooga Gas Chattanooga Gas Company, a wholly-owned subsidiary of Southern Company Gas COD Commercial operation date CODM Chief operating decision maker CWIP Construction work in progress Dalton City of Dalton, Georgia, an incorporated municipality in the state of Georgia, acting by and through its Board of Water, Light, and Sinking Fund Commissioners Dalton Pipeline A pipeline facility in Georgia in which Southern Company Gas has a 50% undivided ownership interest DOE U.S. Department of Energy ECO Plan Mississippi Power's environmental compliance overview plan EPA U.S. Environmental Protection Agency EPS Earnings per share FCC Federal Communications Commission FERC Federal Energy Regulatory Commission FFB Federal Financing Bank Fitch Fitch Ratings, Inc. Form 10-K Annual Report on Form 10-K of Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas for the year ended December 31, 2025, as applicable GAAP U.S. generally accepted accounting principles Georgia Power Georgia Power Company Heating Degree Days A measure of weather, calculated when the average daily temperatures are less than 65 degrees Fahrenheit Heating Season The period from November through March when Southern Company Gas' natural gas usage and operating revenues are generally higher HLBV Hypothetical liquidation at book value IIC Intercompany Interchange Contract Illinois Commission Illinois Commerce Commission Internal Revenue Code Internal Revenue Code of 1986, as amended IRA Inflation Reduction Act of 2022 IRP Integrated resource plan ITC Investment tax credit Jurisdictional Separation Study Order Authorization from the Alabama PSC in June 2025 for Alabama Power to defer certain costs associated with capacity previously allocated to wholesale electric services that is now being used for retail electric service KWH Kilowatt-hour 4 Table of Contents Index to Financial Statements DEFINITIONS (continued) Term Meaning LIFO Last-in, first-out LTSA Long-term service agreement MEAG Power Municipal Electric Authority of Georgia Mississippi Power Mississippi Power Company mmBtu Million British thermal units Moody's Moody's Investors Service, Inc. MRA Municipal and Rural Associations MW Megawatt natural gas distribution utilities Southern Company Gas' natural gas distribution utilities (Nicor Gas, Atlanta Gas Light, Virginia Natural Gas, and Chattanooga Gas) NDR Alabama Power's Natural Disaster Reserve Nicor Gas Northern Illinois Gas Company, a wholly-owned subsidiary of Southern Company Gas N/M Not meaningful NRC U.S. Nuclear Regulatory Commission OBBB One Big Beautiful Bill Act OCI Other comprehensive income OPC Oglethorpe Power Corporation (an electric membership corporation) PEP Mississippi Power's Performance Evaluation Plan PowerSecure PowerSecure, Inc., a wholly-owned subsidiary of Southern Company PPA Power purchase agreements, as well as, for Southern Power, contracts for differences that provide the owner of a renewable facility a certain fixed price for the electricity sold to the grid PSC Public Service Commission PTC Production tax credit Rate CNP Alabama Power's Rate Certificated New Plant, consisting of Rate CNP New Plant, Rate CNP Compliance, Rate CNP PPA, and Rate CNP Depreciation Rate ECR Alabama Power's Rate Energy Cost Recovery Rate RSE Alabama Power's Rate Stabilization and Equalization Registrants Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power Company, and Southern Company Gas ROE Return on equity S&P S&P Global Ratings, a division of S&P Global Inc. SCS Southern Company Services, Inc., the Southern Company system service company and a wholly-owned subsidiary of Southern Company SEC U.S. Securities and Exchange Commission SEGCO Southern Electric Generating Company, 50% owned by each of Alabama Power and Georgia Power SNG Southern Natural Gas Company, L.L.C., a pipeline system in which Southern Company Gas has a 50% ownership interest SOFR Secured Overnight Financing Rate Southern Company The Southern Company Southern Company Gas Southern Company Gas and its subsidiaries Southern Company Gas Capital Southern Company Gas Capital Corporation, a wholly-owned subsidiary of Southern Company Gas Southern Company power pool The operating arrangement whereby the integrated generating resources of the traditional electric operating companies and Southern Power (excluding subsidiaries) are subject to joint commitment and dispatch in order to serve their combined load obligations Southern Company system Southern Company, the traditional electric operating companies, Southern Power, Southern Company Gas, SEGCO, Southern Nuclear, SCS, Southern Linc, PowerSecure, and other subsidiaries Southern Holdings Southern Company Holdings, Inc., a wholly-owned subsidiary of Southern Company 5 Table of Contents Index to Financial Statements DEFINITIONS (continued) Term Meaning Southern Linc Southern Communications Services, Inc., a wholly-owned subsidiary of Southern Company, doing business as Southern Linc Southern Nuclear Southern Nuclear Operating Company, Inc., a wholly-owned subsidiary of Southern Company Southern Power Southern Power Company and its subsidiaries SouthStar SouthStar Energy Services, LLC (a Marketer), a wholly-owned subsidiary of Southern Company Gas SP Solar SP Solar Holdings I, LP, a limited partnership indirectly owning substantially all of Southern Power's solar and battery energy storage facilities, in which Southern Power has a 67% ownership interest SP Wind SP Wind Holdings II, LLC, a holding company owning a portfolio of eight operating wind facilities and wholly owned by Southern Power as of December 31, 2025, was previously in a tax equity arrangement where Southern Power was the controlling partner through December 31, 2025 SRR Mississippi Power's System Restoration Rider, a tariff for retail property damage cost recovery and reserve Subsidiary Registrants Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas Tax Reform Legislation The Tax Cuts and Jobs Act, which became effective on January 1, 2018 traditional electric operating companies Alabama Power, Georgia Power, and Mississippi Power U.S. Treasury U.S. Department of the Treasury VIE Variable interest entity Virginia Natural Gas Virginia Natural Gas, Inc., a wholly-owned subsidiary of Southern Company Gas Vogtle Owners Georgia Power, OPC, MEAG Power, and Dalton 6 Table of Contents Index to Financial Statements CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION This Quarterly Report on Form 10-Q contains forward-looking statements. Forward-looking statements include, among other things, statements concerning regulated rates, the strategic goals for the business, customer and sales growth, economic conditions, including interest rates, tariffs, and inflation, cost recovery and other rate actions, current and proposed environmental regulations and related compliance plans and estimated expenditures, pending or potential litigation matters, access to sources of capital, financing activities, completion dates and costs of construction projects, filings with state and federal regulatory authorities, and estimated construction plans and expenditures. In some cases, forward-looking statements can be identified by terminology such as "may," "will," "could," "would," "should," "expects," "plans," "anticipates," "believes," "estimates," "projects," "predicts," "potential," or "continue" or the negative of these terms or other similar terminology. There are various factors that could cause actual results to differ materially from those suggested by the forward-looking statements; accordingly, there can be no assurance that such indicated results will be realized. These factors include: • the impact of recent and future federal and state legal and regulatory changes, including tax, environmental, and other laws and regulations to which Southern Company and its subsidiaries are subject, as well as changes in application of existing laws, regulations, and guidance; • the extent and timing of costs and legal requirements related to CCR; • current and future litigation or regulatory investigations, proceedings, or inquiries; • the effects, extent, and timing of the entry of additional competition in the markets in which Southern Company's subsidiaries operate, including from the development and deployment of alternative energy sources; • variations in demand for electricity and natural gas, including uncertainties related to projected significant growth in electricity demand driven primarily by data centers and other large load customers, and the related requirement for substantial new generation and transmission investments, creating capital access and revenue recovery risks for the traditional electric operating companies; • customer affordability matters; • available sources and costs of natural gas and other fuels and commodities; • the ability to complete necessary or desirable pipeline expansion or infrastructure projects, limits on pipeline capacity, public and policymaker support for such projects, and operational interruptions to natural gas distribution and transmission activities; • transmission constraints; • the ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of facilities or other projects due to challenges which include, but are not limited to, changes in labor costs, availability, and productivity; challenges with the management of contractors or vendors; subcontractor performance; adverse weather conditions; shortages, delays, increased costs, or inconsistent quality of equipment, materials, and labor; contractor or supplier delay; the impacts of inflation and trade policies (including tariffs and other trade measures) of the United States and other countries; delays due to judicial or regulatory action; nonperformance under construction, operating, or other agreements; operational readiness, including specialized operator training and required site safety programs; engineering or design problems or any remediation related thereto; design and other licensing-based compliance matters; challenges with start-up activities, including major equipment failure, or system integration, and/or operational performance; challenges related to future epidemic or pandemic health events; continued public and policymaker support for projects; environmental and geological conditions; delays or increased costs to interconnect facilities to transmission grids; and increased financing costs as a result of changes in interest rates or as a result of project delays; • legal proceedings and regulatory approvals and actions related to past, ongoing, and proposed construction projects, including state PSC or other applicable state regulatory agency approvals and FERC and NRC actions; • the ability to construct facilities in accordance with the requirements of permits and licenses, to satisfy any environmental performance standards and the requirements of tax credits and other incentives, and to integrate facilities into the Southern Company system upon completion of construction; • investment performance of the employee and retiree benefit plans and nuclear decommissioning trust funds and, with respect to retiree benefit plans, changes in actuarial assumptions and differences between the assumptions and actual values, any of the foregoing of which could cause additional funding requirements; • advances in technology, including the pace and extent of development of low- to no-carbon energy and battery energy storage technologies and the impact of advancing technology on data center and other large load customer demand; • performance of counterparties under ongoing renewable energy partnerships and development agreements; 7 Table of Contents Index to Financial Statements CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION (continued) • state and federal rate regulations and the impact of pending and future rate cases and negotiations, including rate actions relating to ROE, equity ratios, additional generating capacity and transmission facilities, extension of retirement dates for fossil fuel plants, and fuel and other cost recovery mechanisms; • the ability to successfully operate the traditional electric operating companies', SEGCO's, and Southern Power's generation, transmission, distribution, and battery energy storage facilities, as applicable, and Southern Company Gas' natural gas distribution and storage facilities and the successful performance of necessary corporate functions; • the inherent risks involved in operating nuclear generating facilities; • the inherent risks involved in generation, transmission, and distribution of electricity and transportation and storage of natural gas, including accidents, explosions, fires, mechanical problems, discharges or releases of toxic or hazardous substances or gases, and other environmental risks; • the performance of projects undertaken by the non-utility businesses and the success of efforts to invest in and develop new opportunities; • internal restructuring or other restructuring options that may be pursued; • potential business strategies, including acquisitions or dispositions of assets or businesses, or interests therein, which cannot be assured to be completed or beneficial to Southern Company or its subsidiaries; • the ability of counterparties of Southern Company and its subsidiaries to make payments as and when due and to perform as required; • the ability to obtain new short- and long-term contracts with wholesale customers; • the direct or indirect effect on the Southern Company system's business resulting from cyber intrusion or physical attack and the threat of cyber and physical attacks; • global and U.S. economic conditions, including impacts from geopolitical conflicts, recession, inflation, changes in trade policies (including tariffs and other trade measures) of the United States and other countries, interest rate fluctuations, and financial market conditions, and the results of financing efforts; • prolonged or recurring U.S. federal government shutdowns; • access to capital markets and other financing sources; • changes in Southern Company's and any of its subsidiaries' credit ratings; • the ability of the traditional electric operating companies to obtain additional generating capacity (or sell excess generating capacity) at competitive prices; • catastrophic events such as fires, including wildfires, land movement, earthquakes, explosions, floods, high winds, tornadoes, hurricanes and other storms, solar flares, droughts, future epidemic or pandemic health events, wars, political unrest, or other similar occurrences; • the direct or indirect effects on the Southern Company system's business resulting from incidents affecting the U.S. electric grid, natural gas pipeline infrastructure, or operation of generating or storage resources; • impairments of goodwill or long-lived assets; • the effect of accounting pronouncements issued periodically by standard-setting bodies; and • other factors discussed elsewhere herein and in other reports (including the Form 10-K) filed by the Registrants from time to time with the SEC. The Registrants expressly disclaim any obligation to update any forward-looking statements. 8 Table of Contents Index to Financial Statements PART I Item 1. Financial Statements (Unaudited). Page The Southern Company and Subsidiary Companies: Condensed Consolidated Statements of Income 10 Condensed Consolidated Statements of Comprehensive Income 11 Condensed Consolidated Statements of Cash Flows 12 Condensed Consolidated Balance Sheets 13 Condensed Consolidated Statements of Stockholders' Equity 15 Alabama Power Company: Condensed Statements of Income 16 Condensed Statements of Comprehensive Income 16 Condensed Statements of Cash Flows 17 Condensed Balance Sheets 18 Condensed Statements of Common Stockholder's Equity 20 Georgia Power Company: Condensed Statements of Income 21 Condensed Statements of Comprehensive Income 21 Condensed Statements of Cash Flows 22 Condensed Balance Sheets 23 Condensed Statements of Common Stockholder's Equity 25 Mississippi Power Company: Condensed Statements of Income and Comprehensive Income 26 Condensed Statements of Cash Flows 27 Condensed Balance Sheets 28 Condensed Statements of Common Stockholder's Equity 30 Southern Power Company and Subsidiary Companies: Condensed Consolidated Statements of Income (Loss) 31 Condensed Consolidated Statements of Comprehensive Income (Loss) 31 Condensed Consolidated Statements of Cash Flows 32 Condensed Consolidated Balance Sheets 33 Condensed Consolidated Statements of Stockholders' Equity 35 Southern Company Gas and Subsidiary Companies: Condensed Consolidated Statements of Income 36 Condensed Consolidated Statements of Comprehensive Income 36 Condensed Consolidated Statements of Cash Flows 37 Condensed Consolidated Balance Sheets 38 Condensed Consolidated Statements of Stockholder's Equity 40 Combined Notes to the Condensed Financial Statements 41 9 Table of Contents Index to Financial Statements THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Operating Revenues: Retail electric revenues $ 4,745 $ 4,758 $ 9,385 $ 9,358 Wholesale electric revenues 699 681 1,664 1,425 Other electric revenues 242 220 507 463 Natural gas revenues (includes alternative revenue programs of $ 4 , $( 9 ), $ 2 , and $( 28 ), respectively) 966 979 3,157 2,818 Other revenues 325 335 661 684 Total operating revenues 6,977 6,973 15,374 14,748 Operating Expenses: Fuel 1,054 1,116 2,544 2,408 Purchased power 288 260 532 510 Cost of natural gas 177 255 1,103 929 Cost of other sales 176 167 357 366 Other operations and maintenance 1,705 1,685 3,359 3,305 Depreciation and amortization 1,434 1,323 2,854 2,608 Taxes other than income taxes 367 403 831 848 Total operating expenses 5,201 5,209 11,580 10,974 Operating Income 1,776 1,764 3,794 3,774 Other Income and (Expense): Allowance for equity funds used during construction 128 80 248 153 Earnings from equity method investments 86 10 136 43 Interest expense, net of amounts capitalized ( 796 ) ( 874 ) ( 1,573 ) ( 1,588 ) Other income (expense), net 181 162 336 310 Total other income and (expense) ( 401 ) ( 622 ) ( 853 ) ( 1,082 ) Earnings Before Income Taxes 1,375 1,142 2,941 2,692 Income taxes 187 289 414 569 Consolidated Net Income 1,188 853 2,527 2,123 Net income (loss) attributable to noncontrolling interests 14 ( 27 ) ( 4 ) ( 91 ) Consolidated Net Income Attributable to Southern Company $ 1,174 $ 880 $ 2,531 $ 2,214 Common Stock Data: Earnings per share - Basic $ 1.03 $ 0.80 $ 2.24 $ 2.01 Diluted $ 1.03 $ 0.79 $ 2.23 $ 2.00 Average number of shares of common stock outstanding (in millions) Basic 1,137 1,101 1,130 1,100 Diluted 1,141 1,108 1,134 1,107 The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements. 10 Table of Contents Index to Financial Statements THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Consolidated Net Income $ 1,188 $ 853 $ 2,527 $ 2,123 Other comprehensive income (loss): Qualifying hedges: Changes in fair value, net of tax of $( 4 ), $ 11 , $( 4 ), and $ 16 , respectively ( 13 ) 35 ( 16 ) 49 Reclassification adjustment for amounts included in net income, net of tax of $ 3 , $( 10 ), $ 4 , and $( 14 ), respectively 7 ( 31 ) 11 ( 43 ) Pension and other postretirement benefit plans: Benefit plan net gain (loss), net of tax of $ — , $ — , $ — , and $ — , respectively — — 1 1 Reclassification adjustment for amounts included in net income, net of tax of $ — , $ — , $ — , and $ — , respectively 1 — 1 — Total other comprehensive income (loss) ( 5 ) 4 ( 3 ) 7 Comprehensive Income 1,183 857 2,524 2,130 Comprehensive income (loss) attributable to noncontrolling interests 14 ( 27 ) ( 4 ) ( 91 ) Consolidated Comprehensive Income Attributable to Southern Company $ 1,169 $ 884 $ 2,528 $ 2,221 The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements. 11 Table of Contents Index to Financial Statements THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) For the Six Months Ended June 30, 2026 2025 (in millions) Operating Activities: Consolidated net income $ 2,527 $ 2,123 Adjustments to reconcile consolidated net income to net cash provided from operating activities — Depreciation and amortization, total 3,176 2,860 Deferred income taxes 310 453 Allowance for equity funds used during construction ( 248 ) ( 153 ) Pension, postretirement, and other employee benefits ( 277 ) ( 253 ) Settlement of asset retirement obligations ( 283 ) ( 285 ) Stock based compensation expense 112 102 Storm damage cost recovery – long-term ( 139 ) ( 238 ) Other, net ( 87 ) 76 Changes in certain current assets and liabilities — -Receivables 116 ( 130 ) -Retail fuel cost under recovery 188 158 -Prepayments ( 96 ) ( 109 ) -Materials and supplies ( 178 ) 35 -Natural gas for sale, net of temporary LIFO liquidation 197 233 -Other current assets ( 60 ) 61 -Accounts payable ( 403 ) ( 695 ) -Accrued taxes ( 221 ) ( 245 ) -Accrued compensation ( 459 ) ( 421 ) -Other current liabilities 105 ( 141 ) Net cash provided from operating activities 4,280 3,431 Investing Activities: Property additions ( 6,639 ) ( 5,456 ) Contributions in aid of construction 313 219 Nuclear decommissioning trust fund purchases ( 994 ) ( 777 ) Nuclear decommissioning trust fund sales 994 777 Cost of removal, net of salvage ( 349 ) ( 304 ) Other investing activities ( 83 ) ( 193 ) Net cash used for investing activities ( 6,758 ) ( 5,734 ) Financing Activities: Increase (decrease) in notes payable, net 1,415 ( 150 ) Proceeds — Long-term debt 4,790 6,319 Short-term borrowings 350 200 Common stock 2,596 62 Redemptions and repurchases — Long-term debt ( 3,085 ) ( 2,254 ) Short-term borrowings ( 350 ) — Distributions to noncontrolling interests ( 76 ) ( 66 ) Payment of common stock dividends ( 1,579 ) ( 1,494 ) Other financing activities ( 233 ) ( 150 ) Net cash provided from financing activities 3,828 2,467 Net Change in Cash, Cash Equivalents, and Restricted Cash 1,350 164 Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 1,640 1,101 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 2,990 $ 1,265 Supplemental Cash Flow Information: Cash paid during the period for — Interest (net of $ 100 and $ 61 capitalized for 2026 and 2025, respectively) $ 1,472 $ 1,287 Income taxes, net (excludes credit transfers) 146 199 Noncash transactions — Accrued property additions at end of period 1,409 1,091 Right-of-use assets obtained under operating leases 107 114 Right-of-use assets obtained under finance leases 5 14 Issuance of common stock under dividend reinvestment plan 109 112 The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements. 12 Table of Contents Index to Financial Statements THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) Assets At June 30, 2026 At December 31, 2025 (in millions) Current Assets: Cash and cash equivalents $ 2,984 $ 1,639 Receivables — Customer accounts 2,301 2,251 Unbilled revenues 938 931 Under recovered fuel clause revenues 227 316 Other accounts and notes 580 655 Accumulated provision for uncollectible accounts ( 98 ) ( 84 ) Materials and supplies 2,380 2,202 Fossil fuel for generation 728 735 Natural gas for sale 198 396 Prepaid expenses 370 327 Regulatory assets – asset retirement obligations 353 353 Other regulatory assets 916 709 Other current assets 501 487 Total current assets 12,378 10,917 Property, Plant, and Equipment: In service 151,437 146,114 Less: Accumulated depreciation 45,868 43,483 Plant in service, net of depreciation 105,569 102,631 Other utility plant, net — 307 Nuclear fuel, at amortized cost 902 897 Construction work in progress 11,874 10,534 Total property, plant, and equipment 118,345 114,369 Other Property and Investments: Goodwill 5,161 5,161 Nuclear decommissioning trusts, at fair value 3,110 2,947 Equity investments in unconsolidated subsidiaries 1,428 1,318 Other intangible assets, net of amortization of $ 457 and $ 444 , respectively 287 300 Miscellaneous property and investments 701 714 Total other property and investments 10,687 10,440 Deferred Charges and Other Assets: Operating lease right-of-use assets, net of amortization 1,369 1,358 Deferred charges related to income taxes 1,094 948 Prepaid pension costs 3,544 3,257 Unamortized loss on reacquired debt 179 187 Deferred under recovered fuel clause revenues 151 252 Regulatory assets – asset retirement obligations, deferred 5,042 5,129 Other regulatory assets, deferred 7,577 7,427 Other deferred charges and assets 1,661 1,436 Total deferred charges and other assets 20,617 19,994 Total Assets $ 162,027 $ 155,720 The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements. 13 Table of Contents Index to Financial Statements THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) Liabilities and Stockholders' Equity At June 30, 2026 At December 31, 2025 (in millions) Current Liabilities: Securities due within one year $ 4,694 $ 6,220 Notes payable 2,132 722 Accounts payable 3,374 3,710 Customer deposits 487 475 Accrued taxes — Accrued income taxes 70 22 Other accrued taxes 695 982 Accrued interest 812 807 Accrued compensation 927 1,418 Asset retirement obligations 658 662 Liabilities from risk management activities, net of collateral 151 118 Operating lease obligations 207 197 Natural gas cost over recovery 191 158 Other regulatory liabilities 190 240 Other current liabilities 1,146 1,157 Total current liabilities 15,734 16,888 Long-term Debt 68,756 65,649 Deferred Credits and Other Liabilities: Accumulated deferred income taxes 12,628 12,133 Deferred credits related to income taxes 4,611 4,712 Accumulated deferred ITCs 2,066 2,002 Employee benefit obligations 1,029 980 Operating lease obligations, deferred 1,298 1,287 Asset retirement obligations, deferred 8,917 8,939 Other cost of removal obligations 2,084 2,036 Other regulatory liabilities, deferred 712 722 Other deferred credits and liabilities 1,850 1,505 Total deferred credits and other liabilities 35,195 34,316 Total Liabilities 119,685 116,853 Total Stockholders' Equity (See accompanying statements) 42,342 38,867 Total Liabilities and Stockholders' Equity $ 162,027 $ 155,720 The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements. 14 Table of Contents Index to Financial Statements SOUTHERN COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (UNAUDITED) Southern Company Common Stockholders' Equity Number of Common Shares Common Stock Accumulated Other Comprehensive Income (Loss) Issued Treasury Par Value Paid-In Capital Treasury Retained Earnings Noncontrolling Interests Total (in millions) Balance at December 31, 2024 1,098 ( 1 ) $ 5,446 $ 14,149 $ ( 59 ) $ 13,750 $ ( 78 ) $ 3,466 $ 36,674 Consolidated net income (loss) — — — — — 1,334 — ( 64 ) 1,270 Other comprehensive income — — — — — — 3 — 3 Stock issued 2 — 7 78 — — — — 85 Stock-based compensation — — — 5 — — — — 5 Dividends of $ 0.72 per share — — — — — ( 791 ) — — ( 791 ) Capital contributions from noncontrolling interests — — — — — — — 19 19 Distributions to noncontrolling interests — — — — — — — ( 37 ) ( 37 ) Other — — — ( 1 ) ( 2 ) ( 2 ) — — ( 5 ) Balance at March 31, 2025 1,100 ( 1 ) $ 5,453 $ 14,231 $ ( 61 ) $ 14,291 $ ( 75 ) $ 3,384 $ 37,223 Consolidated net income (loss) — — — — — 880 — ( 27 ) 853 Other comprehensive income — — — — — — 4 — 4 Stock issued 1 — 5 84 — — — — 89 Stock-based compensation — — — 11 — — — — 11 Dividends of $ 0.74 per share — — — — — ( 815 ) — — ( 815 ) Capital contributions from noncontrolling interests — — — — — — — 4 4 Distributions to noncontrolling interests — — — — — — — ( 33 ) ( 33 ) Other — — — 6 ( 1 ) 1 — — 6 Balance at June 30, 2025 1,101 ( 1 ) $ 5,458 $ 14,332 $ ( 62 ) $ 14,357 $ ( 71 ) $ 3,328 $ 37,342 Balance at December 31, 2025 1,120 ( 1 ) $ 5,554 $ 15,740 $ ( 59 ) $ 14,856 $ ( 75 ) $ 2,851 $ 38,867 Consolidated net income (loss) — — — — — 1,356 — ( 18 ) 1,338 Other comprehensive income — — — — — — 2 — 2 Stock issued 8 — 34 555 — — — — 589 Stock-based compensation — — — ( 9 ) — — — — ( 9 ) Dividends of $ 0.74 per share — — — — — ( 830 ) — — ( 830 ) Capital contributions from noncontrolling interests — — — — — — — 4 4 Distributions to noncontrolling interests — — — — — — — ( 46 ) ( 46 ) Other — — — ( 1 ) ( 1 ) — — ( 1 ) ( 3 ) Balance at March 31, 2026 1,128 ( 1 ) $ 5,588 $ 16,285 $ ( 60 ) $ 15,382 $ ( 73 ) $ 2,790 $ 39,912 Consolidated net income — — — — — 1,174 — 14 1,188 Other comprehensive income (loss) — — — — — — ( 5 ) — ( 5 ) Change in par value from $ 5.00 to $ 0.01 — — ( 5,577 ) 5,577 — — — — — Stock issued 23 — — 2,116 — — — — 2,116 Stock-based compensation — — — 15 — — — — 15 Dividends of $ 0.76 per share — — — — — ( 858 ) — — ( 858 ) Distributions to noncontrolling interests — — — — — — — ( 32 ) ( 32 ) Other — — — 5 ( 1 ) 2 — — 6 Balance at June 30, 2026 1,151 ( 1 ) $ 11 $ 23,998 $ ( 61 ) $ 15,700 $ ( 78 ) $ 2,772 $ 42,342 The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements. 15 Table of Contents Index to Financial Statements ALABAMA POWER COMPANY CONDENSED STATEMENTS OF INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Operating Revenues: Retail revenues $ 1,710 $ 1,718 $ 3,438 $ 3,441 Wholesale revenues, non-affiliates 85 98 202 189 Wholesale revenues, affiliates 55 36 174 105 Other revenues 113 116 241 245 Total operating revenues 1,963 1,968 4,055 3,980 Operating Expenses: Fuel 336 337 764 723 Purchased power, non-affiliates 63 54 136 124 Purchased power, affiliates 53 67 126 121 Other operations and maintenance 415 472 808 935 Depreciation and amortization 385 371 766 741 Taxes other than income taxes 118 120 251 250 Total operating expenses 1,370 1,421 2,851 2,894 Operating Income 593 547 1,204 1,086 Other Income and (Expense): Allowance for equity funds used during construction 18 18 37 36 Interest expense, net of amounts capitalized ( 117 ) ( 116 ) ( 232 ) ( 225 ) Other income (expense), net 78 47 116 84 Total other income and (expense) ( 21 ) ( 51 ) ( 79 ) ( 105 ) Earnings Before Income Taxes 572 496 1,125 981 Income taxes 135 115 263 226 Net Income $ 437 $ 381 $ 862 $ 755 CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Net Income $ 437 $ 381 $ 862 $ 755 Other comprehensive income (loss): Qualifying hedges: Changes in fair value, net of tax of $ — , $ — , $ — , and $ — , respectively ( 2 ) — ( 2 ) — Reclassification adjustment for amounts included in net income, net of tax of $ — , $ — , $ — , and $ — , respectively — — — 1 Total other comprehensive income (loss) ( 2 ) — ( 2 ) 1 Comprehensive Income $ 435 $ 381 $ 860 $ 756 The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements. 16 Table of Contents Index to Financial Statements ALABAMA POWER COMPANY CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED) For the Six Months Ended June 30, 2026 2025 (in millions) Operating Activities: Net income $ 862 $ 755 Adjustments to reconcile net income to net cash provided from operating activities — Depreciation and amortization, total 867 803 Deferred income taxes 88 116 Pension, postretirement, and other employee benefits ( 115 ) ( 89 ) Settlement of asset retirement obligations ( 114 ) ( 120 ) Retail fuel cost under recovery – long-term ( 66 ) ( 62 ) Other, net ( 57 ) ( 44 ) Changes in certain current assets and liabilities — -Receivables ( 6 ) ( 94 ) -Prepayments ( 66 ) ( 89 ) -Other current assets ( 21 ) ( 8 ) -Accounts payable ( 277 ) ( 251 ) -Accrued taxes 72 25 -Accrued compensation ( 111 ) ( 93 ) -Customer refunds 2 ( 110 ) -Other current liabilities 20 ( 61 ) Net cash provided from operating activities 1,078 678 Investing Activities: Property additions ( 958 ) ( 1,065 ) Contributions in aid of construction 157 31 Nuclear decommissioning trust fund purchases ( 307 ) ( 270 ) Nuclear decommissioning trust fund sales 307 270 Cost of removal, net of salvage ( 95 ) ( 92 ) Other investing activities 18 ( 43 ) Net cash used for investing activities ( 878 ) ( 1,169 ) Financing Activities: Proceeds — Senior notes — 600 Other long-term debt — 4 Redemptions — Senior notes — ( 250 ) Other long-term debt ( 45 ) — Capital contributions from parent company 276 562 Payment of common stock dividends ( 601 ) ( 609 ) Other financing activities 6 ( 7 ) Net cash provided from (used for) financing activities ( 364 ) 300 Net Change in Cash, Cash Equivalents, and Restricted Cash ( 164 ) ( 191 ) Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 566 585 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 402 $ 394 Supplemental Cash Flow Information: Cash paid during the period for — Interest (net of $ 11 and $ 10 capitalized for 2026 and 2025, respectively) $ 229 $ 205 Income taxes, net 217 217 Noncash transactions — Accrued property additions at end of period 131 116 Right-of-use assets obtained under operating leases 11 7 Right-of-use assets obtained under finance leases 3 1 The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements. 17 Table of Contents Index to Financial Statements ALABAMA POWER COMPANY CONDENSED BALANCE SHEETS (UNAUDITED) Assets At June 30, 2026 At December 31, 2025 (in millions) Current Assets: Cash and cash equivalents $ 402 $ 566 Receivables — Customer accounts 587 470 Unbilled revenues 216 189 Affiliated 120 126 Other accounts and notes 84 113 Accumulated provision for uncollectible accounts ( 23 ) ( 23 ) Fossil fuel stock 294 303 Materials and supplies 746 732 Prepaid expenses 152 86 Other regulatory assets 372 344 Other current assets 84 80 Total current assets 3,034 2,986 Property, Plant, and Equipment: In service 40,731 38,915 Less: Accumulated provision for depreciation 14,001 12,816 Plant in service, net of depreciation 26,730 26,099 Other utility plant, net — 307 Nuclear fuel, at amortized cost 276 290 Construction work in progress 1,386 1,441 Total property, plant, and equipment 28,392 28,137 Other Property and Investments: Nuclear decommissioning trusts, at fair value 1,653 1,542 Equity investments in unconsolidated subsidiaries 53 48 Miscellaneous property and investments 123 123 Total other property and investments 1,829 1,713 Deferred Charges and Other Assets: Operating lease right-of-use assets, net of amortization 89 86 Deferred charges related to income taxes 263 261 Prepaid pension and other postretirement benefit costs 1,061 1,016 Regulatory assets – asset retirement obligations 1,454 1,518 Other regulatory assets, deferred 2,146 1,982 Other deferred charges and assets 411 425 Total deferred charges and other assets 5,424 5,288 Total Assets $ 38,679 $ 38,124 The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements. 18 Table of Contents Index to Financial Statements ALABAMA POWER COMPANY CONDENSED BALANCE SHEETS (UNAUDITED) Liabilities and Stockholder's Equity At June 30, 2026 At December 31, 2025 (in millions) Current Liabilities: Securities due within one year $ 303 $ 625 Accounts payable — Affiliated 263 294 Other 422 576 Customer deposits 115 113 Accrued taxes 187 105 Accrued interest 137 134 Accrued compensation 185 275 Asset retirement obligations 261 256 Other regulatory liabilities 58 89 Other current liabilities 148 135 Total current liabilities 2,079 2,602 Long-term Debt 11,670 11,388 Deferred Credits and Other Liabilities: Accumulated deferred income taxes 4,351 4,209 Deferred credits related to income taxes 1,535 1,585 Accumulated deferred ITCs 105 115 Employee benefit obligations 138 152 Operating lease obligations 80 78 Asset retirement obligations, deferred 3,387 3,423 Other regulatory liabilities, deferred 216 252 Other deferred credits and liabilities 587 326 Total deferred credits and other liabilities 10,399 10,140 Total Liabilities 24,148 24,130 Common Stockholder's Equity (See accompanying statements) 14,531 13,994 Total Liabilities and Stockholder's Equity $ 38,679 $ 38,124 The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements. 19 Table of Contents Index to Financial Statements ALABAMA POWER COMPANY CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (UNAUDITED) Number of Common Shares Issued Common Stock Paid-In Capital Retained Earnings Accumulated Other Comprehensive Income (Loss) Total (in millions) Balance at December 31, 2024 31 $ 1,222 $ 7,657 $ 4,214 $ ( 5 ) $ 13,088 Net income — — — 375 — 375 Capital contributions from parent company — — 527 — — 527 Other comprehensive income — — — — 1 1 Cash dividends on common stock — — — ( 305 ) — ( 305 ) Other — — — — ( 1 ) ( 1 ) Balance at March 31, 2025 31 $ 1,222 $ 8,184 $ 4,284 $ ( 5 ) $ 13,685 Net income — — — 381 — 381 Capital contributions from parent company — — 38 — — 38 Cash dividends on common stock — — — ( 304 ) — ( 304 ) Other — — — ( 1 ) 1 — Balance at June 30, 2025 31 $ 1,222 $ 8,222 $ 4,360 $ ( 4 ) $ 13,800 Balance at December 31, 2025 31 $ 1,222 $ 8,263 $ 4,512 $ ( 3 ) $ 13,994 Net income — — — 425 — 425 Capital contributions from parent company — — 226 — — 226 Cash dividends on common stock — — — ( 301 ) — ( 301 ) Balance at March 31, 2026 31 $ 1,222 $ 8,489 $ 4,636 $ ( 3 ) $ 14,344 Net income — — — 437 — 437 Capital contributions from parent company — — 53 — — 53 Other comprehensive income (loss) — — — — ( 2 ) ( 2 ) Cash dividends on common stock — — — ( 300 ) — ( 300 ) Other — — — ( 1 ) — ( 1 ) Balance at June 30, 2026 31 $ 1,222 $ 8,542 $ 4,772 $ ( 5 ) $ 14,531 The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements. 20 Table of Contents Index to Financial Statements GEORGIA POWER COMPANY CONDENSED STATEMENTS OF INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Operating Revenues: Retail revenues $ 2,753 $ 2,765 $ 5,391 $ 5,395 Wholesale revenues 120 107 347 250 Other revenues 260 238 538 503 Total operating revenues 3,133 3,110 6,276 6,148 Operating Expenses: Fuel 466 476 1,067 1,000 Purchased power, non-affiliates 171 180 329 340 Purchased power, affiliates 184 197 473 461 Other operations and maintenance 667 645 1,341 1,283 Depreciation and amortization 503 512 987 1,015 Taxes other than income taxes 138 173 313 342 Total operating expenses 2,129 2,183 4,510 4,441 Operating Income 1,004 927 1,766 1,707 Other Income and (Expense): Allowance for equity funds used during construction 104 56 201 104 Interest expense, net of amounts capitalized ( 228 ) ( 198 ) ( 431 ) ( 385 ) Other income (expense), net 50 58 108 112 Total other income and (expense) ( 74 ) ( 84 ) ( 122 ) ( 169 ) Earnings Before Income Taxes 930 843 1,644 1,538 Income taxes 151 236 236 334 Net Income $ 779 $ 607 $ 1,408 $ 1,204 CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Net Income $ 779 $ 607 $ 1,408 $ 1,204 Other comprehensive income: Qualifying hedges: Changes in fair value, net of tax of $ — , $ 1 , $ — , and $ 1 , respectively — 4 — 2 Reclassification adjustment for amounts included in net income, net of tax of $ — , $ — , $ — , and $ — , respectively — — — 1 Total other comprehensive income — 4 — 3 Comprehensive Income $ 779 $ 611 $ 1,408 $ 1,207 The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements. 21 Table of Contents Index to Financial Statements GEORGIA POWER COMPANY CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED) For the Six Months Ended June 30, 2026 2025 (in millions) Operating Activities: Net income $ 1,408 $ 1,204 Adjustments to reconcile net income to net cash provided from operating activities — Depreciation and amortization, total 1,128 1,167 Deferred income taxes 25 238 Allowance for equity funds used during construction ( 201 ) ( 104 ) Pension, postretirement, and other employee benefits ( 127 ) ( 128 ) Settlement of asset retirement obligations ( 147 ) ( 149 ) Storm damage cost recovery – long-term ( 139 ) ( 238 ) Other, net ( 23 ) ( 39 ) Changes in certain current assets and liabilities — -Receivables ( 210 ) ( 270 ) -Retail fuel cost under recovery 210 186 -Materials and supplies ( 132 ) 16 -Other current assets ( 36 ) ( 11 ) -Accounts payable 48 ( 396 ) -Accrued taxes ( 207 ) ( 196 ) -Other current liabilities ( 20 ) 55 Net cash provided from operating activities 1,577 1,335 Investing Activities: Property additions ( 4,233 ) ( 3,090 ) Contributions in aid of construction 141 99 Nuclear decommissioning trust fund purchases ( 687 ) ( 507 ) Nuclear decommissioning trust fund sales 687 507 Cost of removal, net of salvage ( 194 ) ( 152 ) Other investing activities ( 26 ) ( 75 ) Net cash used for investing activities ( 4,312 ) ( 3,218 ) Financing Activities: Increase in notes payable, net 70 285 Proceeds — Senior notes 1,300 1,600 Short-term borrowings 250 200 FFB loan 1,016 — Redemptions and repurchases — Senior notes ( 325 ) ( 700 ) Short-term borrowings ( 250 ) — FFB loan ( 43 ) ( 43 ) Other long-term debt ( 400 ) — Capital contributions from parent company 2,463 1,671 Payment of common stock dividends ( 1,287 ) ( 1,105 ) Other financing activities ( 46 ) ( 49 ) Net cash provided from financing activities 2,748 1,859 Net Change in Cash, Cash Equivalents, and Restricted Cash 13 ( 24 ) Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 59 118 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 72 $ 94 Supplemental Cash Flow Information: Cash paid during the period for — Interest (net of $ 61 and $ 33 capitalized for 2026 and 2025, respectively) $ 392 $ 341 Income taxes, net (excludes credit transfers) 118 25 Noncash transactions — Accrued property additions at end of period 1,050 699 Right-of-use assets obtained under operating leases 23 28 Right-of-use assets obtained under finance leases 1,400 13 The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements. 22 Table of Contents Index to Financial Statements GEORGIA POWER COMPANY CONDENSED BALANCE SHEETS (UNAUDITED) Assets At June 30, 2026 At December 31, 2025 (in millions) Current Assets: Cash and cash equivalents $ 72 $ 59 Receivables — Customer accounts, net 1,014 993 Unbilled revenues 577 346 Under recovered retail fuel clause revenues 161 310 Joint owner accounts 76 195 Affiliated 95 96 Other accounts and notes 127 61 Fossil fuel stock 364 362 Materials and supplies 1,130 994 Regulatory assets – asset retirement obligations 222 222 Other regulatory assets 500 335 Other current assets 288 285 Total current assets 4,626 4,258 Property, Plant, and Equipment: In service 63,226 59,458 Less: Accumulated provision for depreciation 16,442 15,957 Plant in service, net of depreciation 46,784 43,501 Nuclear fuel, at amortized cost 626 606 Construction work in progress 8,215 6,764 Total property, plant, and equipment 55,625 50,871 Other Property and Investments: Nuclear decommissioning trusts, at fair value 1,457 1,405 Equity investments in unconsolidated subsidiaries 39 40 Miscellaneous property and investments 229 231 Total other property and investments 1,725 1,676 Deferred Charges and Other Assets: Operating lease right-of-use assets, net of amortization 881 1,120 Deferred charges related to income taxes 805 660 Prepaid pension costs 1,180 1,099 Deferred under recovered retail fuel clause revenues 151 212 Regulatory assets – asset retirement obligations, deferred 3,360 3,382 Other regulatory assets, deferred 4,034 4,032 Other deferred charges and assets 984 767 Total deferred charges and other assets 11,395 11,272 Total Assets $ 73,371 $ 68,077 The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements. 23 Table of Contents Index to Financial Statements GEORGIA POWER COMPANY CONDENSED BALANCE SHEETS (UNAUDITED) Liabilities and Stockholder's Equity At June 30, 2026 At December 31, 2025 (in millions) Current Liabilities: Securities due within one year $ 1,548 $ 1,370 Notes payable 230 160 Accounts payable — Affiliated 904 992 Other 1,756 1,728 Customer deposits 277 267 Accrued taxes 471 678 Accrued interest 236 234 Accrued compensation 217 327 Operating lease obligations 132 170 Asset retirement obligations 350 360 Other regulatory liabilities 29 52 Other current liabilities 346 332 Total current liabilities 6,496 6,670 Long-term Debt 22,857 20,122 Deferred Credits and Other Liabilities: Accumulated deferred income taxes 4,902 4,811 Deferred credits related to income taxes 2,207 2,225 Accumulated deferred ITCs 461 354 Employee benefit obligations 192 189 Operating lease obligations, deferred 761 960 Asset retirement obligations, deferred 5,193 5,167 Other deferred credits and liabilities 682 545 Total deferred credits and other liabilities 14,398 14,251 Total Liabilities 43,751 41,043 Common Stockholder's Equity (See accompanying statements) 29,620 27,034 Total Liabilities and Stockholder's Equity $ 73,371 $ 68,077 The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements. 24 Table of Contents Index to Financial Statements GEORGIA POWER COMPANY CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (UNAUDITED) Number of Common Shares Issued Common Stock Paid-In Capital Retained Earnings Accumulated Other Comprehensive Income (Loss) Total (in millions) Balance at December 31, 2024 9 $ 398 $ 19,708 $ 3,562 $ 13 $ 23,681 Net income — — — 596 — 596 Capital contributions from parent company — — 702 — — 702 Other comprehensive income (loss) — — — — ( 1 ) ( 1 ) Cash dividends on common stock — — — ( 552 ) — ( 552 ) Balance at March 31, 2025 9 $ 398 $ 20,410 $ 3,606 $ 12 $ 24,426 Net income — — — 607 — 607 Capital contributions from parent company — — 972 — — 972 Other comprehensive income — — — — 4 4 Cash dividends on common stock — — — ( 553 ) — ( 553 ) Other — — — 1 — 1 Balance at June 30, 2025 9 $ 398 $ 21,382 $ 3,661 $ 16 $ 25,457 Balance at December 31, 2025 9 $ 398 $ 22,416 $ 4,204 $ 16 $ 27,034 Net income — — — 628 — 628 Capital contributions from parent company — — 1,500 — — 1,500 Cash dividends on common stock — — — ( 644 ) — ( 644 ) Other — — — 1 — 1 Balance at March 31, 2026 9 $ 398 $ 23,916 $ 4,189 $ 16 $ 28,519 Net income — — — 779 — 779 Capital contributions from parent company — — 965 — — 965 Cash dividends on common stock — — — ( 643 ) — ( 643 ) Balance at June 30, 2026 9 $ 398 $ 24,881 $ 4,325 $ 16 $ 29,620 The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements. 25 Table of Contents Index to Financial Statements MISSISSIPPI POWER COMPANY CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Operating Revenues: Retail revenues $ 283 $ 274 $ 556 $ 522 Wholesale revenues, non-affiliates 74 62 162 133 Wholesale revenues, affiliates 35 55 131 136 Other revenues 11 9 26 30 Total operating revenues 403 400 875 821 Operating Expenses: Fuel and purchased power 122 143 328 309 Other operations and maintenance 107 82 194 166 Depreciation and amortization 58 52 113 105 Taxes other than income taxes 36 36 72 69 Total operating expenses 323 313 707 649 Operating Income 80 87 168 172 Other Income and (Expense): Interest expense, net of amounts capitalized ( 21 ) ( 20 ) ( 41 ) ( 40 ) Other income (expense), net 9 9 19 16 Total other income and (expense) ( 12 ) ( 11 ) ( 22 ) ( 24 ) Earnings Before Income Taxes 68 76 146 148 Income taxes 16 17 34 34 Net Income and Comprehensive Income $ 52 $ 59 $ 112 $ 114 The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements. 26 Table of Contents Index to Financial Statements MISSISSIPPI POWER COMPANY CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED) For the Six Months Ended June 30, 2026 2025 (in millions) Operating Activities: Net income $ 112 $ 114 Adjustments to reconcile net income to net cash provided from operating activities — Depreciation and amortization, total 125 115 Deferred income taxes 14 4 Pension, postretirement, and other employee benefits ( 9 ) ( 8 ) Settlement of asset retirement obligations ( 12 ) ( 7 ) Other, net ( 3 ) ( 7 ) Changes in certain current assets and liabilities — -Receivables ( 11 ) ( 26 ) -Retail fuel cost under recovery ( 14 ) ( 28 ) -Fossil fuel stock — 20 -Other current assets ( 8 ) 8 -Accounts payable ( 23 ) ( 22 ) -Accrued taxes ( 57 ) ( 49 ) -Accrued compensation ( 21 ) ( 22 ) -Wholesale fuel cost over recovery — ( 15 ) -Other current liabilities — 1 Net cash provided from operating activities 93 78 Investing Activities: Property additions ( 185 ) ( 166 ) Contributions in aid of construction 4 57 Cost of removal, net of salvage ( 18 ) ( 17 ) Payments pursuant to LTSAs ( 11 ) ( 11 ) Other investing activities 1 ( 8 ) Net cash used for investing activities ( 209 ) ( 145 ) Financing Activities: Increase in notes payable, net 38 18 Proceeds — Senior notes 75 100 Capital contributions from parent company 97 57 Payment of common stock dividends ( 96 ) ( 97 ) Other financing activities ( 2 ) ( 2 ) Net cash provided from financing activities 112 76 Net Change in Cash, Cash Equivalents, and Restricted Cash ( 4 ) 9 Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 26 13 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 22 $ 22 Supplemental Cash Flow Information: Cash paid during the period for — Interest $ 40 $ 37 Income taxes, net 23 21 Noncash transactions — Accrued property additions at end of period 42 30 Right-of-use assets obtained under operating leases 3 — The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements. 27 Table of Contents Index to Financial Statements MISSISSIPPI POWER COMPANY CONDENSED BALANCE SHEETS (UNAUDITED) Assets At June 30, 2026 At December 31, 2025 (in millions) Current Assets: Cash and cash equivalents $ 22 $ 26 Receivables — Customer accounts, net 60 50 Unbilled revenues 48 44 Under recovered retail fuel clause revenues 55 — Affiliated 27 26 Other accounts and notes 18 22 Fossil fuel stock 46 46 Materials and supplies 102 101 Other regulatory assets 58 49 Other current assets 14 10 Total current assets 450 374 Property, Plant, and Equipment: In service 6,111 5,972 Less: Accumulated provision for depreciation 2,020 1,922 Plant in service, net of depreciation 4,091 4,050 Construction work in progress 223 238 Total property, plant, and equipment 4,314 4,288 Other Property and Investments 140 143 Deferred Charges and Other Assets: Deferred charges related to income taxes 24 25 Prepaid pension costs 162 151 Deferred under recovered retail fuel clause revenues — 40 Regulatory assets – asset retirement obligations 228 229 Other regulatory assets, deferred 259 255 Accumulated deferred income taxes 59 66 Other deferred charges and assets 81 66 Total deferred charges and other assets 813 832 Total Assets $ 5,717 $ 5,637 The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements. 28 Table of Contents Index to Financial Statements MISSISSIPPI POWER COMPANY CONDENSED BALANCE SHEETS (UNAUDITED) Liabilities and Stockholder's Equity At June 30, 2026 At December 31, 2025 (in millions) Current Liabilities: Securities due within one year $ 141 $ 66 Notes payable 38 — Accounts payable — Affiliated 72 70 Other 69 77 Accrued taxes 70 125 Accrued compensation 30 49 Asset retirement obligations 18 21 Other regulatory liabilities 24 20 Other current liabilities 97 92 Total current liabilities 559 520 Long-term Debt 1,720 1,720 Deferred Credits and Other Liabilities: Accumulated deferred income taxes 501 491 Deferred credits related to income taxes 192 211 Employee benefit obligations 66 67 Asset retirement obligations, deferred 97 103 Other cost of removal obligations 103 115 Other regulatory liabilities, deferred 137 141 Other deferred credits and liabilities 40 80 Total deferred credits and other liabilities 1,136 1,208 Total Liabilities 3,415 3,448 Common Stockholder's Equity (See accompanying statements) 2,302 2,189 Total Liabilities and Stockholder's Equity $ 5,717 $ 5,637 The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements. 29 Table of Contents Index to Financial Statements MISSISSIPPI POWER COMPANY CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (UNAUDITED) Number of Common Shares Issued Common Stock Paid-In Capital Retained Earnings (Accumulated Deficit) Accumulated Other Comprehensive Income (Loss) Total (in millions) Balance at December 31, 2024 1 $ 38 $ 4,791 $ ( 2,745 ) $ 5 $ 2,089 Net income — — — 55 — 55 Capital contributions from parent company — — 51 — — 51 Cash dividends on common stock — — — ( 48 ) — ( 48 ) Other — — — — ( 1 ) ( 1 ) Balance at March 31, 2025 1 $ 38 $ 4,842 $ ( 2,738 ) $ 4 $ 2,146 Net income — — — 59 — 59 Capital contributions from parent company — — 7 — — 7 Cash dividends on common stock — — — ( 49 ) — ( 49 ) Other — — — 1 — 1 Balance at June 30, 2025 1 $ 38 $ 4,849 $ ( 2,727 ) $ 4 $ 2,164 Balance at December 31, 2025 1 $ 38 $ 4,871 $ ( 2,724 ) $ 4 $ 2,189 Net income — — — 60 — 60 Capital contributions from parent company — — 90 — — 90 Cash dividends on common stock — — — ( 48 ) — ( 48 ) Balance at March 31, 2026 1 $ 38 $ 4,961 $ ( 2,712 ) $ 4 $ 2,291 Net income — — — 52 — 52 Capital contributions from parent company — — 7 — — 7 Cash dividends on common stock — — — ( 48 ) — ( 48 ) Balance at June 30, 2026 1 $ 38 $ 4,968 $ ( 2,708 ) $ 4 $ 2,302 The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements. 30 Table of Contents Index to Financial Statements SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF INCOME (LOSS) (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Operating Revenues: Wholesale revenues, non-affiliates $ 439 $ 424 $ 1,016 $ 870 Wholesale revenues, affiliates 92 114 192 229 Other revenues 4 8 8 14 Total operating revenues 535 546 1,216 1,113 Operating Expenses: Fuel 129 147 383 355 Purchased power 36 31 94 59 Other operations and maintenance 139 135 278 257 Depreciation and amortization 280 177 558 329 Taxes other than income taxes 13 13 25 25 Total operating expenses 597 503 1,338 1,025 Operating Income (Loss) ( 62 ) 43 ( 122 ) 88 Other Income and (Expense): Interest expense, net of amounts capitalized ( 28 ) ( 24 ) ( 55 ) ( 50 ) Other income (expense), net 2 3 4 6 Total other income and (expense) ( 26 ) ( 21 ) ( 51 ) ( 44 ) Earnings (Loss) Before Income Taxes ( 88 ) 22 ( 173 ) 44 Income taxes (benefit) ( 77 ) ( 2 ) ( 147 ) ( 3 ) Net Income (Loss) ( 11 ) 24 ( 26 ) 47 Net income (loss) attributable to noncontrolling interests 14 ( 27 ) ( 4 ) ( 91 ) Net Income (Loss) Attributable to Southern Power $ ( 25 ) $ 51 $ ( 22 ) $ 138 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Net Income (Loss) $ ( 11 ) $ 24 $ ( 26 ) $ 47 Other comprehensive income (loss): Qualifying hedges: Changes in fair value, net of tax of $( 2 ), $ 11 , $( 5 ), and $ 17 , respectively ( 7 ) 35 ( 14 ) 52 Reclassification adjustment for amounts included in net income, net of tax of $ 1 , $( 10 ), $ 4 . and $( 15 ), respectively 4 ( 33 ) 13 ( 48 ) Total other comprehensive income (loss) ( 3 ) 2 ( 1 ) 4 Comprehensive Income (Loss) ( 14 ) 26 ( 27 ) 51 Comprehensive income (loss) attributable to noncontrolling interests 14 ( 27 ) ( 4 ) ( 91 ) Comprehensive Income (Loss) Attributable to Southern Power $ ( 28 ) $ 53 $ ( 23 ) $ 142 The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements. 31 Table of Contents Index to Financial Statements SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) For the Six Months Ended June 30, 2026 2025 (in millions) Operating Activities: Net income (loss) $ ( 26 ) $ 47 Adjustments to reconcile net income (loss) to net cash provided from operating activities — Depreciation and amortization, total 568 340 Deferred income taxes ( 75 ) ( 2 ) Utilization of federal tax credit carryforward 130 — Amortization of ITCs ( 29 ) ( 29 ) Loss on damaged equipment 22 — Other, net ( 9 ) ( 18 ) Changes in certain current assets and liabilities — -Receivables ( 47 ) ( 69 ) -Income taxes receivable ( 39 ) ( 2 ) -Other current assets ( 24 ) 2 -Accounts payable ( 19 ) ( 20 ) -Accrued compensation ( 11 ) ( 11 ) -Other current liabilities 8 ( 6 ) Net cash provided from operating activities 449 232 Investing Activities: Property additions ( 399 ) ( 392 ) Payments pursuant to LTSAs ( 28 ) ( 26 ) Other investing activities 10 — Net cash used for investing activities ( 417 ) ( 418 ) Financing Activities: Increase (decrease) in notes payable, net ( 135 ) 201 Proceeds — Senior notes 600 — Redemptions — Senior notes ( 564 ) — Capital contributions from parent company 465 146 Capital contributions from noncontrolling interests 4 23 Distributions to noncontrolling interests ( 76 ) ( 66 ) Payment of common stock dividends ( 143 ) ( 139 ) Other financing activities ( 10 ) ( 4 ) Net cash provided from financing activities 141 161 Net Change in Cash, Cash Equivalents, and Restricted Cash 173 ( 25 ) Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 105 168 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 278 $ 143 Supplemental Cash Flow Information: Cash paid (received) during the period for — Interest (net of $ 21 and $ 8 capitalized for 2026 and 2025, respectively) $ 61 $ 59 Income taxes, net (excludes credit transfers) ( 61 ) 52 Noncash transactions — Accrued property additions at end of period 66 60 Right-of-use assets obtained under operating leases — 2 The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements. 32 Table of Contents Index to Financial Statements SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) Assets At June 30, 2026 At December 31, 2025 (in millions) Current Assets: Cash and cash equivalents $ 278 $ 105 Receivables — Customer accounts, net 193 151 Affiliated 42 35 Other 52 16 Materials and supplies 136 132 Prepaid income taxes 52 8 Other current assets 61 81 Total current assets 814 528 Property, Plant, and Equipment: In service 15,339 15,034 Less: Accumulated provision for depreciation 5,564 5,214 Plant in service, net of depreciation 9,775 9,820 Construction work in progress 944 1,080 Total property, plant, and equipment 10,719 10,900 Other Property and Investments: Intangible assets, net of amortization of $ 198 and $ 188 , respectively 194 203 Net investment in sales-type leases 133 137 Total other property and investments 327 340 Deferred Charges and Other Assets: Operating lease right-of-use assets, net of amortization 474 479 Prepaid LTSAs 198 170 Other deferred charges and assets 248 240 Total deferred charges and other assets 920 889 Total Assets $ 12,780 $ 12,657 The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements. 33 Table of Contents Index to Financial Statements SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) Liabilities and Stockholders' Equity At June 30, 2026 At December 31, 2025 (in millions) Current Liabilities: Securities due within one year $ — $ 587 Notes payable — 138 Accounts payable — Affiliated 76 88 Other 101 93 Accrued taxes 21 9 Accrued interest 32 38 Operating lease obligations 31 31 Other current liabilities 75 92 Total current liabilities 336 1,076 Long-term Debt 2,950 2,353 Deferred Credits and Other Liabilities: Accumulated deferred income taxes 655 579 Accumulated deferred ITCs 1,354 1,383 Operating lease obligations, deferred 505 510 Other deferred credits and liabilities 238 235 Total deferred credits and other liabilities 2,752 2,707 Total Liabilities 6,038 6,136 Total Stockholders' Equity (See accompanying statements) 6,742 6,521 Total Liabilities and Stockholders' Equity $ 12,780 $ 12,657 The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements. 34 Table of Contents Index to Financial Statements SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (UNAUDITED) Paid-In Capital Retained Earnings Accumulated Other Comprehensive Income (Loss) Total Common Stockholder's Equity Noncontrolling Interests Total (in millions) Balance at December 31, 2024 $ 1,306 $ 1,912 $ ( 2 ) $ 3,216 $ 3,466 $ 6,682 Net income (loss) — 87 — 87 ( 64 ) 23 Capital contributions from parent company 130 — — 130 — 130 Other comprehensive income — — 2 2 — 2 Cash dividends on common stock — ( 70 ) — ( 70 ) — ( 70 ) Capital contributions from noncontrolling interests — — — — 19 19 Distributions to noncontrolling interests — — — — ( 37 ) ( 37 ) Balance at March 31, 2025 $ 1,436 $ 1,929 $ — $ 3,365 $ 3,384 $ 6,749 Net income (loss) — 51 — 51 ( 27 ) 24 Capital contributions from parent company 16 — — 16 — 16 Other comprehensive income — — 2 2 — 2 Cash dividends on common stock — ( 69 ) — ( 69 ) — ( 69 ) Capital contributions from noncontrolling interests — — — — 4 4 Distributions to noncontrolling interests — — — — ( 33 ) ( 33 ) Other — ( 1 ) — ( 1 ) — ( 1 ) Balance at June 30, 2025 $ 1,452 $ 1,910 $ 2 $ 3,364 $ 3,328 $ 6,692 Balance at December 31, 2025 $ 1,912 $ 1,758 $ — $ 3,670 $ 2,851 $ 6,521 Net income (loss) — 4 — 4 ( 18 ) ( 14 ) Other comprehensive income — — 2 2 — 2 Cash dividends on common stock — ( 72 ) — ( 72 ) — ( 72 ) Capital contributions from noncontrolling interests — — — — 4 4 Distributions to noncontrolling interests — — — — ( 46 ) ( 46 ) Other ( 1 ) 1 — — ( 1 ) ( 1 ) Balance at March 31, 2026 $ 1,911 $ 1,691 $ 2 $ 3,604 $ 2,790 $ 6,394 Net income (loss) — ( 25 ) — ( 25 ) 14 ( 11 ) Capital contributions from parent company 465 — — 465 — 465 Other comprehensive income (loss) — — ( 3 ) ( 3 ) — ( 3 ) Cash dividends on common stock — ( 71 ) — ( 71 ) — ( 71 ) Distributions to noncontrolling interests — — — — ( 32 ) ( 32 ) Other 1 ( 1 ) — — — — Balance at June 30, 2026 $ 2,377 $ 1,594 $ ( 1 ) $ 3,970 $ 2,772 $ 6,742 The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements. 35 Table of Contents Index to Financial Statements SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Operating Revenues: Natural gas revenues (includes revenue taxes of $ 25 , $ 27 , $ 95 , and $ 90 , respectively) $ 966 $ 979 $ 3,157 $ 2,818 Total operating revenues 966 979 3,157 2,818 Operating Expenses: Cost of natural gas 177 255 1,103 929 Other operations and maintenance 341 301 683 617 Depreciation and amortization 185 172 369 341 Taxes other than income taxes 61 61 166 158 Total operating expenses 764 789 2,321 2,045 Operating Income 202 190 836 773 Other Income and (Expense): Earnings from equity method investments 32 23 78 62 Interest expense, net of amounts capitalized ( 101 ) ( 92 ) ( 206 ) ( 183 ) Other income (expense), net 25 18 41 34 Total other income and (expense) ( 44 ) ( 51 ) ( 87 ) ( 87 ) Earnings Before Income Taxes 158 139 749 686 Income taxes 32 33 176 162 Net Income $ 126 $ 106 $ 573 $ 524 CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED) For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (in millions) (in millions) Net Income $ 126 $ 106 $ 573 $ 524 Other comprehensive income (loss): Qualifying hedges: Changes in fair value, net of tax of $( 1 ), $( 2 ), $ 1 , and $ 2 , respectively ( 3 ) ( 6 ) 2 6 Reclassification adjustment for amounts included in net income, net of tax of $ 1 , $ — , $( 2 ), and $ — , respectively 2 ( 1 ) ( 4 ) — Pension and other postretirement benefit plans: Reclassification adjustment for amounts included in net income, net of tax of $ — , $ — , $ — , and $ — , respectively — — ( 1 ) ( 1 ) Total other comprehensive income (loss) ( 1 ) ( 7 ) ( 3 ) 5 Comprehensive Income $ 125 $ 99 $ 570 $ 529 The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements. 36 Table of Contents Index to Financial Statements SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) For the Six Months Ended June 30, 2026 2025 (in millions) Operating Activities: Net income $ 573 $ 524 Adjustments to reconcile net income to net cash provided from operating activities — Depreciation and amortization, total 366 338 Deferred income taxes 89 67 Other, net 40 26 Changes in certain current assets and liabilities — -Receivables 427 209 -Natural gas for sale, net of temporary LIFO liquidation 197 233 -Other current assets ( 12 ) 37 -Accounts payable ( 152 ) ( 105 ) -Accrued compensation ( 39 ) ( 44 ) -Natural gas cost over recovery 34 ( 87 ) -Other current liabilities ( 15 ) 12 Net cash provided from operating activities 1,508 1,210 Investing Activities: Property additions ( 799 ) ( 704 ) Contributions in aid of construction 11 27 Cost of removal, net of salvage ( 39 ) ( 42 ) Change in construction payables, net 26 15 Capital contributions to unconsolidated subsidiaries ( 93 ) ( 31 ) Other investing activities 5 — Net cash used for investing activities ( 889 ) ( 735 ) Financing Activities: Increase (decrease) in notes payable, net ( 190 ) 16 Proceeds — Other long-term debt 500 — Redemptions — Senior notes ( 350 ) — First mortgage bonds ( 100 ) — Return of capital to parent company — ( 23 ) Capital contributions from parent company 22 22 Payment of common stock dividends ( 281 ) ( 297 ) Other financing activities ( 17 ) ( 12 ) Net cash used for financing activities ( 416 ) ( 294 ) Net Change in Cash, Cash Equivalents, and Restricted Cash 203 181 Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 15 44 Cash, Cash Equivalents, and Restricted Cash at End of Period $ 218 $ 225 Supplemental Cash Flow Information: Cash paid during the period for — Interest (net of $ 7 and $ 9 capitalized for 2026 and 2025, respectively) $ 201 $ 185 Income taxes, net 55 66 Noncash transactions — Accrued property additions at end of period 138 101 Right-of-use assets obtained under operating leases 1 60 Return of capital to parent company — 33 The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements. 37 Table of Contents Index to Financial Statements SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) Assets At June 30, 2026 At December 31, 2025 (in millions) Current Assets: Cash and cash equivalents $ 214 $ 15 Receivables — Customer accounts 326 490 Unbilled revenues 85 341 Other accounts and notes 61 57 Accumulated provision for uncollectible accounts ( 65 ) ( 50 ) Materials and supplies 61 62 Natural gas for sale 198 396 Prepaid expenses 35 26 Other regulatory assets 117 114 Other current assets 49 66 Total current assets 1,081 1,517 Property, Plant, and Equipment: In service 24,726 24,098 Less: Accumulated depreciation 6,489 6,273 Plant in service, net of depreciation 18,237 17,825 Construction work in progress 969 863 Total property, plant, and equipment 19,206 18,688 Other Property and Investments: Goodwill 5,015 5,015 Equity investments in unconsolidated subsidiaries 1,254 1,182 Other intangible assets, net of amortization of $ 181 and $ 179 , respectively 1 3 Miscellaneous property and investments 25 24 Total other property and investments 6,295 6,224 Deferred Charges and Other Assets: Operating lease right-of-use assets, net of amortization 80 85 Prepaid pension and other postretirement benefit costs 301 229 Other regulatory assets, deferred 508 517 Other deferred charges and assets 133 127 Total deferred charges and other assets 1,022 958 Total Assets $ 27,604 $ 27,387 The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements. 38 Table of Contents Index to Financial Statements SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) Liabilities and Stockholder's Equity At June 30, 2026 At December 31, 2025 (in millions) Current Liabilities: Securities due within one year $ 80 $ 531 Notes payable 235 425 Accounts payable — Affiliated 75 70 Other 439 553 Customer deposits 75 75 Accrued taxes 111 107 Accrued interest 102 100 Accrued compensation 98 137 Natural gas cost over recovery 191 158 Other regulatory liabilities 36 36 Other current liabilities 96 110 Total current liabilities 1,538 2,302 Long-term Debt 9,224 8,743 Deferred Credits and Other Liabilities: Accumulated deferred income taxes 2,059 1,971 Deferred credits related to income taxes 667 681 Employee benefit obligations 135 78 Operating lease obligations 120 123 Other cost of removal obligations 1,981 1,921 Accrued environmental remediation 201 207 Other deferred credits and liabilities 238 234 Total deferred credits and other liabilities 5,401 5,215 Total Liabilities 16,163 16,260 Common Stockholder's Equity (See accompanying statements) 11,441 11,127 Total Liabilities and Stockholder's Equity $ 27,604 $ 27,387 The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements. 39 Table of Contents Index to Financial Statements SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDER'S EQUITY (UNAUDITED) Paid-In Capital Retained Earnings Accumulated Other Comprehensive Income (Loss) Total (in millions) Balance at December 31, 2024 $ 10,863 $ 85 $ 48 $ 10,996 Net income — 418 — 418 Return of capital to parent company ( 56 ) — — ( 56 ) Capital contributions from parent company 3 — — 3 Other comprehensive income — — 12 12 Cash dividends on common stock — ( 149 ) — ( 149 ) Other — 1 — 1 Balance at March 31, 2025 $ 10,810 $ 355 $ 60 $ 11,225 Net income — 106 — 106 Capital contributions from parent company 23 — — 23 Other comprehensive income (loss) — — ( 7 ) ( 7 ) Cash dividends on common stock — ( 148 ) — ( 148 ) Other — ( 1 ) — ( 1 ) Balance at June 30, 2025 $ 10,833 $ 312 $ 53 $ 11,198 Balance at December 31, 2025 $ 10,854 $ 222 $ 51 $ 11,127 Net income — 447 — 447 Capital contributions from parent company 1 — — 1 Other comprehensive income (loss) — — ( 2 ) ( 2 ) Cash dividends on common stock — ( 141 ) — ( 141 ) Other — 1 — 1 Balance at March 31, 2026 $ 10,855 $ 529 $ 49 $ 11,433 Net income — 126 — 126 Capital contributions from parent company 24 — — 24 Other comprehensive income (loss) — — ( 1 ) ( 1 ) Cash dividends on common stock — ( 140 ) — ( 140 ) Other — ( 1 ) — ( 1 ) Balance at June 30, 2026 $ 10,879 $ 514 $ 48 $ 11,441 The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements. 40 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS FOR THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES ALABAMA POWER COMPANY GEORGIA POWER COMPANY MISSISSIPPI POWER COMPANY SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES (UNAUDITED) INDEX TO THE NOTES TO THE CONDENSED FINANCIAL STATEMENTS Note Page A Introduction 42 B Regulatory Matters 45 C Contingencies 49 D Revenue from Contracts with Customers and Lease Income 51 E Consolidated Entities and Equity Method Investments 58 F Financin g and Leases 59 G Income Taxes 64 H Retirement Benefits 65 I Fair Value Measurements 68 J Derivatives 72 K Acquisitions and Dispositions 81 L Segment and Related Information 83 INDEX TO APPLICABLE NOTES TO FINANCIAL STATEMENTS BY REGISTRANT The following unaudited notes to the condensed financial statements are a combined presentation; however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants. The table below indicates the Registrants to which each note applies. Applicable Notes Registrant A B C D E F G H I J K L Southern Company l l l l l l l l l l l l Alabama Power l l l l l l l l l l Georgia Power l l l l l l l l l l Mississippi Power l l l l l l l l l l Southern Power l l l l l l l l l l l Southern Company Gas l l l l l l l l l l l 41 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (A) INTRODUCTION The condensed quarterly financial statements of each Registrant included herein have been prepared by such Registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets at December 31, 2025 have been derived from the audited financial statements of each Registrant. In the opinion of each Registrant's management, the information regarding such Registrant furnished herein reflects all adjustments, which, except as otherwise disclosed, are of a normal recurring nature, necessary to present fairly the results of operations for the periods ended June 30, 2026 and 2025. Certain information and disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations, although each Registrant believes that the disclosures regarding such Registrant are adequate to make the information presented not misleading. Disclosures which would substantially duplicate the disclosures in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are generally omitted from this Quarterly Report on Form 10-Q unless specifically required by GAAP. Therefore, these Condensed Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Due to the seasonal variations in the demand for energy and other factors, operating results for the periods presented are not necessarily indicative of the operating results to be expected for the full year. The preparation of financial statements in conformity with GAAP requires the use of estimates, and the actual results may differ from those estimates. Certain prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the overall results of operations, financial position, or cash flows of any Registrant. Goodwill and Other Intangible Assets Goodwill at both June 30, 2026 and December 31, 2025 was as follows: Goodwill (in millions) Southern Company $ 5,161 Southern Company Gas: Gas distribution operations $ 4,034 Gas marketing services 981 Southern Company Gas total $ 5,015 Goodwill is not amortized but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if goodwill impairment indicators exist. 42 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Other intangible assets were as follows: At June 30, 2026 At December 31, 2025 Gross Carrying Amount Accumulated Amortization Other Intangible Assets, Net Gross Carrying Amount Accumulated Amortization Other Intangible Assets, Net (in millions) (in millions) Southern Company Subject to amortization: Customer relationships $ 212 $ ( 192 ) $ 20 $ 212 $ ( 189 ) $ 23 Trade names 64 ( 64 ) — 64 ( 64 ) — PPA fair value adjustments 390 ( 198 ) 192 390 ( 188 ) 202 Other 3 ( 3 ) — 3 ( 3 ) — Total subject to amortization $ 669 $ ( 457 ) $ 212 $ 669 $ ( 444 ) $ 225 Not subject to amortization: FCC licenses 75 — 75 75 — 75 Total other intangible assets $ 744 $ ( 457 ) $ 287 $ 744 $ ( 444 ) $ 300 Southern Power (*) PPA fair value adjustments $ 390 $ ( 198 ) $ 192 $ 390 $ ( 188 ) $ 202 Southern Company Gas (*) Gas marketing services Customer relationships $ 156 $ ( 155 ) $ 1 $ 156 $ ( 153 ) $ 3 Trade names 26 ( 26 ) — 26 ( 26 ) — Total other intangible assets $ 182 $ ( 181 ) $ 1 $ 182 $ ( 179 ) $ 3 (*) All subject to amortization. Amortization associated with other intangible assets was as follows: Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 (in millions) Southern Company (a) $ 7 $ 8 $ 13 $ 16 Southern Power (b) 5 5 10 10 Southern Company Gas Gas marketing services 1 1 2 3 (a) Includes $ 5 million for the three months ended June 30, 2026 and 2025 and $ 10 million for the six months ended June 30, 2026 and 2025 recorded as a reduction to operating revenues. (b) Recorded as a reduction to operating revenues. 43 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Cash, Cash Equivalents, and Restricted Cash The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants: Southern Company Southern Company Gas (in millions) At June 30, 2026 Cash and cash equivalents $ 2,984 $ 214 Restricted cash (a) : Other current assets 5 4 Total cash, cash equivalents, and restricted cash (b) $ 2,990 $ 218 At December 31, 2025 Cash and cash equivalents $ 1,639 $ 15 Restricted cash (a) : Other current assets 1 — Total cash, cash equivalents, and restricted cash (b) $ 1,640 $ 15 (a) For Southern Company Gas, reflects funds held to support letters of credit. For Southern Company, also reflects collateral of $ 1 million for life insurance and long-term disability insurance, which was included at Southern Holdings. (b) Total may not add due to rounding. Natural Gas for Sale With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a weighted average cost basis. For any declines in market prices below the weighted average cost considered to be non-temporary, an adjustment is recorded to reduce the value of natural gas inventories to market value. Nicor Gas' natural gas inventory is carried at cost on a LIFO basis. Inventory decrements occurring during the year that are restored prior to year-end are charged to cost of natural gas at the estimated annual replacement cost. Inventory decrements that are not restored prior to year-end are charged to cost of natural gas at the actual LIFO cost of the inventory layers liquidated. Southern Company Gas recorded no material adjustments to natural gas inventories for either period presented. Nicor Gas' inventory decrements that occurred during the year have been restored as of June 30, 2026. Asset Retirement Obligations See BUSINESS – "Regulation – Federal Power Act" in Item 1 and Note 6 to the financial statements in Item 8 of the Form 10-K for additional information. On April 16, 2026, the FERC issued a surrender order for Georgia Power's Langdale and Riverview hydroelectric projects, which includes dam removal obligations and other post-dam removal activities. As a result, in June 2026, Georgia Power recorded AROs of $ 46 million. 44 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) (B) REGULATORY MATTERS See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information relating to regulatory matters. The recovery balances for retail fuel and storm/property damage for the traditional electric operating companies and natural gas cost for Southern Company Gas at June 30, 2026 and December 31, 2025 were as follows: Recovery/Regulatory Clause Balance Sheet Location At June 30, 2026 At December 31, 2025 (in millions) Alabama Power Rate ECR Other regulatory assets, current $ 7 $ — Other regulatory assets, deferred 212 146 NDR Other regulatory liabilities, deferred 29 60 Georgia Power Fuel cost recovery Receivables – under recovered retail fuel clause revenues $ 161 $ 310 Deferred under recovered retail fuel clause revenues 151 212 Storm damage recovery Other regulatory assets, current 187 31 Other regulatory assets, deferred 784 880 Mississippi Power Fuel cost recovery (*) Receivables – under recovered retail fuel clause revenues $ 55 $ — Deferred under recovered retail fuel clause revenues — 40 Property damage reserve Other regulatory liabilities, deferred 56 57 Southern Company Gas Natural gas cost recovery Natural gas cost over recovery $ 191 $ 158 (*) Mississippi Power also has wholesale MRA and Market Based (MB) fuel cost recovery factors. At June 30, 2026 and December 31, 2025, wholesale MRA fuel cost under recovery was $ 10 million and $ 6 million, respectively, and was included in customer accounts receivable, net on Mississippi Power's balance sheets. The wholesale MB fuel cost recovery was immaterial for both periods presented. Alabama Power Power to the People Act In December 2025, the Alabama PSC issued a consent order to keep retail rates stable through 2027. On April 2, 2026, the State of Alabama enacted legislation providing that retail base rates established and in place on October 1, 2026 may not be increased before January 1, 2029 for utilities that are regulated by the Alabama PSC and that provide retail electric service. The ultimate outcome of this matter cannot be determined at this time. Reliability Reserve Accounting Order In accordance with the notification provided to the Alabama PSC through its annual Rate RSE filing indicating plans to use $ 60 million of the reliability reserve, Alabama Power utilized $ 40 million of its reliability reserve during the first six months of 2026 for reliability-related transmission, distribution, and generation expenses. At June 30, 2026, Alabama Power's reliability reserve balance was $ 144 million. Environmental Accounting Order As a result of the planned conversion of Plant Barry Unit 5 from coal to natural gas, the unit's net book value no longer meets the criteria to be considered probable of abandonment, and, in the first quarter 2026, approximately $ 307 million was reclassified from other utility plant, net to plant in service on Alabama Power's and Southern Company's balance sheets. 45 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Georgia Power Integrated Resource Plans Certification Requests On March 25, 2026, Georgia Interfaith Power & Light, Park Avenue Baptist Church, Unitarian Universalist Church of Savannah, Sierra Club, Adrien Webber, and Southern Alliance for Clean Energy filed a petition with the Fulton County Superior Court appealing the Georgia PSC's December 19, 2025 approval of Georgia Power's request for certification of resources totaling 9,885 MWs (2025 All-Source Certification). The petition requests a reversal of the 2025 All-Source Certification, including a decertification of at least 757 MWs of resources. Georgia Power intervened in the proceeding, and both the Georgia PSC and Georgia Power filed motions to dismiss on April 24, 2026 and June 23, 2026, respectively. Georgia Power believes the appeal has no merit; however, the ultimate outcome of this matter cannot be determined at this time. On June 2, 2026, the FERC approved two affiliate PPAs with Southern Power procured under the 2022 IRP. These affiliate PPAs began in June 2026 with capacities of 638 MWs and 74 MWs. See Note (F) under "Georgia Power Lease Modification" for additional information. 2025 IRP Pursuant to the final order for Georgia Power's 2025 IRP, on June 9, 2026, Georgia Power initiated a request for proposals for 2,000 MWs to 6,000 MWs of capacity resources with projected CODs or delivery commencement dates in 2032 and 2033. Fuel Cost Recovery On each of March 13, 2026, April 15, 2026, and May 14, 2026, Georgia Power filed an Interim Fuel Rider (IFR) notification and plan informing the Georgia PSC that Georgia Power's under recovered fuel balance accumulated since May 31, 2023 exceeded $ 200 million, as established in a Georgia PSC stipulation approved in 2023, as of February 28, 2026, March 31, 2026, and April 30, 2026, respectively. Georgia Power did not propose a fuel cost recovery rate change pursuant to these IFR notifications and plans. On May 28, 2026, the Georgia PSC approved a stipulation among Georgia Power, the staff of the Georgia PSC, and certain intervenors to decrease annual fuel billings by 12.9 %, or approximately $ 394 million, effective June 1, 2026. Under the approved stipulation, Georgia Power is required to file for an adjustment to its fuel cost recovery rates under an IFR prior to the next fuel case, subject to a maximum 40 % cumulative change, if its under or over recovered fuel balance accumulated since May 31, 2026 exceeds $ 300 million. Within 30 days of the filing, the Georgia PSC will approve, modify, or reject any proposed fuel cost recovery rate adjustment. Georgia Power is scheduled to file its next fuel case no later than February 28, 2029. Changes in fuel rates have no significant effect on Georgia Power's net income but impact the related operating cash flows. Storm Damage Recovery On May 28, 2026, the Georgia PSC approved a stipulation among Georgia Power, the staff of the Georgia PSC, and certain intervenors regarding Georgia Power's recovery of storm restoration costs. Under the stipulation, the Georgia PSC approved the following: • Recovery of $ 31 million annually for storm restoration costs incurred after December 31, 2025. • Recovery of Georgia Power's adjusted regulatory asset balance totaling $ 869 million, as determined through the proceedings and stipulation, related to storm damage as of December 31, 2025 over a period of 67 months from June 1, 2026 through December 31, 2031, or $ 156 million annually. Additionally, the stipulation provided for the treatment of the Internal Revenue Code §45U PTCs generated from Georgia Power's nuclear generating facilities in 2024 and 2025, in which Georgia Power agreed to use $ 77 million of these tax credits for the benefit of customers. 46 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Construction At June 30, 2026, Georgia Power had recorded approximately $ 4.4 billion of combined capital costs, excluding AFUDC, for the projects reflected in the table below approved by the Georgia PSC through the 2023 IRP Update and certification requests in September and December 2025 authorized through its 2022 IRP. The total certified amounts related to these projects are approximately $ 19.5 billion, excluding AFUDC. The ultimate outcome of these matters cannot be determined at this time. Resource/Project Approximate Nameplate Capacity (MW) Actual/Projected COD Projects Under Construction at June 30, 2026 Battery Energy Storage McGrau Ford Phase 2 265 Third quarter 2026 McGrau Ford Phase 1 265 Fourth quarter 2026 Hammond Phase 1 58 Fourth quarter 2026 Hammond Phase 2 193 Fourth quarter 2030 Twiggs County 200 Fourth quarter 2027 Wadley 260 Fourth quarter 2027 Bowen Phase 1 250 Fourth quarter 2028 Bowen Phase 2 250 Fourth quarter 2029 South Hall 250 Fourth quarter 2028 Wansley 500 Fourth quarter 2028 Yates Phase 1 320 Fourth quarter 2028 Yates Phase 2 250 Fourth quarter 2028 Thomson 500 Fourth quarter 2029 McIntosh 250 Fourth quarter 2030 Solar with Battery Energy Storage Laurens County 200 Fourth quarter 2028 Plant Mitchell 150 Fourth quarter 2028 Combined Cycle Plant Bowen Unit 7 741 Fourth quarter 2029 Plant Bowen Unit 8 741 Second quarter 2030 Plant Wansley Unit 10 727 Fourth quarter 2029 Plant Wansley Unit 11 727 Second quarter 2030 Plant McIntosh Unit 12 757 Fourth quarter 2030 Combustion Turbine Plant Yates Unit 8 (*) 442 Fourth quarter 2026 Plant Yates Unit 9 (*) 442 Second quarter 2027 Plant Yates Unit 10 (*) 442 Third quarter 2027 Projects Completed During the Six Months Ended June 30, 2026 Battery Energy Storage Robins 128 March 2026 Moody 50 April 2026 (*) Pursuant to the 2023 IRP Update, cost recovery over the certified amount is limited. 47 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Mississippi Power Performance Evaluation Plan On June 18, 2026, the Mississippi PSC approved Mississippi Power's annual retail PEP Evaluation Report for 2026, resulting in an annual increase in revenues of approximately 1.8 %, or $ 20 million, primarily due to increases in investment and depreciation. In accordance with the PEP rate schedule, the increase became effective with the first billing cycle of January 2026. Integrated Resource Plans On March 9, 2026, in compliance with its IRP requirements, Mississippi Power submitted its mid-point update to its 2024 IRP to the Mississippi PSC, indicating that the retirement dates of Plant Daniel Unit 2 and Plant Watson Unit 4 will extend beyond 2028. On July 7, 2026, the Mississippi PSC approved a request from Mississippi Power to convert either Plant Daniel Unit 1 or Unit 2 from a coal-fired unit to a natural gas-fired unit. Conversion of the declared unit is projected to be completed in 2029. The remaining net book value of Plant Daniel Units 1 and 2 was approximately $ 481 million at June 30, 2026, and Mississippi Power is continuing to depreciate these units using approved rates. Until a unit is declared to be converted, Mississippi Power is unable to determine what portion of the net book value will remain in service upon a unit conversion. Mississippi Power expects to reclassify the remaining net book value of assets no longer in service upon a unit conversion or retirement to a regulatory asset to be amortized over a period to be determined by the Mississippi PSC in future proceedings, consistent with a 2020 order. The ultimate outcome of this matter cannot be determined at this time. Environmental Compliance Overview Plan On April 14, 2026, the Mississippi PSC approved Mississippi Power's annual ECO Plan filing for 2026, resulting in a $ 2 million annual increase in revenues effective with the first billing cycle of May 2026. Ad Valorem Tax Adjustment On June 12, 2026, Mississippi Power submitted its annual ad valorem tax adjustment filing for 2026 to the Mississippi PSC, which requested a $ 7 million annual increase in revenues. The ultimate outcome of this matter cannot be determined at this time. System Restoration Rider On June 18, 2026, the Mississippi PSC approved Mississippi Power's annual SRR filing for 2026, with no change in retail rates. Mississippi Power's minimum annual SRR accrual increased from $ 13.5 million to $ 13.7 million. Reliability Reserve Accounting Order On March 16, 2026, through its annual PEP Evaluation Report, Mississippi Power notified the Mississippi PSC of its intent to use a portion of its $ 59 million retail reliability reserve balance during 2026. On June 18, 2026, the Mississippi PSC approved the annual PEP filing which allowed for the use of approximately $ 7 million of the reliability reserve balance, which Mississippi Power utilized for reliability-related generation, transmission, and distribution expenses during the first six months of 2026. At June 30, 2026, Mississippi Power's retail reliability reserve balance was $ 52 million. See "Performance Evaluation Plan" herein for information regarding Mississippi Power's annual PEP filing. Excess Accumulated Deferred Income Tax Accounting Order On June 18, 2026, the Mississippi PSC approved approximately $ 21 million associated with certain federal excess accumulated deferred income taxes resulting from the Tax Reform Legislation to be credited back to customers over an 18-month period starting with the first billing cycle of July 2026. 48 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company Gas Rate Proceedings On June 16, 2026, in connection with Nicor Gas' 2023 general base rate case proceeding, the Illinois Appellate Court determined that the Illinois Commission did not provide sufficient support for its disallowance of $ 43 million of Nicor Gas' planned capital investments that were expected to be completed by December 31, 2024. As the disallowance related to planned capital investments for which costs had not yet been incurred, it was not included in the pre-tax charge to income recorded in 2023. This matter remains subject to further proceedings before the Illinois Commission and had no impact on the current period financial statements. On July 21, 2026, Nicor Gas filed a petition for leave to appeal with the Illinois Supreme Court related to the capital structure approved in Nicor Gas' 2023 general base rate case proceeding. The Illinois Supreme Court is expected to rule on the petition on September 30, 2026. The ultimate outcome of these matters cannot be determined at this time. (C) CONTINGENCIES See Note 3 to the financial statements in Item 8 of the Form 10-K for information relating to various lawsuits and other contingencies. General Litigation Matters The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential litigation or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on such Registrant's financial statements. The Registrants intend to dispute the allegations raised in and vigorously defend against the pending legal challenges discussed below; however, the ultimate outcome of each of these matters cannot be determined at this time. Southern Company In July 2025, a purported class action complaint was filed in the U.S. District Court for the District of Maryland against two nuclear consulting companies and all U.S. commercial nuclear power operators, or affiliated entities, including Southern Company. The purported class of plaintiffs includes all persons employed in nuclear power generation by the defendants, including nuclear operators, nuclear engineers, and nuclear technicians, from May 1, 2003 to the present. The complaint alleges that, since at least May 2003, the nuclear power industry conspired to fix and suppress employee compensation for nuclear power generation employees in violation of federal antitrust law. Although not named as defendants, other entities are accused of having participated in the conspiracy alleged by the plaintiffs. The plaintiffs seek to recover, among other relief, unspecified monetary damages, including treble damages and attorneys' fees, and injunctive relief. In October 2025, Southern Company moved to dismiss the complaint. In November 2025, the plaintiffs filed an amended complaint naming Southern Nuclear, among others, as a defendant. In December 2025, Southern Company and Southern Nuclear filed a motion to dismiss the amended complaint. An adverse outcome could have a material impact on Southern Company's financial statements. Alabama Power In 2022, Mobile Baykeeper filed a citizen suit in the U.S. District Court for the Southern District of Alabama alleging that Alabama Power's plan to close the Plant Barry surface impoundment utilizing a closure-in-place methodology violates the Resource Conservation and Recovery Act (RCRA) and regulations governing CCR. Among other relief requested, Mobile Baykeeper sought a declaratory judgment that the RCRA and regulations governing CCR were being violated, preliminary and injunctive relief to prevent implementation of Alabama Power's closure plan, and the development of a closure plan that satisfies regulations governing CCR requirements. 49 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Later in 2022, Alabama Power filed a motion to dismiss the case. In 2024, the lawsuit was dismissed without prejudice by the U.S. District Court judge. Later in 2024, the U.S. District Court judge denied a motion to reconsider filed by the plaintiff, and the plaintiff filed a notice of appeal in the U.S. Court of Appeals for the Eleventh Circuit challenging the denial of the motion to reconsider the order of dismissal. On May 18, 2026, the U.S. Court of Appeals for the Eleventh Circuit overturned the dismissal and remanded the case to the U.S. District Court for further proceedings. In 2023, the EPA issued a Notice of Potential Violations (NOPV) associated with Alabama Power's plan to close the Plant Barry surface impoundment. In 2024, Alabama Power reached a settlement with the EPA resolving two of the three allegations in the NOPV related to the groundwater monitoring system and the emergency action plan at the Plant Barry surface impoundment. The settlement did not resolve the EPA's allegation relating to Alabama Power's plan to close the Plant Barry surface impoundment. Alabama Power has affirmed to the EPA its position that it is in compliance with CCR requirements. In July 2025, Coosa Riverkeeper filed a citizen suit in the U.S. District Court for the Northern District of Alabama alleging that Alabama Power's closure of the Plant Gadsden surface impoundment utilizing a closure-in-place methodology violates the RCRA and regulations governing CCR. Among other relief requested, Coosa Riverkeeper seeks declaratory judgment that Alabama Power is in violation of the RCRA and regulations governing CCR, and preliminary and injunctive relief to require Alabama Power to close the CCR unit and operate a groundwater monitoring system in a different manner to satisfy the RCRA and the regulations governing CCR requirements. In September 2025, Alabama Power filed a motion to dismiss the citizen suit. These matters could have a material impact on Alabama Power's and Southern Company's financial statements, including ARO estimates and cash flows. See Note 6 to the financial statements in Item 8 of the Form 10-K for a discussion of Alabama Power's ARO liabilities. Environmental Remediation The Southern Company system must comply with environmental laws and regulations governing the handling and disposal of waste and releases of hazardous substances. Under these various laws and regulations, the Southern Company system could incur substantial costs to clean up affected sites. The traditional electric operating companies and the natural gas distribution utilities in Illinois and Georgia have each received authority from their respective state PSCs or other applicable state regulatory agencies to recover approved environmental remediation costs through regulatory mechanisms. These regulatory mechanisms are adjusted annually or as necessary within limits approved by the state PSCs or other applicable state regulatory agencies. Georgia Power's environmental remediation liability was $ 15 million and $ 14 million at June 30, 2026 and December 31, 2025, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected. Southern Company Gas' environmental remediation liability was $ 215 million and $ 227 million at June 30, 2026 and December 31, 2025, respectively, based on the estimated cost of environmental investigation and remediation at known former manufactured gas plant operating sites. The ultimate outcome of these matters cannot be determined at this time; however, as a result of the regulatory treatment for environmental remediation expenses described above, the final disposition of these matters is not expected to have a material impact on the financial statements of the applicable Registrants. 50 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) (D) REVENUE FROM CONTRACTS WITH CUSTOMERS AND LEASE INCOME Revenue from Contracts with Customers The Registrants generate revenues from a variety of sources, some of which are not accounted for as revenue from contracts with customers, such as leases, derivatives, and certain cost recovery mechanisms. Included in the wholesale electric revenues of the traditional electric operating companies and Southern Power are revenues associated with affiliate transactions. These revenues are generated through long-term PPAs or short-term energy sales made in accordance with the IIC, as approved by the FERC. Amounts related to these affiliate revenues are eliminated in consolidation for Southern Company. See Note 1 to the financial statements under "Affiliate Transactions" and "Revenues" in Item 8 of the Form 10-K for additional information. See "Lease Income" herein and Note (J) for additional information on revenue accounted for under lease and derivative accounting guidance, respectively. 51 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) The following table disaggregates revenue from contracts with customers for the three and six months ended June 30, 2026 and 2025: Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Three Months Ended June 30, 2026 Operating revenues Retail electric revenues Residential $ 2,007 $ 720 $ 1,208 $ 79 $ — $ — Commercial 1,757 501 1,166 90 — — Industrial 1,021 441 471 109 — — Other 29 3 24 2 — — Total retail electric revenues 4,814 1,665 2,869 280 — — Natural gas distribution revenues Residential 353 — — — — 353 Commercial 89 — — — — 89 Transportation 358 — — — — 358 Industrial 6 — — — — 6 Other 67 — — — — 67 Total natural gas distribution revenues 873 — — — — 873 Wholesale electric revenues PPA energy revenues 301 47 40 8 218 — PPA capacity revenues 145 18 32 25 89 — Non-PPA revenues 64 55 19 80 43 — Total wholesale electric revenues 510 120 91 113 350 — Other natural gas revenues Gas marketing services 73 — — — — 73 Other 2 — — — — 2 Total other natural gas revenues 75 — — — — 75 Other revenues 450 62 212 11 4 — Total revenue from contracts with customers 6,722 1,847 3,172 404 354 948 Other revenue sources (*) 255 116 ( 39 ) ( 1 ) 181 18 Total operating revenues $ 6,977 $ 1,963 $ 3,133 $ 403 $ 535 $ 966 52 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Six Months Ended June 30, 2026 Operating revenues Retail electric revenues Residential $ 4,010 $ 1,493 $ 2,358 $ 159 $ — $ — Commercial 3,419 978 2,269 172 — — Industrial 1,962 855 909 198 — — Other 61 6 50 5 — — Total retail electric revenues 9,452 3,332 5,586 534 — — Natural gas distribution revenues Residential 1,380 — — — — 1,380 Commercial 342 — — — — 342 Transportation 798 — — — — 798 Industrial 30 — — — — 30 Other 213 — — — — 213 Total natural gas distribution revenues 2,763 — — — — 2,763 Wholesale electric revenues PPA energy revenues 796 93 104 11 610 — PPA capacity revenues 294 36 76 46 172 — Non-PPA revenues 156 175 63 250 88 — Total wholesale electric revenues 1,246 304 243 307 870 — Other natural gas revenues Gas marketing services 355 — — — — 355 Other 4 — — — — 4 Total other natural gas revenues 359 — — — — 359 Other revenues 945 140 449 26 8 — Total revenue from contracts with customers 14,765 3,776 6,278 867 878 3,122 Other revenue sources (*) 609 279 ( 2 ) 8 338 35 Total operating revenues $ 15,374 $ 4,055 $ 6,276 $ 875 $ 1,216 $ 3,157 53 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Three Months Ended June 30, 2025 Operating revenues Retail electric revenues Residential $ 2,021 $ 725 $ 1,217 $ 79 $ — $ — Commercial 1,716 504 1,127 85 — — Industrial 1,015 432 496 87 — — Other 29 2 25 2 — — Total retail electric revenues 4,781 1,663 2,865 253 — — Natural gas distribution revenues Residential 394 — — — — 394 Commercial 94 — — — — 94 Transportation 331 — — — — 331 Industrial 7 — — — — 7 Other 60 — — — — 60 Total natural gas distribution revenues 886 — — — — 886 Wholesale electric revenues PPA energy revenues 310 58 50 2 210 — PPA capacity revenues 154 29 35 17 85 — Non-PPA revenues 60 36 10 100 59 — Total wholesale electric revenues 524 123 95 119 354 — Other natural gas revenues Gas marketing services 81 — — — — 81 Other 5 — — — — 5 Total other natural gas revenues 86 — — — — 86 Other revenues 457 67 206 9 8 — Total revenue from contracts with customers 6,734 1,853 3,166 381 362 972 Other revenue sources (*) 239 115 ( 56 ) 19 184 7 Total operating revenues $ 6,973 $ 1,968 $ 3,110 $ 400 $ 546 $ 979 54 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Six Months Ended June 30, 2025 Operating revenues Retail electric revenues Residential $ 4,087 $ 1,531 $ 2,403 $ 153 $ — $ — Commercial 3,327 986 2,181 160 — — Industrial 1,930 822 940 168 — — Other 61 4 52 5 — — Total retail electric revenues 9,405 3,343 5,576 486 — — Natural gas distribution revenues Residential 1,239 — — — — 1,239 Commercial 292 — — — — 292 Transportation 737 — — — — 737 Industrial 26 — — — — 26 Other 170 — — — — 170 Total natural gas distribution revenues 2,464 — — — — 2,464 Wholesale electric revenues PPA energy revenues 723 112 134 5 491 — PPA capacity revenues 299 57 74 34 169 — Non-PPA revenues 136 106 19 233 121 — Total wholesale electric revenues 1,158 275 227 272 781 — Other natural gas revenues Gas marketing services 337 — — — — 337 Other 10 — — — — 10 Total other natural gas revenues 347 — — — — 347 Other revenues 954 150 436 30 14 — Total revenue from contracts with customers 14,328 3,768 6,239 788 795 2,811 Other revenue sources (*) 420 212 ( 91 ) 33 318 7 Total operating revenues $ 14,748 $ 3,980 $ 6,148 $ 821 $ 1,113 $ 2,818 (*) Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs primarily at Southern Company Gas, and cost recovery mechanisms and revenues (including those related to fuel costs) that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies. 55 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Contract Balances The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers at June 30, 2026 and December 31, 2025: Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Accounts Receivable At June 30, 2026 $ 3,155 $ 860 $ 1,549 $ 122 $ 136 $ 448 At December 31, 2025 3,139 716 1,278 115 132 864 Contract Assets At June 30, 2026 $ 354 $ — $ 189 $ 4 $ — $ 67 At December 31, 2025 294 3 160 — — 67 Contract Liabilities At June 30, 2026 $ 329 $ 7 $ 123 $ — $ 1 $ — At December 31, 2025 213 6 75 — 2 — Contract assets for Georgia Power primarily relate to unregulated service agreements, where payment is contingent on project completion, and retail customer fixed bill programs, where payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over a one-year contract term. Contract liabilities for Georgia Power primarily relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern Company Gas' contract assets relate to work performed on an energy efficiency enhancement and upgrade contract with the U.S. General Services Administration. Southern Company Gas received cash advances totaling approximately $ 68 million from a third-party financial institution to fund work performed. These advances have been accounted for as long-term debt on the balance sheets. See Note 1 to the financial statements under "Affiliate Transactions" in Item 8 of the Form 10-K for additional information regarding the construction contract. At June 30, 2026 and December 31, 2025, Southern Company's unregulated distributed generation business had contract assets of $ 92 million and $ 63 million, respectively, and contract liabilities of $ 199 million and $ 132 million, respectively, for outstanding performance obligations, all of which are expected to be satisfied within one year. Revenues recognized in the three and six months ended June 30, 2026, which were included in contract liabilities at December 31, 2025, were $ 26 million and $ 80 million, respectively, for Southern Company, $ 7 million and $ 18 million, respectively, for Georgia Power, and immaterial for the other Registrants. Contract liabilities are primarily classified as current on the balance sheets as the corresponding revenues are generally expected to be recognized within one year. Remaining Performance Obligations Southern Company's subsidiaries may enter into long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. For the traditional electric operating companies and Southern Power, these contracts primarily relate to PPAs whereby electricity and generation capacity are provided to a customer. The revenue recognized for the delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related 56 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at June 30, 2026 are expected to be recognized as follows: 2026 (remaining) 2027 2028 2029 2030 Thereafter (in millions) Southern Company $ 668 $ 826 $ 472 $ 413 $ 416 $ 3,130 Alabama Power 7 5 4 3 1 6 Georgia Power 37 69 46 22 22 146 Mississippi Power (*) 33 69 73 12 — — Southern Power (*) 184 349 389 393 393 2,978 Southern Company Gas 28 24 — — — — (*) Includes performance obligations related to affiliate PPAs with Georgia Power. See Note 1 to the financial statements under "Affiliate Transactions" in Item 8 of the Form 10-K for additional information. Lease Income Lease income for the three and six months ended June 30, 2026 and 2025 was as follows: Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Three Months Ended June 30, 2026 Lease income - interest income on sales-type leases $ 5 $ — $ — $ 3 $ 2 $ — Lease income - operating leases 34 3 7 1 27 9 Variable lease income 125 — — — 136 — Total lease income $ 164 $ 3 $ 7 $ 4 $ 165 $ 9 Six Months Ended June 30, 2026 Lease income - interest income on sales-type leases $ 12 $ — $ — $ 7 $ 4 $ — Lease income - operating leases 69 6 15 2 64 18 Variable lease income 204 — — — 223 — Total lease income $ 285 $ 6 $ 15 $ 9 $ 291 $ 18 Three Months Ended June 30, 2025 Lease income - interest income on sales-type leases $ 6 $ — $ — $ 4 $ 2 $ — Lease income - operating leases 33 2 7 1 37 9 Variable lease income 125 — — — 136 — Total lease income $ 164 $ 2 $ 7 $ 5 $ 175 $ 9 Six Months Ended June 30, 2025 Lease income - interest income on sales-type leases $ 11 $ — $ — $ 7 $ 4 $ — Lease income - operating leases 66 3 14 1 73 18 Variable lease income 207 1 — — 225 — Total lease income $ 284 $ 4 $ 14 $ 8 $ 302 $ 18 Lease payments received under tolling arrangements and PPAs consist of either scheduled payments or variable payments based on the amount of energy produced by the underlying electric generating units. Lease income related to PPAs is included in wholesale revenues for Alabama Power, Georgia Power, and Southern Power. 57 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) (E) CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS See Note 7 to the financial statements in Item 8 of the Form 10-K for additional information. Southern Company At June 30, 2026 and December 31, 2025, Southern Holdings had equity method investments totaling $ 156 million and $ 124 million, respectively, primarily related to investments in venture capital funds focused on energy and utility investments. The net earnings (losses) from these investments totaled $ 45 million and $( 14 ) million for the three months ended June 30, 2026 and 2025, respectively, and $ 48 million and $( 20 ) million for the six months ended June 30, 2026 and 2025, respectively. Southern Power Variable Interest Entities Southern Power has certain subsidiaries that are determined to be VIEs. Southern Power is considered the primary beneficiary of these VIEs because it controls the most significant activities of the VIEs, including operating and maintaining the respective assets, and has the obligation to absorb expected losses of these VIEs to the extent of its equity interests. SP Solar At June 30, 2026 and December 31, 2025, SP Solar had total assets of $ 5.1 billion and $ 5.2 billion, respectively, total liabilities of $ 364 million and $ 360 million, respectively, and noncontrolling interests of $ 907 million and $ 918 million, respectively. Cash distributions from SP Solar are allocated 67 % to Southern Power and 33 % to the limited partner in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. Southern Power consolidates SP Solar, as the primary beneficiary, since it controls the most significant activities of the entity, including operating and maintaining its assets. Certain transfers and sales of the assets in the VIE are subject to partner consent, and the liabilities are non-recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do not include any long-term debt. Other Variable Interest Entities Southern Power has other consolidated VIEs that relate to certain subsidiaries that have either sold noncontrolling interests to tax equity investors or acquired less than a 100% interest from facility developers. These entities are considered VIEs because the arrangements are structured similar to a limited partnership and the noncontrolling members do not have substantive kick-out rights. At June 30, 2026 and December 31, 2025, the other VIEs had total assets of $ 1.5 billion and $ 1.6 billion, respectively, total liabilities of $ 259 million and $ 236 million, respectively, and noncontrolling interests of $ 563 million and $ 617 million, respectively. Under the terms of the partnership agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent. 58 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company Gas The carrying amounts of Southern Company Gas' equity method investments at June 30, 2026 and December 31, 2025 were as follows: Investment Balance At June 30, 2026 At December 31, 2025 (in millions) SNG $ 1,220 $ 1,148 Other 34 34 Total $ 1,254 $ 1,182 The earnings from Southern Company Gas' equity method investment in SNG were $ 32 million and $ 23 million for the three months ended June 30, 2026 and 2025, respectively, and $ 77 million and $ 62 million for the six months ended June 30, 2026 and 2025, respectively. The earnings from Southern Company Gas' other equity method investments were immaterial for all periods presented. (F) FINANCING AND LEASES Bank Credit Arrangements See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K for additional information. At June 30, 2026, committed credit arrangements with banks were as follows: Expires Company 2026 2027 2028 2029 2031 Total Unused Expires within One Year (in millions) Southern Company parent (a) $ — $ — $ 500 $ — $ 2,500 $ 3,000 $ 2,999 $ — Alabama Power (b) 15 — — 650 700 1,365 1,365 15 Georgia Power (c) — — — — 2,050 2,050 2,042 — Mississippi Power (a) — — — 125 150 275 275 — Southern Power (a)(d) — — — — 600 600 600 — Southern Company Gas (e) — — — — 1,600 1,600 1,598 — SEGCO — 30 — — — 30 30 30 Southern Company $ 15 $ 30 $ 500 $ 775 $ 7,600 $ 8,920 $ 8,909 $ 45 (a) Arrangement expiring in 2031 represents a $ 3.25 billion combined arrangement for Southern Company, Mississippi Power, and Southern Power allowing for flexible sublimits. Pursuant to the combined facility, the allocations among Southern Company, Mississippi Power, and Southern Power may be adjusted. (b) Includes $ 15 million expiring in 2026 at Alabama Property Company, a wholly-owned subsidiary of Alabama Power, of which $ 15 million was unused at June 30, 2026. Alabama Power is not party to this arrangement. (c) Georgia Power had $ 26 million of letters of credit outstanding under an uncommitted letter of credit facility at June 30, 2026. (d) Does not include Southern Power Company's $ 75 million and $ 100 million continuing letter of credit facilities for standby letters of credit, expiring in 2027 and 2029, respectively, of which $ 17 million and $ 4 million, respectively, was unused at June 30, 2026. In addition, Southern Power Company had $ 23 million of letters of credit outstanding under an uncommitted letter of credit facility at June 30, 2026. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities. (e) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $ 800 million of the credit arrangement expiring in 2031. Southern Company Gas' committed credit arrangement expiring in 2031 also includes $ 800 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the multi-year credit arrangement expiring in 2031, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. As reflected in the table above, in March 2026, (i) Southern Company, Mississippi Power, and Southern Power extended the maturity date of their $ 3.25 billion combined multi-year credit arrangement from 2030 to 2031, (ii) 59 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company extended the maturity date of its multi-year credit agreement from 2027 to 2028, (iii) Georgia Power extended the maturity date of its multi-year credit arrangement from 2030 to 2031, and (iv) Mississippi Power extended the maturity date of its multi-year credit arrangement from 2027 to 2029. In May 2026, Alabama Power and Southern Company Gas Capital, along with Nicor Gas, extended the maturity date of each of their respective multi-year credit arrangements from 2030 to 2031. In May and June 2026, SEGCO amended its credit arrangements to extend the maturity dates from 2026 to 2027. Subject to applicable market conditions, Southern Company and its subsidiaries expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, Southern Company and its subsidiaries may extend the maturity dates and/or increase or decrease the lending commitments thereunder. These bank credit arrangements, as well as the term loan arrangements of the Registrants, Nicor Gas, and SEGCO, contain covenants that limit debt levels and contain cross-acceleration provisions to other indebtedness (including guarantee obligations) that are restricted only to the indebtedness of the individual company. The cross-acceleration provisions to other indebtedness would trigger an event of default if the applicable borrower defaulted on indebtedness, the payment of which was then accelerated. At June 30, 2026, the Registrants, Nicor Gas, and SEGCO were in compliance with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowings. A portion of the unused credit with banks is allocated to provide liquidity support to certain revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. At June 30, 2026, outstanding variable rate demand revenue bonds of the traditional electric operating companies with allocated liquidity support totaled approximately $ 1.5 billion (comprised of approximately $ 796 million at Alabama Power, $ 667 million at Georgia Power, and $ 58 million at Mississippi Power). In addition, at June 30, 2026, Georgia Power had approximately $ 210 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months. Variable rate demand revenue bonds and fixed rate revenue bonds required to be remarketed within the next 12 months are classified as long-term debt on the balance sheets as a result of available long-term committed credit. DOE Loan Guarantee Borrowings On February 20, 2026, pursuant to the loan guarantee program (DOE Loan Guarantee Program) established under Title XVII of the Energy Policy Act of 2005, as amended (Title XVII), Alabama Power entered into (i) a loan guarantee agreement, dated as of February 20, 2026 (Alabama Power LGA), between Alabama Power and the DOE, as guarantor, (ii) a note purchase agreement, dated as of February 20, 2026 (Alabama Power NPA), among Alabama Power, the FFB, and the Secretary of Energy, acting through the DOE, and (iii) future advance promissory notes, each dated February 20, 2026, made by Alabama Power to the FFB (each an Alabama Power FFB Note and, together with the Alabama Power NPA, the Alabama Power FFB Credit Facility Documents). The Alabama Power LGA and the Alabama Power FFB Credit Facility Documents are referred to herein together as the Alabama Power Loan Documents. In addition, on February 20, 2026, pursuant to the DOE Loan Guarantee Program, Georgia Power entered into (i) a loan guarantee agreement, dated as of February 20, 2026 (Georgia Power LGA and, together with the Alabama Power LGA, the Loan Guarantee Agreements), between Georgia Power and the DOE, as guarantor, (ii) a note purchase agreement, dated as of February 20, 2026 (Georgia Power NPA), among Georgia Power, the FFB, and the Secretary of Energy, acting through the DOE, and (iii) future advance promissory notes, each dated February 20, 2026, made by Georgia Power to the FFB (each a Georgia Power FFB Note and, together with the Georgia Power NPA, the Georgia Power FFB Credit Facility Documents). The Georgia Power LGA and the Georgia Power FFB Credit Facility Documents are referred to herein together as the Georgia Power Loan Documents. The Alabama Power FFB Credit Facility Documents provide for a multi-advance term loan facility under which Alabama Power may make term loan borrowings through the FFB (Alabama Power Credit Facility). The Georgia Power FFB Credit Facility Documents provide for a multi-advance term loan facility under which Georgia Power may make term loan borrowings through the FFB (Georgia Power Credit Facility and, together with the Alabama 60 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Power Credit Facility, the Credit Facilities). Each of Alabama Power and Georgia Power is referred to herein as a Borrower in connection with its applicable Credit Facility. Proceeds of advances made under each Credit Facility must be used for the purpose of reimbursing the applicable Borrower for a portion (up to 80 %) of "eligible project costs" (as defined in the applicable Loan Guarantee Agreement) incurred by such Borrower for projects that are eligible for financing under the terms of the applicable Loan Guarantee Agreement and the DOE Loan Guarantee Program (Eligible Projects). Eligible Projects may include new gas generating units and upgrades associated with existing gas generating units; new transmission lines, substations, and transmission system upgrades; new stand-alone battery energy storage systems; hydropower refurbishment and upgrades; upgrades, uprates, and license extensions for existing nuclear facilities; coal-to-gas conversions; and grid enhancements. The aggregate amount of advances under the Alabama Power Credit Facility may not exceed approximately $ 4.1 billion (Alabama Power Maximum Facility Amount). The aggregate amount of advances under the Georgia Power Credit Facility may not exceed approximately $ 22.4 billion (Georgia Power Maximum Facility Amount and, together with the Alabama Power Maximum Facility Amount, the Maximum Facility Amounts). Each Borrower may request advances under its applicable Credit Facility during an availability period (with respect to each Borrower, the "availability period") that will continue until the earliest of (i) September 15, 2033, (ii) the date total advances reach the applicable Maximum Facility Amount, or (iii) the termination of the obligation to fund further advances following an event of default under the applicable Loan Guarantee Agreement. In addition, the FFB's obligation to fund advances to Alabama Power will terminate if Alabama Power has failed to request an initial advance by February 20, 2031. In March 2026, Georgia Power received initial advances under the Georgia Power Credit Facility in an amount of approximately $ 1.0 billion at an interest rate of 5.041 % through the final maturity date of December 10, 2055. Future advances under each of the Credit Facilities are subject to confirmation of investment grade credit ratings and satisfaction of customary conditions, as well as certification of compliance with the requirements of Title XVII, including accuracy of project-related representation and warranties, delivery of updated project-related information, and evidence of compliance with the prevailing wage requirements of the Davis-Bacon Act of 1931, as amended (DOE Program Requirements), compliance with the Cargo Preference Act of 1954, and certification from the DOE's consulting engineer that proceeds of the advances are used to reimburse for eligible project costs. All borrowings under each of the Credit Facilities will be full recourse, senior unsecured obligations of the respective Borrower. Alabama Power is not a party to, and has no obligations with respect to, the Georgia Power Credit Facility. Georgia Power is not a party to, and has no obligations with respect to, the Alabama Power Credit Facility. The final scheduled maturity date for all borrowings under each Credit Facility is December 10, 2055. Each advance will bear interest at a rate equal to the applicable U.S. Treasury rate plus a spread of 0.375 %, which rate will be determined at the time of the advance. Principal payments for the Alabama Power Credit Facility are payable in three equal annual installments, beginning on December 10, 2053. Principal payments for the Georgia Power Credit Facility are payable in seven equal annual installments, beginning on December 10, 2049. Under each of the Loan Guarantee Agreements, the DOE agreed to provide guarantees with respect to the obligations of Alabama Power and Georgia Power under the Alabama Power FFB Credit Facility Documents and Georgia Power FFB Credit Facility Documents, respectively. Under their respective Loan Guarantee Agreements, Alabama Power and Georgia Power are obligated to reimburse the DOE for any amounts the DOE is required to pay with respect to such guarantees. Alabama Power's and Georgia Power's reimbursement obligations to the DOE are full recourse, senior unsecured obligations of the respective Borrower. Under each Loan Guarantee Agreement, the applicable Borrower is subject to customary affirmative and negative covenants and events of default. In addition, Alabama Power and Georgia Power are subject to project-related reporting requirements and other project-specific covenants and events of default. 61 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Under each Loan Guarantee Agreement, the applicable Borrower will be required to prepay certain amounts outstanding under the applicable Credit Facility if (i) the applicable Borrower takes any action that causes an Eligible Project to cease to be an Eligible Project, (ii) certain "termination events" (as defined in the applicable Loan Guarantee Agreement) occur with respect to any Eligible Project of the applicable Borrower, (iii) eligible project costs recoverable in customer rates of the applicable Borrower are less than 95 % of total advances made to the applicable Borrower under the applicable Credit Facility, with such amount tested on the third anniversary of the termination of the applicable availability period, or (iv) the applicable Borrower receives advances for certain preliminary costs and fails to satisfy the DOE Program Requirements. Any mandatory prepayment will be made in quarterly installments and, depending on the size of the required mandatory prepayment, will be payable over a period of one to three years (in the case of Alabama Power) or one to five years (in the case of Georgia Power). Any such mandatory prepayment will be at a prepayment price equal to 100 % of the principal amount to be prepaid, plus accrued and unpaid interest to the date of prepayment. In addition, if a "change of control" (as defined in the applicable Loan Guarantee Agreement) occurs with respect to the applicable Borrower, such Borrower will be required to offer to prepay all outstanding advances under its Credit Facility. Any such prepayment will be made with a make-whole premium or discount, as applicable. Each Borrower will be permitted to voluntarily prepay all or a portion of any outstanding advances. Any such prepayment will be made with a make-whole premium or discount, as applicable. Equity Distribution Agreement See Note 8 to the financial statements under "Equity Distribution Agreement" in Item 8 of the Form 10-K for additional information. In June 2026, Southern Company established a new at-the-market program and entered into an equity distribution agreement pursuant to which it may sell, from time to time, up to an aggregate of 50 million shares of its common stock, including through initially priced forward sale contracts and collared forward sale contracts (2026 ATM Program). In connection with the establishment of the 2026 ATM Program, Southern Company terminated further sales under its prior at-the-market program established in 2024 (2024 ATM Program). 62 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) The table below reflects shares of Southern Company common stock sold and settled under separate initially priced forward sale contracts with forward purchasers during the six months ended June 30, 2026. Shares Sold Initial Forward Price per Share To be Settled On or Before Forward Price Per Share Settled Shares Issued to Settle Settlement Date Sold during 2025 (2024 ATM Program) 3,255,866 $ 89.4692 December 31, 2026 $ 89.2443 3,255,866 March 2, 2026 2,314,487 $ 92.7805 June 30, 2027 $ 92.8723 2,314,487 March 2, 2026 3,850,000 $ 90.6617 December 31, 2026 $ 90.2362 3,850,000 June 1, 2026 2,470,306 $ 94.5394 June 30, 2027 $ 93.8913 2,470,306 June 1, 2026 1,590,200 $ 93.4524 June 30, 2027 $ 93.4038 1,590,200 June 1, 2026 4,000,000 $ 90.8141 June 30, 2027 $ 90.6358 4,000,000 June 12, 2026 2,876,034 $ 92.2437 June 30, 2027 $ 91.9664 2,876,034 June 12, 2026 3,015,668 $ 93.4521 June 30, 2027 $ 93.1290 3,015,668 June 12, 2026 3,130,641 (a) $ 88.2823 December 31, 2026 $ 88.0620 1,070,641 June 16, 2026 2,346,903 $ 91.1610 June 30, 2027 $ 90.9425 2,346,903 June 16, 2026 911,448 $ 94.2411 June 30, 2027 $ 93.9331 911,448 June 16, 2026 Sold during 2026 (2024 ATM Program) 1,467,305 $ 96.3883 March 31, 2028 N/A N/A N/A 1,896,549 $ 97.5815 March 31, 2028 N/A N/A N/A 1,903,317 $ 95.5086 March 31, 2028 N/A N/A N/A Sold during 2026 (2026 ATM Program) 1,713,535 $ 93.2987 June 30, 2028 N/A N/A N/A 1,909,112 $ 92.4821 June 30, 2028 N/A N/A N/A 1,994,083 $ 95.1457 June 30, 2028 N/A N/A N/A 600,094 (b) $ 95.9974 June 30, 2028 N/A N/A N/A (a) The total number of shares sold under this forward sale contract is 3,130,641 , of which 1,070,641 shares were settled during the six months ended June 30, 2026. The other 2,060,000 shares were settled in December 2025. (b) The total number of shares sold under this forward sale contract is 1,940,548 , of which the remaining 1,340,454 shares were sold subsequent to June 30, 2026. The initial forward price was determined after the completion of sales by the forward seller in July 2026. As of June 30, 2026, Southern Company had entered into separate forward sale contracts with forward purchasers for a total of 49,885,779 shares of common stock under the 2024 ATM Program, all of which had been sold by the forward sellers, and 7,557,278 shares of common stock under the 2026 ATM Program, of which 6,216,824 shares had been sold by the forward sellers. Of these shares, 27,701,553 were settled during the six months ended June 30, 2026, all under the 2024 ATM Program, in the form of shares at the initial forward price adjusted for interest earned and dividends paid from the forward sale date to the settlement date. The net proceeds from the shares settled during the six months ended June 30, 2026 were approximately $ 2.5 billion. As of June 30, 2026, the total number of shares sold remaining under the forward sale contracts subject to settlement at a future date is 11,483,995 . Each initial forward price is subject to adjustment under certain circumstances as specified in the respective forward sales contracts. Southern Company may settle each of the forward transactions in shares, cash, or net shares. Earnings per Share For Southern Company, the difference in computing basic and diluted EPS is attributable to awards outstanding under stock-based compensation plans, forward sale contracts pursuant to the equity distribution agreement, convertible senior notes, and equity units. EPS dilution resulting from stock-based compensation plans, forward sale contracts, and the equity units is determined using the treasury stock method. EPS dilution resulting from the convertible senior notes is determined using the net share settlement method. See "Equity Distribution Agreement" 63 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) herein and Note 8 to the financial statements under "Convertible Senior Notes," "Equity Distribution Agreement," and "Equity Units" and Note 12 to the financial statements in Item 8 of the Form 10-K for additional information. Shares used to compute diluted EPS were as follows: Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 (in millions) As reported shares 1,137 1,101 1,130 1,100 Effect of stock-based compensation 3 6 3 6 Effect of convertible senior notes — 1 — 1 Effect of forward sale contracts 1 — 1 — Diluted shares 1,141 1,108 1,134 1,107 For all periods presented, an immaterial number of stock-based compensation awards was excluded from the diluted EPS calculation because the awards were anti-dilutive. Georgia Power Lease Modification See Note 9 to the financial statements in Item 8 of the Form 10-K for information on Georgia Power's leases. In June 2026, Georgia Power recognized a lease modification related to an existing affiliate PPA with Southern Power which converted from an operating lease to a finance lease upon its approval by the FERC. As a result, Georgia Power removed from its balance sheet operating lease right-of-use assets, net of amortization of $ 179 million and lease obligations of $ 197 million maturing through 2030 and recorded finance lease right-of-use assets of $ 1.3 billion and lease obligations of $ 1.3 billion maturing through 2045. See Note (B) under "Georgia Power – Integrated Resource Plans – Certification Requests" for additional information. (G) INCOME TAXES See Note 10 to the financial statements in Item 8 of the Form 10-K for additional tax information. Cash Paid for Income Taxes Alabama Power, Georgia Power, and Southern Power have entered into transferability agreements with non-affiliated parties to sell ITCs and PTCs at a discount to the generated credit value in 2024, 2025, and 2026. The discount is recorded as a reduction in tax credits recognized in the financial statements and does not have a material impact on results of operations. During the first six months of 2026, Alabama Power, Georgia Power, and Southern Power received cash of $ 39 million, $ 91 million, and $ 49 million, respectively, from credits transferred. The Southern Company system continues to explore the ability to efficiently monetize its tax credits through third-party transfer agreements. During the first six months of 2026, pursuant to certain joint ownership agreements, Georgia Power paid $ 83 million to the other Vogtle Owners for advanced nuclear PTCs for Plant Vogtle Units 3 and 4. The gain was recognized as an income tax benefit and was immaterial. Effective Tax Rate Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity at the traditional electric operating companies, flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs. Details of significant changes in the effective tax rate for the applicable Registrants are provided herein. Southern Company Southern Company's effective tax rate was 14.1 % for the six months ended June 30, 2026 compared to 21.1 % for the corresponding period in 2025. The effective tax rate decrease was primarily due to a decrease in charges to a 64 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) valuation allowance on certain state tax credit carryforwards at Georgia Power, an increase in federal PTCs at Southern Power, and an increase in amortization of federal PTCs at Georgia Power, partially offset by a decrease in the flowback of excess state deferred income taxes at Georgia Power. Georgia Power Georgia Power's effective tax rate was 14.3 % for the six months ended June 30, 2026 compared to 21.7 % for the corresponding period in 2025. The effective tax rate decrease was primarily due to a decrease in charges to a valuation allowance on certain state tax credit carryforwards and an increase in amortization of federal PTCs and ITCs, partially offset by a decrease in the flowback of excess state deferred income taxes. Southern Power Southern Power's effective tax benefit rate was ( 85.1 )% for the six months ended June 30, 2026 compared to ( 7.0 )% for the corresponding period in 2025. The effective tax benefit rate increase was primarily due to an increase in federal PTCs resulting from Southern Power's purchase of the noncontrolling membership interests in the SP Wind tax equity partnership, as well as a change in pre-tax earnings attributable to Southern Power, including the impact of accelerated depreciation related to wind repowering projects. See Note (K) under "Southern Power – Wind Repowering Projects" and Notes 5 and 15 to the financial statements under "Depreciation and Amortization – Southern Power" and "Southern Power – Purchase of Renewable Facility Interests," respectively, in Item 8 of the Form 10-K for additional information. Southern Company Gas Southern Company Gas' effective tax rate was 23.5 % for the six months ended June 30, 2026 compared to 23.7 % for the corresponding period in 2025. The effective tax rate decrease was primarily due to an increase in tax benefits related to certain state tax filing positions, offset by a decrease in the flowback of excess state deferred income taxes. (H) RETIREMENT BENEFITS The Southern Company system has a qualified defined benefit, trusteed, pension plan covering substantially all employees, with the exception of employees at PowerSecure. The qualified pension plan is funded in accordance with requirements of the Employee Retirement Income Security Act of 1974, as amended. No mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2026. The Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other postretirement trusts to the extent required by their respective regulatory commissions. See Note 11 to the financial statements in Item 8 of the Form 10-K for additional information. On each Registrant's condensed statements of income, the service cost component of net periodic benefit costs is included in other operations and maintenance expenses and all other components of net periodic benefit costs are included in other income (expense), net. Components of the net periodic benefit costs for the three and six months ended June 30, 2026 and 2025 are presented in the following tables. 65 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Three Months Ended June 30, 2026 Pension Plans Service cost $ 69 $ 16 $ 16 $ 3 $ 1 $ 7 Interest cost 161 37 47 8 3 11 Expected return on plan assets ( 322 ) ( 78 ) ( 100 ) ( 14 ) ( 4 ) ( 22 ) Amortization: Prior service costs — — 1 — — ( 1 ) Net (gain) loss 19 5 7 — ( 1 ) 1 Net periodic pension income $ ( 73 ) $ ( 20 ) $ ( 29 ) $ ( 3 ) $ ( 1 ) $ ( 4 ) Postretirement Benefits Service cost $ 3 $ 1 $ 1 $ — $ — $ — Interest cost 16 4 6 — — 2 Expected return on plan assets ( 22 ) ( 8 ) ( 8 ) 1 — ( 2 ) Amortization: Net gain ( 2 ) ( 1 ) — — — ( 2 ) Net periodic postretirement benefit cost (income) $ ( 5 ) $ ( 4 ) $ ( 1 ) $ 1 $ — $ ( 2 ) Six Months Ended June 30, 2026 Pension Plans Service cost $ 138 $ 31 $ 33 $ 6 $ 3 $ 14 Interest cost 323 75 94 15 5 22 Expected return on plan assets ( 644 ) ( 157 ) ( 199 ) ( 29 ) ( 8 ) ( 43 ) Amortization: Prior service costs — — 1 — — ( 1 ) Regulatory asset — — — — — 3 Net (gain) loss 37 10 13 1 ( 1 ) 1 Net periodic pension income $ ( 146 ) $ ( 41 ) $ ( 58 ) $ ( 7 ) $ ( 1 ) $ ( 4 ) Postretirement Benefits Service cost $ 6 $ 2 $ 2 $ — $ — $ — Interest cost 32 8 12 1 — 3 Expected return on plan assets ( 45 ) ( 17 ) ( 16 ) — — ( 4 ) Amortization: Prior service costs 1 — — — — — Net gain ( 4 ) ( 1 ) — — — ( 4 ) Net periodic postretirement benefit cost (income) $ ( 10 ) $ ( 8 ) $ ( 2 ) $ 1 $ — $ ( 5 ) 66 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Three Months Ended June 30, 2025 Pension Plans Service cost $ 66 $ 15 $ 15 $ 2 $ 2 $ 7 Interest cost 166 38 49 8 3 11 Expected return on plan assets ( 320 ) ( 78 ) ( 99 ) ( 14 ) ( 4 ) ( 22 ) Amortization: Prior service costs — — 1 — — ( 1 ) Regulatory asset — — — — — 4 Net (gain) loss 10 4 3 — ( 2 ) — Net periodic pension income $ ( 78 ) $ ( 21 ) $ ( 31 ) $ ( 4 ) $ ( 1 ) $ ( 1 ) Postretirement Benefits Service cost $ 3 $ 1 $ 1 $ — $ — $ — Interest cost 18 4 7 — — 2 Expected return on plan assets ( 22 ) ( 9 ) ( 8 ) — — ( 2 ) Amortization: Regulatory asset — — — — — 2 Net (gain) loss ( 4 ) — ( 2 ) 1 — ( 2 ) Net periodic postretirement benefit cost (income) $ ( 5 ) $ ( 4 ) $ ( 2 ) $ 1 $ — $ — Six Months Ended June 30, 2025 Pension Plans Service cost $ 132 $ 30 $ 31 $ 5 $ 3 $ 13 Interest cost 332 77 98 15 5 22 Expected return on plan assets ( 640 ) ( 156 ) ( 198 ) ( 29 ) ( 8 ) ( 43 ) Amortization: Prior service costs — — 1 — — ( 1 ) Regulatory asset — — — — — 8 Net (gain) loss 19 6 7 1 ( 1 ) — Net periodic pension income $ ( 157 ) $ ( 43 ) $ ( 61 ) $ ( 8 ) $ ( 1 ) $ ( 1 ) Postretirement Benefits Service cost $ 6 $ 2 $ 2 $ — $ — $ — Interest cost 35 8 13 1 — 4 Expected return on plan assets ( 45 ) ( 18 ) ( 16 ) — — ( 4 ) Amortization: Prior service costs 1 — — — — — Regulatory asset — — — — — 3 Net gain ( 7 ) — ( 2 ) — — ( 4 ) Net periodic postretirement benefit cost (income) $ ( 10 ) $ ( 8 ) $ ( 3 ) $ 1 $ — $ ( 1 ) 67 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) (I) FAIR VALUE MEASUREMENTS At June 30, 2026, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows: Fair Value Measurements Using At June 30, 2026 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Southern Company Assets: Energy-related derivatives (a) $ 8 $ 61 $ — $ — $ 69 Interest rate derivatives — 5 — — 5 Investments in trusts: (b) Domestic equity 1,030 293 — — 1,323 Foreign equity 199 256 — — 455 U.S. Treasury and government agency securities — 410 — — 410 Municipal bonds — 31 — — 31 Pooled funds – fixed income — 4 — — 4 Corporate bonds — 533 — — 533 Mortgage- and asset-backed securities — 110 — — 110 Private equity — — — 202 202 Cash and cash equivalents 1 — — — 1 Other 33 4 — 9 46 Investments, available-for-sale: U.S. Treasury and government agency securities 1 12 — — 13 Municipal bonds — 2 — — 2 Corporate bonds — 4 — — 4 Mortgage- and asset-backed securities — 3 — — 3 Cash equivalents 1,768 18 — — 1,786 Other investments 10 35 8 — 53 Other — — 10 — 10 Total $ 3,050 $ 1,781 $ 18 $ 211 $ 5,060 Liabilities: Energy-related derivatives (a) $ 11 $ 155 $ — $ — $ 166 Interest rate derivatives — 205 — — 205 Foreign currency derivatives — 63 — — 63 Contingent consideration — — 12 — 12 Other — 13 11 — 24 Total $ 11 $ 436 $ 23 $ — $ 470 68 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Fair Value Measurements Using At June 30, 2026 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Alabama Power Assets: Energy-related derivatives $ — $ 27 $ — $ — $ 27 Nuclear decommissioning trusts: (b) Domestic equity 569 282 — — 851 Foreign equity 199 — — — 199 U.S. Treasury and government agency securities — 16 — — 16 Municipal bonds — 1 — — 1 Corporate bonds — 319 — — 319 Mortgage- and asset-backed securities — 28 — — 28 Private equity — — — 202 202 Other 14 2 — 9 25 Cash equivalents 40 18 — — 58 Other investments — 35 — — 35 Total $ 822 $ 728 $ — $ 211 $ 1,761 Liabilities: Energy-related derivatives $ — $ 58 $ — $ — $ 58 Georgia Power Assets: Energy-related derivatives $ — $ 14 $ — $ — $ 14 Nuclear decommissioning trusts: (b) Domestic equity 461 1 — — 462 Foreign equity — 254 — — 254 U.S. Treasury and government agency securities — 394 — — 394 Municipal bonds — 30 — — 30 Corporate bonds — 214 — — 214 Mortgage- and asset-backed securities — 82 — — 82 Other 19 2 — — 21 Cash equivalents 11 — — — 11 Total $ 491 $ 991 $ — $ — $ 1,482 Liabilities: Energy-related derivatives $ — $ 48 $ — $ — $ 48 69 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Fair Value Measurements Using At June 30, 2026 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Net Asset Value as a Practical Expedient (NAV) Total (in millions) Mississippi Power Assets: Energy-related derivatives $ — $ 14 $ — $ — $ 14 Cash equivalents 1 — — — 1 Total $ 1 $ 14 $ — $ — $ 15 Liabilities: Energy-related derivatives $ — $ 40 $ — $ — $ 40 Southern Power Assets: Energy-related derivatives $ — $ 3 $ — $ — $ 3 Cash equivalents 162 — — — 162 Other — — 10 — 10 Total $ 162 $ 3 $ 10 $ — $ 175 Liabilities: Energy-related derivatives $ — $ 4 $ — $ — $ 4 Contingent consideration — — 12 — 12 Other — 13 11 — 24 Total $ — $ 17 $ 23 $ — $ 40 Southern Company Gas Assets: Energy-related derivatives (a) $ 8 $ 3 $ — $ — $ 11 Non-qualified deferred compensation trusts: Domestic equity — 10 — — 10 Foreign equity — 2 — — 2 Pooled funds – fixed income — 4 — — 4 Cash and cash equivalents 1 — — — 1 Cash equivalents 200 — — — 200 Total $ 209 $ 19 $ — $ — $ 228 Liabilities: Energy-related derivatives (a) $ 11 $ 5 $ — $ — $ 16 Interest rate derivatives — 62 — — 62 Total $ 11 $ 67 $ — $ — $ 78 (a) Excludes cash collateral of $ 18 million. (b) Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6 to the financial statements under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information. Southern Company, Alabama Power, and Georgia Power continue to elect the option to fair value investment securities held in the nuclear decommissioning trust funds. The fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased (decreased) by the amounts shown in the table below for 70 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) the three and six months ended June 30, 2026 and 2025. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively. Three Months Ended June 30, Six Months Ended June 30, Fair value increases (decreases) 2026 2025 2026 2025 (in millions) Southern Company $ 249 $ 165 $ 205 $ 159 Alabama Power 156 99 126 86 Georgia Power 93 66 79 73 Valuation Methodologies The energy-related derivatives primarily consist of exchange-traded and over-the-counter financial products for natural gas and physical power products, including, from time to time, basis swaps. These are standard products used within the energy industry and are valued using the market approach. The inputs used are mainly from observable market sources, such as forward natural gas prices, power prices, implied volatility, and overnight index swap interest rates. Interest rate derivatives are also standard over-the-counter products that are valued using observable market data and assumptions commonly used by market participants. The fair value of interest rate derivatives reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future interest rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and occasionally, implied volatility of interest rate options. The fair value of cross-currency swaps reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future foreign currency exchange rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and discount rates. The interest rate derivatives and cross-currency swaps are categorized as Level 2 under Fair Value Measurements as these inputs are based on observable data and valuations of similar instruments. See Note (J) for additional information on how these derivatives are used. For fair value measurements of the investments within the nuclear decommissioning trusts and the non-qualified deferred compensation trusts, external pricing vendors are designated for each asset class with each security specifically assigned a primary pricing source. For investments held within commingled funds, fair value is determined at the end of each business day through the net asset value, which is established by obtaining the underlying securities' individual prices from the primary pricing source. A market price secured from the primary source vendor is then evaluated by management in its valuation of the assets within the trusts. As a general approach, fixed income market pricing vendors gather market data (including indices and market research reports) and integrate relative credit information, observed market movements, and sector news into proprietary pricing models, pricing systems, and mathematical tools. Dealer quotes and other market information, including live trading levels and pricing analysts' judgments, are also obtained when available. The NRC requires licensees of commissioned nuclear power reactors to establish a plan for providing reasonable assurance of funds for future decommissioning. See Note 6 to the financial statements under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information. Southern Company's investments, available for sale relate to a wholly-owned subsidiary that insures various risk exposures of Southern Company and its subsidiaries. Corporate and municipal bonds, government agency securities, and commercial paper are valued using pricing models maximizing the use of observable inputs for similar securities, including basing value on yields currently available on comparable securities of issues with similar credit ratings. Mortgage- and asset-backed securities are valued through an analysis of the underlying assets and a review of the documentation, including financials, the manager's valuation methodology in valuing their underlying assets, the types of assets and risks involved, and the investor's exit and termination parameters. Southern Power has contingent payment obligations related to two of its acquisitions whereby it is primarily obligated to make generation-based payments to the seller, commencing at the commercial operation of each facility 71 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) and continuing through 2026 and 2036, respectively. The obligations are primarily categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility's generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate. The fair value of the obligations reflects the net present value of expected payments and any periodic change arising from forecasted generation is expected to be immaterial. Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system. The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value of expected payments. "Other investments" primarily includes investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds. At June 30, 2026, the fair value measurements of private market investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $ 211 million and unfunded commitments related to the private market investments totaled $ 94 million. Private market investments include high-quality private equity funds across several market sectors, funds that invest in real estate assets, and private credit funds. Private market funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated. At June 30, 2026, other financial instruments for which the carrying amount did not equal fair value were as follows: Southern Company (*) Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (*) (in billions) Long-term debt, including securities due within one year: Carrying amount $ 72.7 $ 12.0 $ 22.3 $ 1.8 $ 3.0 $ 9.3 Fair value 68.0 10.7 20.7 1.7 2.9 8.4 (*) The carrying amount of Southern Company Gas' long-term debt includes fair value adjustments from the effective date of the 2016 merger with Southern Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being through 2043. The fair values are determined using Level 2 measurements and are based on quoted market prices for the same or similar issues or on the current rates available to the Registrants. (J) DERIVATIVES The Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company's policies in areas such as counterparty exposure and risk management practices. Each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with the classification of the hedged interest or principal, respectively. See Note 1 to the financial statements under "Financial Instruments" in Item 8 of the Form 10-K for additional information. 72 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Energy-Related Derivatives The Subsidiary Registrants enter into energy-related derivatives to hedge exposures to electricity, natural gas, and other fuel price changes. However, due to cost-based rate regulations and other various cost recovery mechanisms, the traditional electric operating companies and the natural gas distribution utilities have limited exposure to market volatility in energy-related commodity prices. Each of the traditional electric operating companies and certain of the natural gas distribution utilities manage fuel-hedging programs, implemented per the guidelines of their respective state PSCs or other applicable state regulatory agencies, through the use of financial derivative contracts, which are expected to continue to mitigate price volatility. The traditional electric operating companies (with respect to wholesale generating capacity) and Southern Power have limited exposure to market volatility in energy-related commodity prices because their long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. However, the traditional electric operating companies and Southern Power may be exposed to market volatility in energy-related commodity prices to the extent any uncontracted capacity is used to sell electricity. Southern Company Gas retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations. Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather. Exchange-traded options are carried at fair value, with changes reflected in natural gas revenues. Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in natural gas revenues. Energy-related derivative contracts are accounted for under one of three methods: • Regulatory Hedges – Energy-related derivative contracts designated as regulatory hedges relate primarily to the traditional electric operating companies' and the natural gas distribution utilities' fuel-hedging programs, where gains and losses are initially recorded as regulatory liabilities and assets, respectively, and then are included in fuel expense as the underlying fuel is used in operations and ultimately recovered through an approved cost recovery mechanism. • Cash Flow Hedges – Gains and losses on energy-related derivatives designated as cash flow hedges (which are mainly used to hedge anticipated purchases and sales) are initially deferred in accumulated OCI before being recognized in the statements of income in the same period and in the same income statement line item as the earnings effect of the hedged transactions. • Not Designated – Gains and losses on energy-related derivative contracts that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred. Some energy-related derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the electric and natural gas industries. When an energy-related derivative contract is settled physically, any cumulative unrealized gain or loss is reversed and the contract price is recognized in the respective line item representing the actual price of the underlying goods being delivered. 73 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) At June 30, 2026, the net volume of energy-related derivative contracts for natural gas positions, together with the longest hedge date over which the respective entity is hedging its exposure to the variability in future cash flows for forecasted transactions and the longest non-hedge date for derivatives not designated as hedges, were as follows: Net Purchased mmBtu Longest Hedge Date Longest Non-Hedge Date (in millions) Southern Company (*) 469 2030 2029 Alabama Power 155 2029 2026 Georgia Power 117 2028 2026 Mississippi Power 114 2030 2026 Southern Power 8 2030 2026 Southern Company Gas (*) 75 2028 2029 (*) Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of 85 million mmBtu long natural gas positions and 10 million mmBtu short natural gas positions at June 30, 2026, which is also included in Southern Company's total volume. In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is 15 million mmBtu for Southern Company, which includes 4 million mmBtu for Alabama Power, 6 million mmBtu for Georgia Power, 2 million mmBtu for Mississippi Power, and 3 million mmBtu for Southern Power. For cash flow hedges of energy-related derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to earnings for the 12-month period ending June 30, 2027 are immaterial for Southern Company, Alabama Power, Mississippi Power, Southern Power, and Southern Company Gas. Interest Rate Derivatives Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and presented on the same income statement line item as the earnings effect of the hedged transactions. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item. Fair value gains or losses on derivatives that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred. 74 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) At June 30, 2026, the following interest rate derivatives were outstanding: Notional Amount Weighted Average Interest Rate Paid Interest Rate Received Hedge Maturity Date Fair Value Gain (Loss) at June 30, 2026 (in millions) (in millions) Fair Value Hedges of Existing Debt Southern Company parent $ 400 1-day SOFR + 0.80 % 1.75 % March 2028 $ ( 23 ) Southern Company parent 1,000 1-day SOFR + 2.48 % 3.70 % April 2030 ( 103 ) Southern Company parent 565 1-day SOFR + 1.56 % 6.50 % March 2045 ( 12 ) Southern Company Gas 500 1-day SOFR + 0.49 % 1.75 % January 2031 ( 62 ) Southern Company $ 2,465 $ ( 200 ) For cash flow hedges of interest rate derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to interest expense for the 12-month period ending June 30, 2027 are immaterial for Southern Company, the traditional electric operating companies, and Southern Company Gas. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2054 for Southern Company, Georgia Power, and Mississippi Power, 2052 for Alabama Power, and 2046 for Southern Company Gas. Foreign Currency Derivatives Southern Company and certain subsidiaries may enter into foreign currency derivatives to hedge exposure to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S. dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and on the same income statement line as the earnings effect of the hedged transactions, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Southern Company has elected to exclude the cross-currency basis spread from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in the fair value of the excluded components and the amounts recognized in earnings as a component of OCI. At June 30, 2026, the following foreign currency derivatives were outstanding: Pay Notional Pay Rate Receive Notional Receive Rate Hedge Maturity Date Fair Value Gain (Loss) at June 30, 2026 (in millions) (in millions) (in millions) Fair Value Hedges of Existing Debt Southern Company parent $ 1,476 3.39 % € 1,250 1.88 % September 2027 $ ( 63 ) Derivative Financial Statement Presentation and Amounts The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties. 75 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected as either assets or liabilities in the balance sheets (included in "Other" or shown separately as "Risk Management Activities") as follows: At June 30, 2026 At December 31, 2025 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) Southern Company Energy-related derivatives designated as hedging instruments for regulatory purposes Current $ 28 $ 89 $ 24 $ 64 Non-current 30 60 31 35 Total derivatives designated as hedging instruments for regulatory purposes 58 149 55 99 Derivatives designated as hedging instruments in cash flow and fair value hedges Energy-related derivatives: Current 3 12 1 6 Non-current 2 1 2 1 Interest rate derivatives: Current 5 52 8 48 Non-current — 153 — 139 Foreign currency derivatives: Current — 23 17 22 Non-current — 40 4 — Total derivatives designated as hedging instruments in cash flow and fair value hedges 10 281 32 216 Energy-related derivatives not designated as hedging instruments Current 6 4 6 6 Gross amounts recognized 74 434 93 321 Gross amounts offset (a) ( 39 ) ( 57 ) ( 21 ) ( 54 ) Net amounts recognized in the Balance Sheets (b) $ 35 $ 377 $ 72 $ 267 Alabama Power Energy-related derivatives designated as hedging instruments for regulatory purposes Current $ 15 $ 31 $ 9 $ 18 Non-current 12 25 10 13 Total derivatives designated as hedging instruments for regulatory purposes 27 56 19 31 Derivatives designated as hedging instruments in cash flow and fair value hedges Energy-related derivatives: Current — 2 — — Gross amounts recognized 27 58 19 31 Gross amounts offset ( 16 ) ( 16 ) ( 13 ) ( 13 ) Net amounts recognized in the Balance Sheets $ 11 $ 42 $ 6 $ 18 76 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) At June 30, 2026 At December 31, 2025 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) Georgia Power Energy-related derivatives designated as hedging instruments for regulatory purposes Current $ 5 $ 32 $ 7 $ 23 Non-current 7 16 10 10 Total derivatives designated as hedging instruments for regulatory purposes 12 48 17 33 Energy-related derivatives not designated as hedging instruments Current 2 — 1 — Gross amounts recognized 14 48 18 33 Gross amounts offset ( 11 ) ( 11 ) ( 14 ) ( 14 ) Net amounts recognized in the Balance Sheets $ 3 $ 37 $ 4 $ 19 Mississippi Power Energy-related derivatives designated as hedging instruments for regulatory purposes Current $ 3 $ 21 $ 3 $ 15 Non-current 11 19 11 12 Total derivatives designated as hedging instruments for regulatory purposes 14 40 14 27 Gross amounts offset ( 13 ) ( 13 ) ( 13 ) ( 13 ) Net amounts recognized in the Balance Sheets $ 1 $ 27 $ 1 $ 14 Southern Power Derivatives designated as hedging instruments in cash flow hedges Energy-related derivatives: Current $ 1 $ 2 $ 1 $ 1 Non-current 2 1 2 — Foreign currency derivatives: Current — — 17 — Total derivatives designated as hedging instruments in cash flow hedges 3 3 20 1 Energy-related derivatives not designated as hedging instruments Current — 1 1 — Gross amounts recognized 3 4 21 1 Gross amounts offset ( 1 ) ( 1 ) — — Net amounts recognized in the Balance Sheets $ 2 $ 3 $ 21 $ 1 77 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) At June 30, 2026 At December 31, 2025 Derivative Category and Balance Sheet Location Assets Liabilities Assets Liabilities (in millions) Southern Company Gas Energy-related derivatives designated as hedging instruments for regulatory purposes Current $ 5 $ 5 $ 5 $ 8 Derivatives designated as hedging instruments in cash flow and fair value hedges Energy-related derivatives: Current 2 8 — 5 Non-current — — — 1 Interest rate derivatives: Current — 13 — 13 Non-current — 49 — 46 Total derivatives designated as hedging instruments in cash flow and fair value hedges 2 70 — 65 Energy-related derivatives not designated as hedging instruments Current 4 3 4 6 Gross amounts recognized 11 78 9 79 Gross amounts offset (a) 6 ( 12 ) 19 ( 14 ) Net amounts recognized in the Balance Sheets (b) $ 17 $ 66 $ 28 $ 65 (a) Gross amounts offset includes cash collateral held on deposit in broker margin accounts of $ 18 million and $ 33 million at June 30, 2026 and December 31, 2025, respectively. (b) Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives at June 30, 2026 and December 31, 2025. At June 30, 2026 and December 31, 2025, the pre-tax effects of unrealized derivative gains (losses) arising from energy-related derivative instruments designated as regulatory hedging instruments and deferred were as follows: Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheets Derivative Category and Balance Sheet Location Southern Company Alabama Power Georgia Power Mississippi Power Southern Company Gas (in millions) At June 30, 2026: Energy-related derivatives: Other regulatory assets, current $ ( 75 ) $ ( 26 ) $ ( 27 ) $ ( 18 ) $ ( 4 ) Other regulatory assets, deferred ( 31 ) ( 13 ) ( 10 ) ( 8 ) — Other regulatory liabilities, current 15 10 — — 5 Total energy-related derivative gains (losses) $ ( 91 ) $ ( 29 ) $ ( 37 ) $ ( 26 ) $ 1 At December 31, 2025: Energy-related derivatives: Other regulatory assets, current $ ( 48 ) $ ( 13 ) $ ( 17 ) $ ( 12 ) $ ( 6 ) Other regulatory assets, deferred ( 8 ) ( 5 ) ( 1 ) ( 2 ) — Other regulatory liabilities, current 7 4 1 — 2 Other regulatory liabilities, deferred 4 2 1 1 — Total energy-related derivative gains (losses) $ ( 45 ) $ ( 12 ) $ ( 16 ) $ ( 13 ) $ ( 4 ) 78 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) For the three and six months ended June 30, 2026 and 2025, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI for the applicable Registrants were as follows: Gain (Loss) From Derivatives Recognized in OCI Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 (in millions) Southern Company Cash flow hedges: Energy-related derivatives $ ( 8 ) $ ( 13 ) $ 1 $ 6 Interest rate derivatives — 9 — 5 Foreign currency derivatives ( 7 ) 47 ( 19 ) 67 Fair value hedges (*) : Foreign currency derivatives — 3 ( 1 ) ( 13 ) Total $ ( 15 ) $ 46 $ ( 19 ) $ 65 Alabama Power Cash flow hedges: Energy-related derivatives $ ( 2 ) $ — $ ( 2 ) $ — Georgia Power Cash flow hedges: Interest rate derivatives $ — $ 5 $ — $ 3 Southern Power Cash flow hedges: Energy-related derivatives $ ( 2 ) $ ( 1 ) $ — $ 2 Foreign currency derivatives ( 7 ) 47 ( 19 ) 67 Total $ ( 9 ) $ 46 $ ( 19 ) $ 69 Southern Company Gas Cash flow hedges: Energy-related derivatives $ ( 4 ) $ ( 12 ) $ 3 $ 4 Interest rate derivatives — 4 — 4 Total $ ( 4 ) $ ( 8 ) $ 3 $ 8 (*) Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded in OCI. 79 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) For the three and six months ended June 30, 2026 and 2025, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows: Gain (Loss) Statements of Income Location Derivative Category Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 (in millions) Southern Company Fuel Energy-related cash flow hedges $ ( 1 ) $ — $ 2 $ 1 Cost of natural gas Energy-related cash flow hedges ( 3 ) 1 7 — Interest expense, net of amounts capitalized Interest rate cash flow hedges ( 2 ) ( 3 ) ( 5 ) ( 6 ) Foreign currency cash flow hedges ( 2 ) ( 2 ) ( 5 ) ( 5 ) Interest rate fair value hedges ( 41 ) 29 ( 21 ) 69 Other income (expense), net Foreign currency cash flow hedges ( 2 ) 45 ( 14 ) 67 Foreign currency fair value hedges ( 13 ) 115 ( 45 ) 155 Amount excluded from effectiveness testing recognized in earnings — ( 3 ) 1 13 Southern Power Fuel Energy-related cash flow hedges $ ( 1 ) $ — $ 2 $ 1 Interest expense, net of amounts capitalized Foreign currency cash flow hedges ( 2 ) ( 2 ) ( 5 ) ( 5 ) Other income (expense), net Foreign currency cash flow hedges ( 2 ) 45 ( 14 ) 67 Southern Company Gas Cost of natural gas Energy-related cash flow hedges $ ( 3 ) $ 1 $ 7 $ — Interest expense, net of amounts capitalized Interest rate fair value hedges ( 32 ) 3 ( 3 ) 21 At June 30, 2026 and December 31, 2025, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for fair value hedges: Carrying Amount of the Hedged Item Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item Balance Sheet Location of Hedged Items At June 30, 2026 At December 31, 2025 At June 30, 2026 At December 31, 2025 (in millions) Southern Company Long-term debt $ ( 3,687 ) $ ( 3,742 ) $ 169 $ 156 Southern Company Gas Long-term debt $ ( 442 ) $ ( 446 ) $ 56 $ 51 Pre-tax gains (losses) on energy-related derivatives not designated as hedging instruments were $ 7 million and $( 14 ) million for the three months ended June 30, 2026 and 2025, respectively, and $ 2 million and $( 6 ) million for the six months ended June 30, 2026 and 2025, respectively, and reflected in cost of natural gas on the statements of income of Southern Company and Southern Company Gas. Contingent Features The Registrants do not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but 80 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. At June 30, 2026, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements. For Southern Company, the fair value of foreign currency derivative liabilities and interest rate derivative liabilities with contingent features, and the maximum potential collateral requirements arising from the credit-risk-related contingent features at a rating below BBB- and/or Baa3, was $ 31 million at June 30, 2026. For the traditional electric operating companies and Southern Power, energy-related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were immaterial at June 30, 2026. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions and they may be required to post collateral based on the value of the positions in these accounts and the associated margin requirements. At June 30, 2026, cash collateral posted in these accounts was immaterial for Alabama Power and Southern Power. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts, which are netted with energy-related derivatives recognized in the balance sheets. The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants generally enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's, S&P, or Fitch or with counterparties who have posted collateral to cover potential credit exposure. The Registrants have also established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty credit risk. Southern Company Gas uses established credit policies to determine and monitor the creditworthiness of counterparties, including requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most often in the form of cash or letters of credit from an investment-grade financial institution, but may also include cash or U.S. government securities held by a trustee. Prior to entering a physical transaction, Southern Company Gas assigns its counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary. The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of counterparty nonperformance. (K) ACQUISITIONS AND DISPOSITIONS See Note 15 to the financial statements in Item 8 of the Form 10-K for additional information. Southern Power Construction Projects During the six months ended June 30, 2026, Southern Power completed construction of and placed in service the 200 -MW first phase and continued construction of the 180 -MW second phase and 132 -MW third phase of the Millers Branch solar facility. At June 30, 2026, the total cost of construction incurred for the Millers Branch project 81 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) was $ 718 million, of which $ 408 million remains in CWIP. The ultimate outcome of these matters cannot be determined at this time. Project Facility Resource Approximate Nameplate Capacity ( MW ) Location Actual/Projected COD PPA Contract Period Projects Under Construction at June 30, 2026 Millers Branch Phase II Solar 180 Haskell County, TX Third quarter 2026 15 years Phase III Solar 132 Haskell County, TX Fourth quarter 2026 15 years Projects Completed During the Six Months Ended June 30, 2026 Millers Branch Phase I Solar 200 Haskell County, TX February 2026 20 years Wind Repowering Projects During the six months ended June 30, 2026, Southern Power continued the development projects to repower the Kay, Grant, Grant Plains, Wake, and Bethel wind facilities. At June 30, 2026, the total cost of construction incurred related to the projects was $ 598 million, of which $ 409 million remains in CWIP. The repowered output of the facilities is contracted under new and amended PPAs. The ultimate outcome of these matters cannot be determined at this time. Project Facility Resource Approximate Nameplate Capacity ( MW ) Location Actual/Projected Completion Date Projects Under Construction at June 30, 2026 Kay (a) Wind 200 Kay County, OK July 2026 (b) Grant Wind 152 Grant County, OK Fourth quarter 2026 Grant Plains Wind 147 Grant County, OK Fourth quarter 2026 Wake Wind 257 Crosby & Floyd Counties, TX Second quarter 2027 Bethel Wind 276 Castro County, TX Third quarter 2027 (a) The facility has a total capacity of 299 MWs, of which 200 MWs was projected to be repowered and is contracted under a PPA. (b) During the first six months of 2026 and subsequent to June 30, 2026, Southern Power placed all 200 MWs of repowered capacity in service. Natural Gas Turbine Upgrade Projects In the first quarter 2026, Southern Power committed to projects to upgrade certain turbines at its existing Franklin and Wansley natural gas facilities, located in Lee County, Alabama and Heard County, Georgia, respectively. The upgrades are projected to add up to 400 MWs of incremental capacity, with commercial operations projected to begin between the second quarter 2029 and the fourth quarter 2030. At June 30, 2026, the total cost of construction incurred related to the projects was $ 82 million, which is included in CWIP. The ultimate outcome of these matters cannot be determined at this time. 82 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) (L) SEGMENT AND RELATED INFORMATION See Note 16 to the financial statements in Item 8 of the Form 10-K for additional information. Southern Company The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. The traditional electric operating companies are vertically integrated utilities providing electric service in three Southeastern states. Southern Power develops, constructs, acquires, owns, operates, and manages power generation assets, including battery energy storage projects, and sells electricity at market-based rates in the wholesale market. Southern Company Gas distributes natural gas through its natural gas distribution utilities and is involved in several other complementary businesses including gas pipeline investments and gas marketing services. Southern Company's reportable business segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the distribution of natural gas and other complementary products and services by Southern Company Gas. While the traditional electric operating companies represent three separate operating segments, they are vertically integrated utilities providing electric service to retail customers, as well as wholesale customers, in the Southeast and have been aggregated into one reportable segment. The "All Other" presentation includes the Southern Company parent entity, which does not allocate operating expenses to business segments, and operating segments below the quantitative threshold for separate disclosure. These operating segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications. Revenues from sales by Southern Power to the traditional electric operating companies were $ 92 million and $ 192 million for the three and six months ended June 30, 2026, respectively, and $ 114 million and $ 229 million for the three and six months ended June 30, 2025, respectively. All other inter-segment revenues were immaterial for all periods presented. Southern Company's CODM utilizes segment net income, including variances to budget and forecasts, to assess performance and is not provided with segment expense information. To achieve the consolidated net income goal, Southern Company's CODM sets net income expectations for each operating segment, which is expected to monitor its expenses in order to achieve its assigned net income target. Therefore, Southern Company has no reportable significant segment expenses. 83 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Financial data for business segments for the three and six months ended June 30, 2026 and 2025 was as follows: Electric Utilities Traditional Electric Operating Companies Southern Power Eliminations Total Southern Company Gas Total Reportable Segments All Other Eliminations Consolidated (in millions) Three Months Ended June 30, 2026 Operating revenues $ 5,396 $ 535 $ ( 105 ) $ 5,826 $ 966 $ 6,792 $ 223 $ ( 38 ) $ 6,977 Other segment items (a) 2,501 329 ( 78 ) 2,752 554 3,306 193 ( 27 ) 3,472 Depreciation and amortization (b) 967 280 ( 15 ) 1,232 185 1,417 17 — 1,434 Earnings from equity method investments 12 — — 12 32 44 42 — 86 Interest expense 367 28 ( 12 ) 383 101 484 312 — 796 Income taxes (benefit) 304 ( 77 ) — 227 32 259 ( 72 ) — 187 Segment net income (loss) (b)(c) $ 1,269 $ ( 25 ) $ — $ 1,244 $ 126 $ 1,370 $ ( 185 ) $ ( 11 ) $ 1,174 Six Months Ended June 30, 2026 Operating revenues $ 10,878 $ 1,216 $ ( 246 ) $ 11,848 $ 3,157 $ 15,005 $ 441 $ ( 72 ) $ 15,374 Other segment items (a) 5,360 772 ( 219 ) 5,913 1,911 7,824 382 ( 68 ) 8,138 Depreciation and amortization (b) 1,908 558 ( 15 ) 2,451 369 2,820 34 — 2,854 Earnings from equity method investments 11 — — 11 78 89 47 — 136 Interest expense (d) 705 55 ( 12 ) 748 206 954 619 — 1,573 Income taxes (benefit) 534 ( 147 ) — 387 176 563 ( 149 ) — 414 Segment net income (loss) (b)(c)(d) $ 2,382 $ ( 22 ) $ — $ 2,360 $ 573 $ 2,933 $ ( 398 ) $ ( 4 ) $ 2,531 At June 30, 2026 Goodwill $ — $ 2 $ — $ 2 $ 5,015 $ 5,017 $ 144 $ — $ 5,161 Total assets 120,194 12,780 ( 2,101 ) 130,873 27,604 158,477 4,283 ( 733 ) 162,027 84 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Electric Utilities Traditional Electric Operating Companies Southern Power Eliminations Total Southern Company Gas Total Reportable Segments All Other Eliminations Consolidated (in millions) Three Months Ended June 30, 2025 Operating revenues $ 5,380 $ 546 $ ( 122 ) $ 5,804 $ 979 $ 6,783 $ 225 $ ( 35 ) $ 6,973 Other segment items (a) 2,674 296 ( 122 ) 2,848 599 3,447 193 ( 23 ) 3,617 Depreciation and amortization (b) 957 177 — 1,134 172 1,306 17 — 1,323 Earnings from equity method investments 4 — — 4 23 27 ( 17 ) — 10 Interest expense (d) 336 24 — 360 92 452 422 — 874 Income taxes (benefit) 370 ( 2 ) — 368 33 401 ( 112 ) — 289 Segment net income (loss) (b)(c)(d) $ 1,047 $ 51 $ — $ 1,098 $ 106 $ 1,204 $ ( 312 ) $ ( 12 ) $ 880 Six Months Ended June 30, 2025 Operating revenues $ 10,692 $ 1,113 $ ( 245 ) $ 11,560 $ 2,818 $ 14,378 $ 454 $ ( 84 ) $ 14,748 Other segment items (a) 5,468 599 ( 245 ) 5,822 1,670 7,492 401 ( 81 ) 7,812 Depreciation and amortization (b) 1,905 329 — 2,234 341 2,575 33 — 2,608 Earnings from equity method investments 2 — — 2 62 64 ( 21 ) — 43 Interest expense (d) 652 50 — 702 183 885 703 — 1,588 Income taxes (benefit) 596 ( 3 ) — 593 162 755 ( 186 ) — 569 Segment net income (loss) (b)(c)(d) $ 2,073 $ 138 $ — $ 2,211 $ 524 $ 2,735 $ ( 518 ) $ ( 3 ) $ 2,214 At December 31, 2025 Goodwill $ — $ 2 $ — $ 2 $ 5,015 $ 5,017 $ 144 $ — $ 5,161 Total assets 114,287 12,657 ( 915 ) 126,029 27,387 153,416 2,829 ( 525 ) 155,720 (a) Primarily consists of fuel, purchased power, cost of natural gas, cost of other sales, other operations and maintenance expenses, taxes other than income taxes, AFUDC equity, non-service cost-related retirement benefits income, and net income (loss) attributable to noncontrolling interests. (b) For Southern Power, includes accelerated depreciation related to the repowering of multiple wind facilities of $ 140 million ($ 109 million after tax) and $ 293 million ($ 228 million after tax) for the three and six months ended June 30, 2026, respectively, and $ 42 million ($ 31 million after tax, net of noncontrolling interest impacts) and $ 69 million ($ 51 million after tax, net of noncontrolling interest impacts) for the three and six months ended June 30, 2025. See Note (K) under "Southern Power – Wind Repowering Projects" and Notes 5 and 15 to the financial statements under "Depreciation and Amortization – Southern Power" and "Southern Power – Wind Repowering Projects," respectively, in Item 8 of the Form 10-K for additional information. (c) Attributable to Southern Company. (d) For All Other, includes pre-tax losses associated with the extinguishment of debt at the parent company of $ 11 million ($ 8 million after tax) for the six months ended June 30, 2026 and $ 129 million ($ 97 million after tax) for the three and six months ended June 30, 2025. Traditional Electric Operating Companies Each of the traditional electric operating companies' single reportable business segment is the sale of electricity. Alabama Power and Georgia Power have identified utility operations and maintenance expenses as significant segment expenses provided to their CODMs. Utility operations and maintenance expenses is calculated as other operations and maintenance, as reflected on the statements of income, less expenses from unregulated products and services, losses (gains) on asset dispositions, impairment charges, and amortization of cloud software. Alabama Power's utility operations and maintenance expenses are disaggregated into expenses related to Rate RSE and Rate 85 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) CNP Compliance. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information. During the third and fourth quarters of 2025, Mississippi Power updated the information provided to its CODM. As a result, Mississippi Power identified certain operational and environmental compliance expenses as significant segment expenses and has recast prior period information to conform to the current period presentation. Financial data for significant segment expenses and other segment information for the three and six months ended June 30, 2026 and 2025 was as follows: Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 (in millions) Alabama Power Operating revenues $ 1,963 $ 1,968 $ 4,055 $ 3,980 Utility operations and maintenance Rate RSE expenses 332 374 633 739 Rate CNP Compliance expenses 71 67 145 142 Total utility operations and maintenance 403 441 778 881 Other segment items (a) 486 544 1,154 1,152 Depreciation and amortization 385 371 766 741 Interest expense 117 116 232 225 Income taxes 135 115 263 226 Segment net income $ 437 $ 381 $ 862 $ 755 Capital expenditures $ 501 $ 599 $ 1,019 $ 1,159 Georgia Power Operating revenues $ 3,133 $ 3,110 $ 6,276 $ 6,148 Utility operations and maintenance 586 568 1,164 1,104 Other segment items (a) 886 989 2,050 2,106 Depreciation and amortization 503 512 987 1,015 Interest expense 228 198 431 385 Income taxes 151 236 236 334 Segment net income $ 779 $ 607 $ 1,408 $ 1,204 Capital expenditures $ 2,173 $ 1,676 $ 4,243 $ 3,313 Mississippi Power Operating revenues $ 403 $ 400 $ 875 $ 821 Operational expenses (b) 80 65 144 122 Environmental compliance expenses (c) 3 4 7 6 Other segment items (a) 173 183 424 400 Depreciation and amortization 58 52 113 105 Interest expense 21 20 41 40 Income taxes 16 17 34 34 Segment net income $ 52 $ 59 $ 112 $ 114 Capital expenditures $ 96 $ 126 $ 178 $ 199 86 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) (a) Primarily consists of fuel, purchased power, expenses from unregulated products and services, losses (gains) on asset dispositions, amortization of cloud software, taxes other than income taxes, AFUDC equity, and non-service cost-related retirement benefits income. For Mississippi Power, includes employee benefit expenses. Also includes earnings from equity method investments, which were immaterial for all periods presented. (b) Consists of certain operations and maintenance expenses related to PEP and the MRA tariff, including labor costs, materials, contract services, and other normal operational costs. See Note (B) under "Mississippi Power" and Note 2 to the financial statements under "Mississippi Power" in Item 8 of the Form 10-K for additional information regarding PEP and the MRA tariff. (c) Consists of environmental compliance expenses related to ECO Plan and the MRA tariff. See Note (B) under "Mississippi Power" and Note 2 to the financial statements under "Mississippi Power" in Item 8 of the Form 10-K for additional information regarding ECO Plan and the MRA tariff. Southern Power Southern Power's single reportable business segment is the sale of electricity in the competitive wholesale market. Southern Power's CODM utilizes segment expense information in the form of variances to budget to assess performance; therefore, Southern Power has no reportable significant segment expenses. Financial data for segment information for the three and six months ended June 30, 2026 and 2025 was as follows: Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 (in millions) Operating revenues $ 535 $ 546 $ 1,216 $ 1,113 Other segment items (a) 329 296 772 599 Depreciation and amortization (b) 280 177 558 329 Interest expense 28 24 55 50 Income taxes (benefit) ( 77 ) ( 2 ) ( 147 ) ( 3 ) Segment net income (loss) (b)(c) $ ( 25 ) $ 51 $ ( 22 ) $ 138 (a) Primarily consists of fuel, purchased power, other operations and maintenance expenses, taxes other than income taxes, and net income (loss) attributable to noncontrolling interests. (b) Includes accelerated depreciation related to the repowering of multiple wind facilities of $ 140 million ($ 109 million after tax) and $ 293 million ($ 228 million after tax) for the three and six months ended June 30, 2026, respectively, and $ 42 million ($ 31 million after tax, net of noncontrolling interest impacts) and $ 69 million ($ 51 million after tax, net of noncontrolling interest impacts) for the three and six months ended June 30, 2025 respectively. See Note (K) under "Southern Power – Wind Repowering Projects" and Notes 5 and 15 to the financial statements under "Depreciation and Amortization – Southern Power" and "Southern Power – Wind Repowering Projects," respectively, in Item 8 of the Form 10-K for additional information. (c) Southern Power had no earnings from equity method investments for any period presented. Southern Company Gas Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. The non-reportable segments are combined and presented as "All Other." The gas distribution operations segment is the largest component of Southern Company Gas' business and includes natural gas local distribution utilities that construct, manage, and maintain intrastate natural gas pipelines and gas distribution facilities in four states. The gas pipeline investments segment consists of joint ventures in natural gas pipeline investments including a 50 % interest in SNG and a 50 % joint ownership interest in the Dalton Pipeline. These natural gas pipelines enable the provision of diverse sources of natural gas supplies to the customers of Southern Company Gas. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information. The gas marketing services segment provides natural gas marketing to end-use customers primarily in Georgia through SouthStar. 87 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) The "All Other" presentation includes operating segments and subsidiaries that fall below the quantitative threshold for separate disclosure. Southern Company Gas' CODM utilizes segment expense information in the form of variances to budget to assess performance; therefore, Southern Company Gas has no reportable significant segment expenses. 88 Table of Contents Index to Financial Statements NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued) (UNAUDITED) Financial data for business segments for the three and six months ended June 30, 2026 and 2025 was as follows: Gas Distribution Operations Gas Pipeline Investments Gas Marketing Services Total Reportable Segments All Other Eliminations Consolidated (in millions) Three Months Ended June 30, 2026 Operating revenues $ 885 $ 8 $ 73 $ 966 $ 2 $ ( 2 ) $ 966 Other segment items (*) 496 1 54 551 5 ( 2 ) 554 Depreciation and amortization 181 1 3 185 — — 185 Earnings from equity method investments — 32 — 32 — — 32 Interest expense 90 9 1 100 1 — 101 Income taxes (benefit) 23 7 4 34 ( 2 ) — 32 Segment net income (loss) $ 95 $ 22 $ 11 $ 128 $ ( 2 ) $ — $ 126 Six Months Ended June 30, 2026 Operating revenues $ 2,785 $ 16 $ 358 $ 3,159 $ 4 $ ( 6 ) $ 3,157 Other segment items (*) 1,673 1 237 1,911 6 ( 6 ) 1,911 Depreciation and amortization 360 2 5 367 2 — 369 Earnings from equity method investments — 78 — 78 — — 78 Interest expense 181 18 2 201 5 — 206 Income taxes (benefit) 139 18 32 189 ( 13 ) — 176 Segment net income $ 432 $ 55 $ 82 $ 569 $ 4 $ — $ 573 Total assets at June 30, 2026 $ 26,244 $ 1,546 $ 1,710 $ 29,500 $ 11,265 $ ( 13,161 ) $ 27,604 Three Months Ended June 30, 2025 Operating revenues $ 885 $ 8 $ 83 $ 976 $ 5 $ ( 2 ) $ 979 Other segment items (*) 526 1 68 595 6 ( 2 ) 599 Depreciation and amortization 167 1 3 171 1 — 172 Earnings from equity method investments — 23 — 23 — — 23 Interest expense 82 9 1 92 — — 92 Income taxes 19 5 3 27 6 — 33 Segment net income (loss) $ 91 $ 15 $ 8 $ 114 $ ( 8 ) $ — $ 106 Six Months Ended June 30, 2025 Operating revenues $ 2,454 $ 16 $ 345 $ 2,815 $ 9 $ ( 6 ) $ 2,818 Other segment items (*) 1,431 3 234 1,668 8 ( 6 ) 1,670 Depreciation and amortization 330 3 7 340 1 — 341 Earnings from equity method investments — 62 — 62 — — 62 Interest expense 164 18 1 183 — — 183 Income taxes (benefit) 123 13 29 165 ( 3 ) — 162 Segment net income $ 406 $ 41 $ 74 $ 521 $ 3 $ — $ 524 Total assets at December 31, 2025 $ 25,391 $ 1,475 $ 1,749 $ 28,615 $ 10,643 $ ( 11,871 ) $ 27,387 (*) Primarily consists of cost of natural gas, other operations and maintenance expenses, taxes other than income taxes, AFUDC equity, and non-service cost-related retirement benefits income. 89 Table of Contents Index to Financial Statements Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations. Page Combined Management's Discussion and Analysis of Financial Condition and Results of Operations Overview 91 Results of Operations 93 Southern Company 93 Alabama Power 100 Georgia Power 105 Mississippi Power 110 Southern Power 114 Southern Company Gas 118 Future Earnings Potential 124 Accounting Policies 129 Financial Condition and Liquidity 129 The following Management's Discussion and Analysis of Financial Condition and Results of Operations is a combined presentation; however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants. 90 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS OVERVIEW Southern Company is a holding company that owns all of the common stock of three traditional electric operating companies (Alabama Power, Georgia Power, and Mississippi Power), Southern Power, and Southern Company Gas and owns other direct and indirect subsidiaries. The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. Southern Company's reportable segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the distribution of natural gas and sale of other complementary products and services by Southern Company Gas. Alabama Power, Georgia Power, and Mississippi Power each operate with one reportable business segment, since substantially all of their business is providing electric service to customers. Southern Power also operates its business with one reportable business segment, the sale of electricity in the competitive wholesale market. Southern Company Gas' reportable segments are gas distribution operations, gas pipeline investments, and gas marketing services. See Note (L) to the Condensed Financial Statements herein for additional information on segment reporting. For additional information on the Registrants' primary business activities, see BUSINESS – "The Southern Company System" in Item 1 of the Form 10-K. The Registrants continue to focus on several key performance indicators. For the traditional electric operating companies and Southern Company Gas, these indicators include, but are not limited to, customer satisfaction, plant availability, electric and natural gas system reliability, and execution of major construction projects. Southern Company Gas also continues to focus on several operating metrics, including customer count and volumes of natural gas sold. For Southern Power, key performance indicators include, but are not limited to, the equivalent forced outage rate and contract availability to evaluate operating results and help ensure its ability to meet its contractual commitments to customers. In addition, Southern Company and the Subsidiary Registrants focus on earnings per share and net income, respectively, as a key performance indicator. Recent Developments Alabama Power In December 2025, the Alabama PSC issued a consent order to keep retail rates stable through 2027. On April 2, 2026, the State of Alabama enacted legislation providing that retail base rates established and in place on October 1, 2026 may not be increased before January 1, 2029 for utilities that are regulated by the Alabama PSC and that provide retail electric service. The ultimate outcome of this matter cannot be determined at this time. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information. Georgia Power On May 28, 2026, the Georgia PSC approved a stipulation among Georgia Power, the staff of the Georgia PSC, and certain intervenors regarding Georgia Power's separate filings in February 2026 associated with recovery of fuel and storm restoration costs. The approved stipulation decreased annual fuel billings by 12.9 %, or approximately $ 394 million, effective June 1, 2026. Under the stipulation, the Georgia PSC approved the following related to storm restoration costs: • Recovery of $ 31 million annually for storm restoration costs incurred after December 31, 2025. • Recovery of Georgia Power's adjusted regulatory asset balance totaling $ 869 million, as determined through the proceedings and stipulation, related to storm damage as of December 31, 2025 over a period of 67 months from June 1, 2026 through December 31, 2031, or $ 156 million annually. Additionally, the stipulation provided for the treatment of the Internal Revenue Code §45U PTCs generated from Georgia Power's nuclear generating facilities in 2024 and 2025, in which Georgia Power agreed to use $ 77 million of these tax credits for the benefit of customers. See Note (B) to the Condensed Financial Statements under "Georgia Power" herein for additional information. 91 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Mississippi Power On June 18, 2026, the Mississippi PSC approved Mississippi Power's annual retail PEP Evaluation Report for 2026, resulting in an annual increase in revenues of approximately 1.8%, or $20 million, primarily due to increases in investment and depreciation. In accordance with the PEP rate schedule, the increase became effective with the first billing cycle of January 2026. In the PEP filing, the Mississippi PSC approved the use of approximately $7 million of the reliability reserve balance, which Mississippi Power utilized for reliability-related generation, transmission, and distribution expenses during the first six months of 2026. In conjunction with the PEP filing, the Mississippi PSC approved approximately $21 million associated with certain federal excess accumulated deferred income taxes resulting from the Tax Reform Legislation to be credited back to customers over an 18-month period starting with the first billing cycle of July 2026. See Note (B) to the Condensed Financial Statements under "Mississippi Power" herein for additional information. Southern Power In the first quarter 2026, Southern Power committed to development projects to upgrade certain turbines at its existing Franklin and Wansley natural gas facilities, which are projected to add up to 400 MWs of incremental capacity. Commercial operations for the incremental capacity at the natural gas facilities are projected to occur between the second quarter 2029 and the fourth quarter 2030. The ultimate outcome of these matters cannot be determined at this time. In addition, during the first six months of 2026 and subsequent to June 30, 2026, Southern Power placed in service all 200 MWs of the repowering project at the Kay wind facility. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information. At June 30, 2026, Southern Power's average investment coverage ratio for its generating assets, including those owned with various partners, based on the ratio of investment under contract to total investment using the respective facilities' net book value (or expected in-service value for facilities under construction) as the investment amount was 97% through 2030 and 88% through 2035, with an average remaining contract duration of approximately 12 years. Southern Company Gas On June 16, 2026, in connection with Nicor Gas' 2023 general base rate case proceeding, the Illinois Appellate Court determined that the Illinois Commission did not provide sufficient support for its disallowance of $ 43 million of Nicor Gas' planned capital investments that were expected to be completed by December 31, 2024. As the disallowance related to planned capital investments for which costs had not yet been incurred, it was not included in the pre-tax charge to income recorded in 2023. This matter remains subject to further proceedings before the Illinois Commission and had no impact on the current period financial statements. On July 21, 2026, Nicor Gas filed a petition for leave to appeal with the Illinois Supreme Court related to the capital structure approved in Nicor Gas' 2023 general base rate case proceeding. The Illinois Supreme Court is expected to rule on the petition on September 30, 2026. The ultimate outcome of these matters cannot be determined at this time. 92 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) RESULTS OF OPERATIONS Southern Company Net Income Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $294 33.4 $317 14.3 Consolidated net income attributable to Southern Company was $1.2 billion ($1.03 per share) in the second quarter 2026 compared to $0.9 billion ($0.80 per share) for the corresponding period in 2025. For year-to-date 2026, consolidated net income attributable to Southern Company was $2.5 billion ($2.24 per share) compared to $2.2 billion ($2.01 per share) for the corresponding period in 2025. The increases were primarily due to increases within retail electric revenues associated with sales growth, higher natural gas revenues associated with base rate increases, decreases in income taxes, and increases in AFUDC equity and earnings from equity method investments, partially offset by increases in depreciation and amortization. Also contributing to the increase in the second quarter 2026 was a decrease in interest expense. Retail Electric Revenues In the second quarter 2026, retail electric revenues were $4.75 billion compared to $4.76 billion for the corresponding period in 2025. For year-to-date 2026, retail electric revenues were $9.39 billion compared to $9.36 billion for the corresponding period in 2025. Details of the changes in retail electric revenues were as follows: Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Rates and pricing $ (10) (0.2) % $ (31) (0.3) % Sales growth 77 1.6 158 1.7 Weather (10) (0.2) (79) (0.9) Fuel and other cost recovery (70) (1.5) (21) (0.2) Retail electric revenues $ (13) (0.3) % $ 27 0.3 % Changes in rates and pricing resulted in decreases in revenues in the second quarter and year-to-date 2026 when compared to the corresponding periods in 2025 primarily due t o lower contributions from commercial and industrial customers with variable demand-driven pricing at Georgia Power, partially offset by an increase in Rate CNP Compliance revenues at Alabama Power and higher revenues associated with a tolling arrangement accounted for as a sales-type lease at Mississippi Power. Also partially offsetting the decrease in revenues for year-to-date 2026 were increases in PEP rates at Mississippi Power. See Note 2 to the financial statements under "Alabama Power – Rate CNP Compliance" and "Mississippi Power – Performance Evaluation Plan" in Item 8 of the Form 10-K for additional information. Changes in sales resulted in increases in revenues in the second quarter and year-to-date 2026 when compared to the corresponding periods in 2025. Weather-adjusted residential KWH sales decreased 0.7% in the second quarter 2026 primarily due to decreased customer usage, partially offset by customer growth. Weather-adjusted residential KWH sales increased 0.1% for year-to-date 2026 primarily due to customer growth, partially offset by decreased customer usage. Weather-adjusted commercial KWH sales increased 7.4% and 6.0% in the second quarter and year-to-date 2026, respectively, primarily due to increased customer usage, largely driven by data centers at Georgia Power. Weather-adjusted industrial KWH sales were flat in the second quarter 2026 primarily due to increases in the primary metals and miscellaneous manufacturing sectors, offset by decreases in the paper, textiles, and chemicals sectors. Weather-adjusted industrial KWH sales increased 0.7% for year-to-date 2026 primarily due to increases in the primary metals, miscellaneous manufacturing, and stone, clay, and glass sectors. 93 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Fuel and other cost recovery revenues decreased $70 million and $21 million in the second quarter and year-to-date 2026, respectively, compared to the corresponding periods in 2025 primarily due to lower recoverable fuel costs. Electric rates for the traditional electric operating companies include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of PPA costs, and do not affect net income. The traditional electric operating companies each have one or more regulatory mechanisms to recover other costs such as environmental and other compliance costs, storm damage, new plants, and PPA capacity costs. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein for additional information. Wholesale Electric Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $18 2.6 $239 16.8 In the second quarter 2026, wholesale electric revenues were $699 million compared to $681 million for the corresponding period in 2025. The increase was primarily due to an increase in energy revenues associated with a $48 million increase related to the volume of KWHs sold resulting from higher demand, partially offset by a decrease of $27 million related to the average cost per KWH sold primarily resulting from lower fuel and purchased power prices. For year-to-date 2026, wholesale electric revenues were $1.66 billion compared to $1.43 billion for the corresponding period in 2025. The increase was primarily due to an increase in energy revenues associated with an increase of $123 million related to the volume of KWHs sold resulting from higher demand and $120 million related to the average cost per KWH sold primarily resulting from higher fuel and purchased power prices. Wholesale electric revenues consist of revenues from PPAs and short-term opportunity sales. Wholesale electric revenues from PPAs (other than solar and wind PPAs) have both capacity and energy components. Capacity revenues generally represent the greatest contribution to net income and are designed to provide recovery of fixed costs plus a return on investment. Energy revenues will vary depending on fuel prices, the market prices of wholesale energy compared to the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Energy sales from solar and wind PPAs do not have a capacity charge and customers either purchase the energy output of a dedicated renewable facility through an energy charge or through a fixed price related to the energy. As a result, the ability to recover fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors. Wholesale electric revenues at Mississippi Power include FERC-regulated municipal and rural association sales under cost-based tariffs as well as market-based sales. Short-term opportunity sales are made at market-based rates that generally provide a margin above the Southern Company system's variable cost to produce the energy. Other Electric Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $22 10.0 $44 9.5 In the second quarter 2026, other electric revenues were $242 million compared to $220 million for the corresponding period in 2025. For year-to-date 2026, other electric revenues were $507 million compared to $463 million for the corresponding period in 2025. The increases in the second quarter and year-to-date 2026 were 94 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) primarily due to increases of $20 million and $37 million, respectively, in open access transmission tariff sales at the traditional electric operating companies. Natural Gas Revenues In the second quarter 2026, natural gas revenues were $966 million compared to $979 million for the corresponding period in 2025. For year-to-date 2026 , natural gas revenues were $3.16 billion compared to $2.82 billion for the corresponding period in 2025. Details of the changes in natural gas revenues were as follows: Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Rates $ 58 5.9 % $ 134 4.8 % Gas costs and other cost recovery (64) (6.5) 181 6.4 Gas marketing services (13) (1.3) 19 0.6 Other 6 0.6 5 0.2 Natural gas revenues $ (13) (1.3) % $ 339 12.0 % Changes in rates resulted in increases in revenues in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025 primarily due to base rate increases at Nicor Gas and Atlanta Gas Light. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information. Revenues associated with gas costs and other cost recovery decreased in the second quarter 2026 as compared to the corresponding period in 2025 primarily due to lower cost of natural gas driven by lower natural gas prices, as well as decreases in other expenses passed through to customers. Revenues associated with gas costs and other cost recovery increased for year-to-date 2026 as compared to the corresponding period in 2025 primarily due to higher cost of natural gas driven by higher natural gas prices in the first quarter 2026, as well as increases in other expenses passed through to customers. See "Cost of Natural Gas" herein for additional information. Revenues from gas marketing services decreased in the second quarter 2026 as compared to the corresponding period in 2025 primarily due to lower commodity prices. Revenues from gas marketing services increased for year-to-date 2026 as compared to the corresponding period in 2025 primarily due to higher commodity prices in the first quarter 2026, partially offset by weather impacts. Other Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(10) (3.0) $(23) (3.4) In the second quarter 2026, other revenues were $325 million compared to $335 million for the corresponding period in 2025. The decrease was primarily due to decreases of $12 million in unregulated sales associated with energy conservation projects at Georgia Power and $8 million in sales of unregulated products and services at Alabama Power, partially offset by an increase of $10 million in unregulated sales associated with power delivery construction and maintenance projects at Georgia Power. For year-to-date 2026, other revenues were $661 million compared to $684 million for the corresponding period in 2025. The decrease was primarily due to decreases of $30 million in unregulated sales associated with energy conservation projects at Georgia Power, $15 million in sales of unregulated products and services at Alabama Power, and $8 million in customer charges related to contributions in aid of construction included in rates in 2025 at Mississippi Power, partially offset by an increase of $24 million in unregulated sales associated with power delivery construction and maintenance projects at Georgia Power. 95 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Fuel and Purchased Power Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Fuel $ (62) (5.6) % $ 136 5.6 % Purchased power 28 10.8 22 4.3 Total fuel and purchased power expenses $ (34) $ 158 In the second quarter 2026, total fuel and purchased power expenses were $1.34 billion compared to $1.38 billion for the corresponding period in 2025. The decrease was due to a $103 million net decrease related to the average cost of fuel and purchased power, partially offset by a $69 million increase related to the volume of KWHs generated and purchased. For year-to-date 2026, total fuel and purchased power expenses were $3.1 billion compared to $2.9 billion for the corresponding period in 2025. The increase was due to a $101 million net increase related to the volume of KWHs generated and purchased and a $57 million increase related to the average cost of fuel and purchased power. Fuel and purchased power energy transactions at the traditional electric operating companies are generally offset by fuel revenues and do not have a significant impact on net income. See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information. Fuel expenses incurred under Southern Power's PPAs are generally the responsibility of the counterparties and do not significantly impact net income. Energy purchases will vary depending on demand for energy within the Southern Company system's electric service territory, the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, and the availability of the Southern Company system's generation. Details of the Southern Company system's generation and purchased power and the related costs were as follows: Second Quarter 2026 Second Quarter 2025 Year-to-Date 2026 Year-to-Date 2025 Total generation (in billions of KWHs) 48 45 95 91 Total purchased power (in billions of KWHs) 6 6 10 11 Sources of generation (percent) — Gas 51 50 51 50 Nuclear 21 18 20 19 Coal 18 19 19 19 Hydro 2 4 2 4 Wind, Solar, and Other 8 9 8 8 Cost of fuel, generated (in cents per net KWH) — Gas 2.86 3.23 3.77 3.56 Nuclear 0.79 0.88 0.79 0.86 Coal 3.41 3.77 3.49 3.90 Average cost of fuel, generated (in cents per net KWH) 2.48 2.86 3.02 3.04 Average cost of purchased power (in cents per net KWH) (*) 5.12 4.73 5.53 5.07 (*) Average cost of purchased power includes fuel purchased by the Southern Company system for tolling agreements where power is generated by the provider. 96 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Cost of Natural Gas Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(78) (30.6) $174 18.7 Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, the natural gas distribution utilities' rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from the natural gas distribution utilities. See Note 2 to the financial statements under "Southern Company Gas – Natural Gas Cost Recovery" in Item 8 of the Form 10-K for additional information. Cost of natural gas at the natural gas distribution utilities represented 87.0% and 84.7% of the total cost of natural gas in the second quarter and year-to-date 2026, respectively. In the second quarter 2026, cost of natural gas was $177 million compared to $255 million for the corresponding period in 2025. The decrease reflects lower gas cost recovery as a result of a 15.8% decrease in natural gas prices. For year-to-date 2026, cost of natural gas was $1.1 billion compared to $0.9 billion for the corresponding period in 2025. The increase reflects higher gas cost recovery, primarily in the first quarter 2026, as a result of an 11.9% increase in natural gas prices. Cost of Other Sales Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $9 5.4 $(9) (2.5) In the second quarter 2026, cost of other sales was $176 million compared to $167 million for the corresponding period in 2025. The increase was primarily due to increases of $12 million in expenses associated with unregulated power delivery construction and maintenance projects at Georgia Power and $5 million related to energy service contracts at Southern Company Gas, partially offset by a decrease of $10 million in expenses related to sales of unregulated products and services at Alabama Power. For year-to-date 2026, cost of other sales was $357 million compared to $366 million for the corresponding period in 2025. The decrease was primarily related to a decrease of $25 million in expenses at PowerSecure primarily related to distributed infrastructure and energy efficiency projects and $15 million in expenses related to sales of unregulated products and services at Alabama Power, partially offset by increases of $23 million in expenses associated with unregulated power delivery construction and maintenance projects at Georgia Power and $4 million related to energy service contracts at Southern Company Gas. Other Operations and Maintenance Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $20 1.2 $54 1.6 In the second quarter 2026, other operations and maintenance expenses were $1.71 billion compared to $1.69 billion for the corresponding period in 2025. The increase was primarily due to a $22 million increase in certain employee compensation and benefit expenses and increases of $13 million in storm damage recovery and $13 million in transmission and distribution operational costs, both at Georgia Power, partially offset by decreases of $19 million associated with utilization of the reliability reserve to offset reliability-related transmission, distribution, and generation expenses at Alabama Power and $16 million in technology infrastructure and application production costs. 97 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) For year-to-date 2026, other operations and maintenance expenses were $3.4 billion compared to $3.3 billion for the corresponding period in 2025. The increase was primarily due to a $47 million increase in certain employee compensation and benefit expenses, a $37 million increase in expenses at Southern Company Gas related to certain deferred expenses, charges related to the disallowance of certain capital investments at Nicor Gas, gas mains, and expenses passed through to customers, a $23 million increase in transmission and distribution operational costs at the traditional electric operating companies, $22 million in weather-related damage at a Southern Power solar project, and increases of $22 million in customer education and assistance expenses at Georgia Power and $18 million in NDR accruals and storm damage recovery at Alabama Power and Georgia Power. Partially offsetting the increase were decreases of $40 million associated with utilization of the reliability reserve to offset reliability-related transmission, distribution, and generation expenses at Alabama Power and $30 million in planned outages at the traditional electric operating companies, $23 million of deferred costs related to the Jurisdictional Separation Study Order at Alabama Power, $21 million associated with higher nuclear property insurance refunds at Alabama Power and Georgia Power, and a decrease of $20 million in legal expenses at Southern Company Gas. See Note (B) to the Condensed Financial Statements under "Mississippi Power – Reliability Reserve Accounting Order" and "Alabama Power – Reliability Reserve Accounting Order" herein for additional information. Also see Notes 2 and 15 to the financial statements under "Alabama Power – Jurisdictional Separation Study Order" and "Alabama Power," respectively, in Item 8 of the Form 10-K for additional information. Depreciation and Amortization Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $111 8.4 $246 9.4 In the second quarter 2026, depreciation and amortization was $1.4 billion compared to $1.3 billion for the corresponding period in 2025. For year-to-date 2026, depreciation and amortization was $2.85 billion compared to $2.61 billion for the corresponding period in 2025. The increases in the second quarter and year-to-date 2026 were primarily due to increases of $98 million and $224 million, respectively, in accelerated depreciation related to wind repowering projects at Southern Power and $102 million and $207 million, respectively, associated with additional plant in service, partially offset by a decrease of $99 million and $197 million, respectively, resulting from the extension of Georgia Power's 2022 ARP. See Note 2 to the financial statements under "Georgia Power – Rate Plans" for additional information related to Georgia Power's 2022 ARP. Also see Note (K) to the Condensed Financial Statements under "Southern Power – Wind Repowering Projects" herein and Notes 5 and 15 to the financial statements under "Depreciation and A mortization – Southern Power" and "Southern Power – Wind Repowering Projects," respectively, in Item 8 of the Form 10-K for additional information regarding Southern Power's wind repowering projects. Taxes Other Than Income Taxes Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(36) (8.9) $(17) (2.0) In the second quarter 2026, taxes other than income taxes were $367 million compared to $403 million for the corresponding period in 2025. For year-to-date 2026, taxes other than income taxes were $831 million compared to $848 million for the corresponding period in 2025. The decreases in the second quarter and year-to-date 2026 were primarily due to decreases of $37 million and $30 million, respectively, in property taxes primarily resulting from the actualization of prior-year tax assessments at Georgia Power. Partially offsetting the decrease for year-to-date 2026 were increases of $7 million in municipal franchise fees and utility license taxes at the traditional electric operating companies and $5 million in revenue taxes as a result of higher natural gas revenues at Nicor Gas. 98 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Allowance for Equity Funds Used During Construction Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $48 60.0 $95 62.1 In the second quarter 2026, allowance for equity funds used during construction was $128 million compared to $80 million for the corresponding period in 2025. For year-to-date 2026, allowance for equity funds used during construction was $248 million compared to $153 million for the corresponding period in 2025. The increases were primarily associated with an increase in capital expenditures subject to AFUDC at Georgia Power. Earnings from Equity Method Investments Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $76 N/M $93 N/M In the second quarter 2026, earnings from equity method investments were $86 million compared to $10 million for the corresponding period in 2025. For year-to-date 2026, earnings from equity method investments were $136 million compared to $43 million for the corresponding period in 2025. The increases i n the second quarter and year-to-date 2026 were primarily due to increases of $58 million and $68 million, respectively, at Southern Holdings related to gains and losses associated with investments in energy-related venture capital funds and increases of $9 million and $16 million, respectively, at Southern Company Gas related to SNG. See Note 7 to the financial statements in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements under "Southern Company" and "Southern Company Gas" herein for additional information. Interest Expense, Net of Amounts Capitalized Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(78) (8.9) $(15) (0.9) In the second quarter 2026, interest expense, net of amounts capitalized was $796 million compared to $874 million for the corresponding period in 2025. For year-to-date 2026, interest expense, net of amounts capitalized was $1.57 billion compared to $1.59 billion for the corresponding period in 2025. The decreases in the second quarter and year-to-date 2026 were primarily due to decreases of $129 million and $118 million, respectively, in losses associated with the extinguishment of debt at the parent company and increases of $17 million and $39 million, respectively, in capitalized interest and AFUDC debt primarily associated with increased capital expenditures, partially offset by increases of $65 million and $121 million, respectively, related to higher average outstanding borrowings, $11 million and $14 million, respectively, related to higher interest rates, and $7 million and $14 million, respectively, in interest associated with PPAs accounted for as finance leases at Georgia Power. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information. Other Income (Expense), Net Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $19 11.7 $26 8.4 In the second quarter 2026, other income (expense), net was $181 million compared to $162 million for the corresponding period in 2025. For year-to-date 2026, other income (expense), net was $336 million compared to 99 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) $310 million for the corresponding period in 2025. The increases in the second quarter and year-to-date 2026 were primarily due to an increase in customer charges related to contributions in aid of construction at Alabama Power. Income Taxes Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(102) (35.3) $(155) (27.2) In the second quarter 2026, income taxes were $187 million compared to $289 million for the corresponding period in 2025. For year-to-date 2026, income taxes were $414 million compared to $569 million for the corresponding period in 2025. The decreases were primarily due to decreases of $93 million and $87 million, respectively, in charges to a valuation allowance on certain state tax credit carryforwards at Georgia Power and increases of $35 million and $71 million, respectively, related to higher wind PTCs resulting from the purchase of the noncontrolling membership interest in the SP Wind tax equity partnership at Southern Power, partially offset by higher pre-tax earnings and decreases of $17 million and $29 million, respectively, in the flowback of excess state deferred income taxes at Georgia Power. See Note (G) to the Condensed Financial Statements herein and Note 15 to the financial statements under "Southern Power – Purchase of Renewable Facility Interests" in Item 8 of the Form 10-K for additional information. Net Income (Loss) Attributable to Noncontrolling Interests Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $41 N/M $87 95.6 Substantially all noncontrolling interests relate to renewable projects at Southern Power. In the second quarter 2026, net income attributable to noncontrolling interests was $14 million compared to a $27 million net loss for the corresponding period in 2025. For year-to-date 2026, net loss attributable to noncontrolling interests was $4 million compared to $91 million for the corresponding period in 2025. The changes in the second quarter and year-to-date 2026 were primarily due to $38 million and $79 million, respectively, in lower HLBV loss allocations to Southern Power's tax equity partners, largely resulting from Southern Power's purchase of the noncontrolling membership interests in the SP Wind tax equity partnership. See Note 15 to the financial statements under "Southern Power – Purchase of Renewable Facility Interests" in Item 8 of the Form 10-K for additional information. Alabama Power Net Income Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $56 14.7 $107 14.2 Alabama Power's net income in the second quarter 2026 was $437 million compared to $381 million for the corresponding period in 2025. The increase was primarily due to a decrease in other operations and maintenance expenses and an increase in other income (expense), net, partially offset by an increase in depreciation and amortization. For year-to-date 2026, net income was $862 million compared to $755 million for the corresponding period in 2025. The increase was primarily due to a decrease in other operations and maintenance expenses, an increase in other income (expense), net, and an increase within retail revenues associated with sales growth, partially offset by weather impacts and an increase in depreciation and amortization. 100 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Retail Revenues In the second quarter 2026, retail revenues were $1.71 billion compared to $1.72 billion for the corresponding period in 2025. For year-to-date 2026, retail revenues were $3.438 billion compared to $3.441 billion for the corresponding period in 2025. Details of the changes in retail revenues were as follows: Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Rates and pricing $ 11 0.6 % $ 14 0.4 % Sales growth (decline) (3) (0.2) 31 0.9 Weather (1) — (40) (1.2) Fuel and other cost recovery (15) (0.9) (8) (0.2) Retail revenues $ (8) (0.5) % $ (3) (0.1) % Changes in rates and pricing resulted in increases in revenues in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025 primarily due to an increase in Rate CNP Compliance revenues resulting from higher recoverable costs. See Note 2 to the financial statements under "Alabama Power – Rate CNP Compliance" in Item 8 of the Form 10-K for additional information. Changes in sales resulted in a decrease in revenues in the second quarter 2026 and an increase in revenues for year-to-date 2026 as compared to the corresponding periods in 2025. Weather-adjusted residential KWH sales decreased 1.3% in the second quarter 2026 primarily due to a decrease in customer usage. Weather-adjusted residential KWH sales increased 0.5% for year-to-date 2026 primarily due to customer growth. Weather-adjusted commercial KWH sales decreased 0.9% and 0.3% in the second quarter and year-to-date 2026, respectively, primarily due to decreases in customer usage. Industrial KWH sales increased 2.0% and 3.0% in the second quarter and year-to-date 2026, respectively, primarily due to increases in the primary metals and mining sectors, partially offset by decreases in the chemicals and pulp and paper sectors. Fuel and other cost recovery revenues decreased in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025 primarily as a result of lower recoverable fuel costs. Electric rates include provisions to recognize the recovery of fuel costs, purchased power costs, PPAs certificated by the Alabam a PSC, and costs associated with the NDR. Under these provisions, fuel and other cost recovery revenues generally equal fuel and other cost recovery expenses and do not affect net income. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information. Wholesale Revenues – Non-Affiliates Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(13) (13.3) $13 6.9 In the second quarter 2026, wholesale revenues from sales to non-affiliates were $85 million compared to $98 million for the corresponding period in 2025. The decrease was primarily due to a decrease in non-fuel revenues from wholesale capacity contracts. For year-to-date 2026, wholesale revenues from sales to non-affiliates were $202 million compared to $189 million for the corresponding period in 2025. The increase consisted of a $34 million increase in energy revenues due to increases of $27 million related to the volume of KWH sales associated with higher market demand and $7 million related to the average cost per KWH sold due to higher Southern Company system fuel and purchased power prices, partially offset by a $21 million decrease in non-fuel revenues from wholesale capacity contracts. The decreases in capacity revenues in the second quarter and year-to-date 2026 were primarily due to the expiration of a power sales agreement in December 2025, partially offset by the commencement of a new power sales 101 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) agreement in October 2025 associated with the acquisition of the Lindsay Hill Generating Station. See Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information. Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Alabama Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not affect net income. Short-term opportunity energy sales are also included in wholesale energy sales to non-affiliates. These opportunity sales are made at market-based rates that generally provide a margin above Alabama Power's variable cost to produce the energy. Wholesale Revenues – Affiliates Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $19 52.8 $69 65.7 In the second quarter 2026, wholesale revenues from sales to affili ates were $55 million compared to $36 million for the corresponding period in 2025. The increase was primarily due to an increase of 73.9% in the volume of KWH sales due to affiliated company energy needs, partially offset by a 10.3% decrease in the price of energy due to a decrease in natural gas prices. For year-to-date 2026, wholesale revenues from sales to affiliates were $174 million compared to $105 million for the corresponding period in 2025. The increase was primarily due to increases of 49.7% in the volume of KWH sales due to affiliated company energy needs and 11.1% in the price of energy due to an increase in natural gas prices. Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. Energy revenues related to these transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost and energy purchases are generally offset by energy revenues through Alabama Power's energy cost recovery clause. Other Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(3) (2.6) $(4) (1.6) In the second quarter 2026, other revenues were $113 million compared to $116 million for the corresponding period in 2025. For year-to-date 2026, other revenues were $241 million compared to $245 million for the corresponding period in 2025. The decreases in the second quarter and year-to-date 2026 were primarily due to decreases of $8 million and $15 million, respectively, in sales of unregulated products and services and $7 million related to undistributed customer bill credits associated with nuclear fuel disposal costs litigation in May 2025, which was offset by an additional NDR accrual within other operations and maintenance expenses, partially offset by increases of $11 million and $14 million, respectively, in open access transmission tariff sales. See Note 2 to the financial statements under "Alabama Power – Rate NDR" in Item 8 of the Form 10-K for additional information. 102 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Fuel and Purchased Power Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Fuel $ (1) (0.3) % $ 41 5.7 % Purchased power – non-affiliates 9 16.7 12 9.7 Purchased power – affiliates (14) (20.9) 5 4.1 Total fuel and purchased power expenses $ (6) $ 58 In the second quarter 2026, total fuel and purchased power expenses were $452 million compared to $458 million for the corresponding period in 2025. The decrease was due to a $34 million decrease related to the average cost of fuel and purchased power, partially offset by a $28 million net increase related to the volume of KWHs generated and purchased. F or year-to-date 2026, total fuel and purchased power expenses were $1.03 billion compared to $0.97 billion for the corresponding period in 2025. The increase was due to a $40 million net increase related to the volume of KWHs generated and purchased and an $18 million net increase related to the average cost of fuel and purchased power. Fuel and purchased power energy transactions do not have a significant impact on earnings since energy expenses are generally offset by energy revenues through Alabama Power's ene rgy cost recovery clause. See Note 2 to the financial statements under "Alabama Power – Rate ECR" in Item 8 of the Form 10-K for additional information. Energy purchases from non-affiliates will vary dep ending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Energy purchases from affiliates will vary depending on demand for energy and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance with the IIC or other contractual agreements, as approved by the FERC. Details of Alabama Power's generation and purchased power and the related costs were as follows: Second Quarter 2026 Second Quarter 2025 Year-to-Date 2026 Year-to-Date 2025 Total generation (in billions of KWHs) 15 14 31 29 Total purchased power (in billions of KWHs) 2 2 4 4 Sources of generation (percent) — Gas 41 37 37 35 Coal 29 36 32 35 Nuclear 26 16 26 20 Hydro 4 11 5 10 Cost of fuel, generated (in cents per net KWH) — Gas 2.63 3.13 3.25 3.35 Coal 3.06 3.10 3.23 3.27 Nuclear 0.74 0.78 0.73 0.73 Average cost of fuel, generated (in cents per net KWH) 2.25 2.69 2.56 2.73 Average cost of purchased power (in cents per net KWH) (*) 5.35 5.35 7.11 6.26 (*) Average cost of purchased power includes fuel, energy, and transmission purchased by Alabama Power for tolling agreements where power is generated by the provider. 103 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Other Operations and Maintenance Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(57) (12.1) $(127) (13.6) In the second quarter 2026, other operations and m aintenance expenses were $415 million compared to $472 million for the corresponding period in 2025. The decrease was primarily d ue to decreases of $19 million associated with utilization of the reliability reserve to offset reliability-related transmission, distribution, and generation expenses, $15 million in expenses related to sales of unregulated products and services, and $8 million related to the acq uisition of the Lindsay Hill Generating Station, as well as $12 million of deferred costs related to the Jurisdictional Separation Study Order. For year-to-date 2026, other operations and maintenance expenses were $808 million compared to $935 million for the corresponding period in 2025. The decrease was primarily due to decreases of $40 million associated with utilization of the reliability reserve to offset reliability-related transmission, distribution, and generation expenses, $34 million in planned outages, $18 million in expenses related to sales of unregulated products and services, $16 million related to the acquisition of the Lindsay Hill Generating Station, and $7 million associated with an additional NDR accrual in May 2025, which was offset within other revenues, as well as $23 million of deferred costs related to the Jurisdictional Separation Study Order and $11 million associated with higher nuclear property insurance refunds. Partially offsetting the decreases was a $12 million increase in NDR accruals. See Note (B) to the Condensed Financial Statements under "Alabama Power – Reliability Reserve Accounting Order" herein and Note 2 to the financial statements under "Alabama Power – Jurisdictional Separation Study Order" and " – Rate NDR" and Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information. Depreciation and Amortization Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $14 3.8 $25 3.4 In the second quarter 2026, depreciation and amortization was $385 million compared to $371 million for the corresponding period in 2025. For year-to-date 2026, depreciation and amortization was $766 million compared to $741 million for the corresponding period in 2025. The increases were primarily related to the acquisition of the Lindsay Hill Generating Station in September 2025 and other additional plant in service, partially offset by the deferral of expenses related to the Jurisdictional Separation Study Order. See Notes 2 and 15 to the financial statements under "Alabama Power – Jurisdictional Separation Study Order" and "Alabama Power," respectively, in Item 8 of the Form 10-K for additional information. Other Income (Expense), Net Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $31 66.0 $32 38.1 In the second quarter 2026, other income (expense), net was $78 million compared to $47 million for the corresponding period in 2025. For year-to-date 2026, other income (expense), net was $116 million compared to $84 million for the corresponding period in 2025. The increases were primarily due to an increase in customer charges related to contributions in aid of construction. 104 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Income Taxes Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $20 17.4 $37 16.4 In the second quarter 2026, income taxes were $135 million compared to $115 million for the corresponding period in 2025. For year-to-date 2026, income taxes were $263 million compared to $226 million for the corresponding period in 2025. The increases were primarily due to higher pre-tax earnings. Georgia Power Net Income Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $172 28.3 $204 16.9 Georgia Power's net income in the second quarter 2026 was $779 million compared to $607 million for the corresponding period in 2025. The increase was primarily due to a decrease in income taxes, higher retail revenues associated with sales growth, an increase in AFUDC equity, and a decrease in taxes other than income taxes, partially offset by lower retail revenues associated with rates and pricing and an increase in interest expense. For year-to-date 2026, net income was $1.4 billion compared to $1.2 billion for the corresponding period in 2025. The increase was primarily due to a decrease in income taxes, higher retail revenues associated with sales growth, an increase in AFUDC equity, and higher non-fuel-related wholesale revenues, partially offset by lower retail revenues associated with rates and pricing, an increase in other operations and maintenance expenses, and an increase in interest expense. Retail Revenues In the second quarter 2026, retail revenues were $2.753 billion compared to $2.765 billion for the corresponding period in 2025. For year-to-date 2026, retail revenues were $5.391 billion compared to $5.395 billion for the corresponding period in 2025. Details of the changes in retail revenues were as follows: Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Rates and pricing $ (37) (1.3) % $ (80) (1.5) % Sales growth 79 2.8 126 2.3 Weather (6) (0.2) (33) (0.6) Fuel cost recovery (48) (1.7) (17) (0.3) Retail revenues $ (12) (0.4) % $ (4) (0.1) % Changes in rates and pricing resulted in decreases in revenues in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025 primarily due to lower contributions from commercial and industrial customers with variable demand-driven pricing. Changes in sales resulted in increases in revenues in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025. Weather-adjusted residential KWH sales decreased 0.5% in the second quarter 2026 primarily due to decreased customer usage. Weather-adjusted residential KWH sales decreased 0.1% for year-to-date 2026 primarily due to decreased customer usage, largely offset by customer growth. Weather-adjusted commercial KWH sales increased 10.9% and 8.7% in the second quarter and year-to-date 2026, respectively, primarily due to increased customer usage, largely driven by data centers. Weather-adjusted industrial KWH sales 105 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) decreased 1.3% and 0.7% in the second quarter and year-to-date 2026, respectively, primarily due to decreases in the paper, textiles, and primary metals sectors, partially offset by increases in the miscellaneous manufacturing and stone, clay, and glass sectors. Fuel revenues and costs are allocated between retail and wholesale jurisdictions. Retail fuel cost recovery revenues decreased in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025 due to lower recoverable fuel costs. Electric rates include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these fuel cost recovery provisions, fuel revenues generally equal fuel expenses and do not affect net income. See Note (B) to the Condensed Financial Statements under "Georgia Power – Fuel Cost Recovery" herein and Note 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information. Wholesale Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $13 12.1 $97 38.8 In the second quarter 2026, wholesale revenues were $120 million compared to $107 million for the corresponding period in 2025. The increase was primarily due to a $15 million increase in energy revenues largely due to increases of $7 million related to the volume of KWH sales associated with higher market demand and $5 million in non-fuel-related energy revenues from wholesale contracts. For year-to-date 2026, wholesale revenues were $347 million compared to $250 million for the corresponding period in 2025. The increase was due to an $89 million increase in energy revenues due to increases of $44 million related to the average cost per KWH sold due to higher Southern Company system fuel and purchased power prices, $30 million in non-fuel-related energy revenues from wholesale contracts, and $15 million related to the volume of KWH sales associated with higher market demand, as well as an $8 million increase in capacity revenues from new and existing power sales agreements. Wholesale revenues from sales to non-affiliates consist of PPAs and short-term opportunity sales. Wholesale revenues from PPAs have both capacity and energy components. Wholesale capacity revenues from PPAs are recognized in amounts billable under the contract terms and provide for recovery of fixed costs and a return on investment. Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Georgia Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Short-term opportunity sales are made at market-based rates that generally provide a margin above Georgia Power's variable cost of energy. Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. Energy revenues related to these transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost. Other Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $22 9.2 $35 7.0 In the second quarter 2026, other revenues were $260 million compared to $238 million for the corresponding period in 2025. The increase was primarily due to increases of $10 million in unregulated sales associated with 106 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) power delivery construction and maintenance projects, $9 million in open access transmission tariff sales, $5 million in realized gains associated with price stability products for retail customers on variable demand-driven pricing tariffs, $4 million in renewable energy program revenues primarily associated with solar application fees, and $4 million in outdoor lighting sales, partially offset by a decrease of $12 million in unregulated sales associated with energy conservation projects. For year-to-date 2026, other revenues were $538 million compared to $503 million for the corresponding period in 2025. The increase was primarily due to increases of $24 million in unregulated sales associated with power delivery construction and maintenance projects, $22 million in open access transmission tariff sales, $13 million in realized gains associated with price stability products for retail customers on variable demand-driven pricing tariffs, and $10 million in outdoor lighting sales, partially offset by a decrease of $30 million in unregulated sales associated with energy conservation projects. Fuel and Purchased Power Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Fuel $ (10) (2.1) % $ 67 6.7 % Purchased power – non-affiliates (9) (5.0) (11) (3.2) Purchased power – affiliates (13) (6.6) 12 2.6 Total fuel and purchased power expenses $ (32) $ 68 In the second quarter 2026, total fuel and purchased power expenses were $821 million compared to $853 million for the corresponding period in 2025. The decrease was due to an $85 million decrease related to the average cost of fuel and purchased power, partially offset by a $53 million increase related to the volume of KWHs generated and purchased. For year-to-date 2026, total fuel and purchased power expenses were $1.9 billion compared to $1.8 billion for the corresponding period in 2025. The increase was due to an $84 million net increase related to the volume of KWHs generated and purchased, partially offset by a $16 million net decrease related to the average cost of fuel and purchased power. Fuel and purchased power energy transactions do not have a significant impact on earnings since these fuel expenses are generally offset by fuel revenues through Georgia Power's fuel cost recovery mechanism. See Note 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information. Energy purchases from non-affiliates will vary depending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Energy purchases from affiliates will vary depending on demand for energy and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance with the IIC or other contractual agreements, all as approved by the FERC. 107 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Details of Georgia Power's generation and purchased power and the related costs were as follows: Second Quarter 2026 Second Quarter 2025 Year-to-Date 2026 Year-to-Date 2025 Total generation (in billions of KWHs) 16 16 33 31 Total purchased power (in billions of KWHs) 9 9 18 18 Sources of generation (percent) — Gas 38 38 40 39 Nuclear 36 37 35 37 Coal 24 21 23 21 Hydro and other 2 4 2 3 Cost of fuel, generated (in cents per net KWH) — Gas 3.14 3.39 3.98 3.75 Nuclear 0.82 0.92 0.83 0.92 Coal 3.69 4.59 3.73 4.66 Average cost of fuel, generated (in cents per net KWH) 2.41 2.68 2.81 2.87 Average cost of purchased power (in cents per net KWH) (*) 4.67 4.97 5.30 5.11 (*) Average cost of purchased power includes fuel purchased by Georgia Power for tolling agreements where power is generated by the provider. Other Operations and Maintenance Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $22 3.4 $58 4.5 In the second quarter 2026, other operations and maintenance expenses were $667 million compared to $645 million for the corresponding period in 2025. The increase was primarily due to increases of $13 million in storm damage recovery, $13 million in transmission and distribution operational costs, $12 million in expenses associated with unregulated power delivery construction and maintenance projects, $9 million in non-outage generation maintenance expenses, and $8 million in certain employee compensation and benefit expenses, partially offset by decreases of $21 million in technology infrastructure and application production costs and $10 million in expenses associated with energy conservation projects. For year-to-date 2026, other operations and maintenance expenses were $1.34 billion compared to $1.28 billion for the corresponding period in 2025. The increase was primarily due to increases of $24 million in expenses associated with unregulated power delivery construction and maintenance projects, $22 million in customer education and assistance expenses, $17 million in transmission and distribution operational costs, $14 million in certain employee compensation and benefit expenses, $13 million in storm damage recovery, and $13 million in non-outage generation maintenance expenses, partially offset by decreases of $26 million in expenses associated with energy conservation projects and $16 million in technology infrastructure and application production costs and an increase of $10 million in nuclear property insurance refunds. See Note (B) to the Condensed Financial Statements under "Georgia Power – Storm Damage Recovery" herein for additional information. 108 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Depreciation and Amortization Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(9) (1.8) $(28) (2.8) In the second quarter 2026, depreciation and amortization was $503 million compared to $512 million for the corresponding period in 2025. For year-to-date 2026, depreciation and amortization was $0.99 billion compared to $1.02 billion for the corresponding period in 2025. The decreases in the second quarter and year-to-date 2026 were primarily due to decreases of $99 million and $197 million, respectively, resulting from the extension of the 2022 ARP, partially offset by increases of $75 million and $147 million, respectively, from additional plant in service and $12 million and $18 million, respectively, from depreciation associated with PPAs accounted for as finance leases. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements under "Georgia Power Lease Modification" herein for additional information. Taxes Other Than Income Taxes Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(35) (20.2) $(29) (8.5) In the second quarter 2026, taxes other than income taxes were $138 million compared to $173 million for the corresponding period in 2025. For year-to-date 2026, taxes other than income taxes were $313 million compared to $342 million for the corresponding period in 2025. The decreases in the second quarter and year-to-date 2026 were primarily due to decreases of $37 million and $35 million, respectively, in property taxes primarily resulting from the actualization of prior-year tax assessments. Allowance for Equity Funds Used During Construction Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $48 85.7 $97 93.3 In the second quarter 2026, allowance for equity funds used during construction was $104 million compared to $56 million for the corresponding period in 2025. For year-to-date 2026, allowance for equity funds used during construction was $201 million compared to $104 million for the corresponding period in 2025. The increases were primarily due to an increase in capital expenditures subject to AFUDC. Interest Expense, Net of Amounts Capitalized Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $30 15.2 $46 11.9 In the second quarter 2026, interest expense, net of amounts capitalized was $228 million compared to $198 million for the corresponding period in 2025. For year-to-date 2026, interest expense, net of amounts capitalized was $431 million compared to $385 million for the corresponding period in 2025. The increases for the second quarter and year-to-date 2026 were primarily associated with increases of approximately $27 million and $52 million, respectively, related to higher average outstanding borrowings and $14 million and $21 million, respectively, in interest associated with PPAs accounted for as finance leases, partially offset by increases of $13 million and $29 million, respectively, in AFUDC debt related to increased capital expenditures. See FINANCIAL CONDITION 109 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein and Note (F) to the Condensed Financial Statements under "Georgia Power Lease Modification" for additional information. Income Taxes Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(85) (36.0) $(98) (29.3) In the second quarter 2026, income taxes were $151 million compared to $236 million for the corresponding period in 2025. For year-to-date 2026, income taxes were $236 million compared to $334 million for the corresponding period in 2025. The decreases in the second quarter and year-to-date 2026 were primarily due to decreases of $93 million and $87 million, respectively, in charges to a valuation allowance on certain state tax credit carryforwards and increases of $12 million and $32 million, respectively, in amortization of federal PTCs and ITCs, partially offset by decreases of $17 million and $29 million, respectively, in the flowback of excess state deferred income taxes and higher pre-tax earnings for both periods presented. See Note (G) to the Condensed Financial Statements herein for additional information. Mississippi Power Net Income Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(7) (11.9) $(2) (1.8) Mississippi Power's net income in the second quarter 2026 was $52 million compared to $59 million for the corresponding period in 2025. For year-to-date 2026, net income was $112 million compared to $114 million for the corresponding period in 2025. The decreases were primarily due to increases in other operations and maintenance expenses and depreciation and amortization, partially offset by higher retail revenues associated with changes in rates and pricing. Retail Revenues In the second quarter 2026, retail revenues were $283 million compared to $274 million for the corresponding period in 2025. For year-to-date 2026, retail revenues were $556 million compared to $522 million for the corresponding period in 2025. Details of the changes in retail revenues were as follows: Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Rates and pricing $ 16 5.8 % $ 35 6.7 % Sales growth 2 0.8 1 0.1 Weather (3) (1.1) (6) (1.1) Fuel and other cost recovery (6) (2.2) 4 0.8 Retail revenues $ 9 3.3 % $ 34 6.5 % Changes in rates and pricing resulted in increases in revenues in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025 primarily due to increases in PEP rates and higher revenues associated with a tolling arrangement accounted for as a sales-type lease. See Note 2 to the financial statements under "Mississippi Power – Performance Evaluation Plan" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Mississippi Power – Performance Evaluation Plan" herein for additional information. 110 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Changes in sales resulted in increases in revenues in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025. Weather-adjusted residential KWH sales increased 1.3% in the second quarter 2026 primarily due to increased customer usage and customer growth. Weather-adjusted residential KWH sales decreased 0.3% for year-to-date 2026 primarily due to decreased customer usage. Weather-adjusted commercial KWH sales increased 1.8% and 1.6% in the second quarter and year-to-date 2026, respectively, primarily due to increased customer usage. Industrial KWH sale s increased 1.1% in the second quarter 2026 primarily due to increases in the petroleum and pipeline sectors, partially offset by decreases in the oil and gas extraction sectors. Industrial KWH sales decreased 0.1% for year-to-date 2026 primarily due to decreases in the chemicals and oil and gas extraction sectors, largely offset by increases in the petroleum and pipeline sectors. Fuel and other cost recovery revenues decreased in the second quarter 2026 as compared to the corresponding period in 2025 primarily as a result of lower recoverable fuel costs. Fuel and other cost recovery revenues increased for year-to-date 2026 as compared to the corresponding period in 2025 primarily as a result of higher recoverable fuel costs. Recoverable fuel costs include fuel and purchased power expenses reduced by the fuel and emissions portion of wholesale revenues from energy sold to customers outside Mississippi Power's service territory. Electric rates include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of purchased power costs, and do not affect net income. See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information. Wholesale Revenues – Non-Affiliates Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $12 19.4 $29 21.8 In the second quarter 2026, wholesale revenues from sales to non-affiliates were $74 million compared to $62 million for the corresponding period in 2025. The increase was primarily due to a $13 million increase associated with new and existing power supply agreements. For year-to-date 2026, wholesale revenues from sales to non-affiliates were $162 million compared to $133 million for the corresponding period in 2025. The increase was primarily due to a $17 million increase associated with new and existing power supply agreements and an $11 million increase in opportunity sales. Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Mississippi Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. In addition, Mississippi Power provides service under long-term contracts with rural electric cooperative associations and municipalities located in southeastern Mississippi under cost-based electric tariffs which are subject to regulation by the FERC. Short-term opportunity energy sales are also included in sales for resale to non-affiliates. These opportunity sales are made at market-based rates that generally provide a margin above Mississippi Power's variable cost to produce the energy. See Note 2 to the financial statements under "Mississippi Power – Municipal and Rural Associations Tariff" in Item 8 of the Form 10-K for additional information. 111 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Wholesale Revenues – Affiliates Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(20) (36.4) $(5) (3.7) In the second quarter 2026, wholesale revenues from sales to affiliates were $35 million compared to $55 million for the corresponding period in 2025. The decrease was primarily due to decreases of $16 million related to the volume of KWH sales and $4 million related to the price of energy driven by natural gas prices . For year-to-date 2026, wholesale revenues from sales to affiliates were $131 million compared to $136 million for the corresponding period in 2025. The decrease was primarily due to a $14 million decrease related to the volume of KWH sales, partially offset by a $10 million increase related to the price of energy driven by natural gas prices. Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC or other contractual agreements, as approved by the FERC. Energy revenues related to these transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost. Other Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $2 22.2 $(4) (13.3) For year-to-date 2026, other revenues were $26 million compared to $30 million for the corresponding period in 2025. The decrease was primarily due to an $8 million decrease in customer charges related to contributions in aid of construction included in rates in 2025, partially offset by a $4 million increase in sales of unregulated products and services. Fuel and Purchased Power Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Fuel $ (18) (14.2) % $ 12 4.3 % Purchased power (3) (18.8) 7 25.9 Total fuel and purchased power expenses $ (21) $ 19 In the second quarter 2026, total fuel and purchased power expenses were $122 million compared to $143 million for the corresponding period in 2025. The decrease was due to an $11 million decrease related to the volume of KWHs generated and purchased and a $10 million net decrease related to the average cost of fuel and purchased power. For year-to-date 2026, total fuel and purchased power expenses were $328 million compared to $309 million for the corresponding period in 2025. The increase was due to a $29 million increase related to the average cost of fuel and purchased power, of which $9 million is related to capacity, partially offset by a $10 million decrease related to the volume of KWHs generated and purchased. Fuel and purchased power energy transactions do not have a significant impact on earnings since energy expenses are generally offset by energy revenues through Mississippi Power's fuel cost recovery clause. Energy purchases will vary depending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's electric service 112 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) territory, and the availability of the Southern Company system's generation. These purchases are made in accordance with the IIC or other contractual agreements, as approved by the FERC. Details of Mississippi Power's generation and purchased power and the related costs were as follows: Second Quarter 2026 Second Quarter 2025 Year-to-Date 2026 Year-to-Date 2025 Total generation (in millions of KWHs) 3,772 3,945 8,326 8,484 Total purchased power (in millions of KWHs) 312 403 554 591 Sources of generation (percent) – Gas 94 89 94 90 Coal 6 11 6 10 Cost of fuel, generated (in cents per net KWH) – Gas 2.93 3.26 3.68 3.39 Coal 5.25 5.03 4.83 4.98 Average cost of fuel, generated (in cents per net KWH) 3.09 3.47 3.76 3.57 Average cost of purchased power (in cents per net KWH) 4.09 3.88 6.09 4.48 Other Operations and Maintenance Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $25 30.5 $28 16.9 In the second quarter 2026, other operations and maintenance expenses were $107 million compared to $82 million for the corresponding period in 2025. The increase was primarily due to increases of $10 million associated with a decrease in utilization of the reliability reserve to offset reliability-related transmission, distribution, and generation expenses, $9 million in generation expenses, and $4 million in distribution and transmission expenses. For year-to-date 2026, other operations and maintenance expenses were $194 million compared to $166 million for the corresponding period in 2025. The increase was primarily due to increases of $13 million in generation expenses, $4 million associated with a decrease in utilization of the reliability reserve to offset reliability-related transmission, distribution, and generation expenses, $4 million related to distribution expenses, and $3 million in expenses associated with unregulated products and services. See Note (B) to the Condensed Financial Statements under "Mississippi Power – Reliability Reserve Accounting Order" herein for additional information. Depreciation and Amortization Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $6 11.5 $8 7.6 In the second quarter 2026, depreciation and amortization was $58 million compared to $52 million for the corresponding period in 2025. For year-to-date 2026, depreciation and amortization was $113 million compared to $105 million for the corresponding period in 2025. The increases were primarily due to additional plant in service. 113 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Southern Power Net Income (Loss) Attributable to Southern Power Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(76) N/M $(160) N/M Net loss attributable to Southern Power in the second quarter 2026 was $25 million compared to net income of $51 million for the corresponding period in 2025. The change was primarily due to higher accelerated depreciation related to wind repowering projects. Net loss attributable to Southern Power for year-to-date 2026 was $22 million compared to net income of $138 million for the corresponding period in 2025. The change was primarily due to higher accelerated depreciation related to wind repowering projects, partially offset by higher revenues due to higher market prices and increased demand for energy related to weather impacts. See Note (K) to the Condensed Financial Statements under "Southern Power – Wind Repowering Projects" herein and Notes 5 and 15 to the financial statements under "Depreciation and Amortization – Southern Power" and "Southern Power," respectively, in Item 8 of the Form 10-K for additional information. Operating Revenues Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(11) (2.0) $103 9.3 Total operating revenues include PPA capacity revenues derived primarily from long-term contracts associated with natural gas facilities and PPA energy revenues derived from long-term contracts associated with Southern Power's generation facilities. To the extent Southern Power has capacity not contracted under a PPA, it may sell power into an accessible wholesale market, or, to the extent those generation assets are part of the FERC-approved IIC, it may sell power into the Southern Company power pool. Natural Gas Capacity and Energy Revenue Capacity revenues generally represent the greatest contribution to operating income and are designed to provide recovery of fixed costs plus a return on investment. Energy is generally sold at variable cost or is indexed to published natural gas indices. Energy revenues will vary depending on the energy demand of Southern Power's customers and their generation capacity, as well as the market prices of wholesale energy compared to the cost of Southern Power's energy. Energy revenues also include fees for support services, fuel storage, and unit start charges. Increases and decreases in energy revenues under PPAs that are driven by fuel or purchased power prices are accompanied by an increase or decrease in fuel and purchased power costs and do not have a significant impact on net income. Solar and Wind Energy Revenue Southern Power's energy sales from solar and wind generating facilities are predominantly through long-term PPAs that do not have capacity revenue. Customers either purchase the energy output of a dedicated renewable facility through an energy charge or pay a fixed price related to the energy generated from the respective facility and sold to the grid. As a result, Southern Power's ability to recover fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors. See FUTURE EARNINGS POTENTIAL – "Southern Power's Power Sales Agreements" in Item 7 of the Form 10-K for additional information regarding Southern Power's PPAs. 114 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Operating Revenues Details Details of Southern Power's operating revenues were as follows: Second Quarter 2026 Second Quarter 2025 Year-to-Date 2026 Year-to-Date 2025 (in millions) PPA capacity revenues $ 118 $ 124 $ 240 $ 246 PPA energy revenues 353 345 832 716 Total PPA revenues 471 469 1,072 962 Non-PPA revenues 60 69 136 137 Other revenues 4 8 8 14 Total operating revenues $ 535 $ 546 $ 1,216 $ 1,113 In the second quarter 2026, total operating revenues were $535 million, reflecting an $11 million, or 2.0%, decrease from the corresponding period in 2025. The change in operating revenues was primarily due to the following: • PPA capacity revenues decreased $6 million, or 4.8%, primarily due to an $18 million charge associated with a lease modification related to an affiliate PPA with Georgia Power, partially offset by an $8 million increase in capacity revenues under the PPA. • PPA energy revenues increased $8 million, or 2.3%, primarily due to a $23 million increase related to the volume of KWHs sold under natural gas PPAs and a $7 million increase in solar revenues primarily related to the first phase of the Millers Branch solar facility being placed in service, largely offset by a $24 million decrease driven by fuel and purchased power prices. See Note (K) to the Condensed Financial Statements under "Southern Power – Construction Projects" herein for additional information. • Non-PPA revenues decreased $9 million, or 13.0%, primarily due to a decrease of $8 million driven by the market price of energy. For year-to-date 2026, total operating revenues were $1.2 billion, reflecting a $103 million, or 9.3%, increase from the corresponding period in 2025. The change in operating revenues was primarily due to the following: • PPA capacity revenues decreased $6 million, or 2.4%, primarily due to an $18 million charge associated with a lease modification related to an affiliate PPA with Georgia Power, partially offset by an $8 million increase in capacity revenues under the PPA. • PPA energy revenues increased $116 million, or 16.2%, primarily due to an increase of $63 million related to the volume of KWHs sold under natural gas PPAs and an increase of $44 million driven by fuel and purchased power prices. • Other revenues decreased $6 million, or 42.9%, primarily due to a decrease in income from liquidated damages related to generation facility production guarantees and a warranty settlement in the prior year, partially offset by an increase in insurance proceeds. 115 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Fuel and Purchased Power Expenses Details of Southern Power's generation and purchased power were as follows: Second Quarter 2026 Second Quarter 2025 Year-to-Date 2026 Year-to-Date 2025 (in billions of KWHs) Generation 12.1 11.6 22.8 22.5 Purchased power 1.0 0.8 1.9 1.3 Total generation and purchased power 13.1 12.4 24.7 23.8 Total generation and purchased power (excluding solar, wind, fuel cells, and tolling agreements) 5.9 5.6 11.7 11.0 Southern Power's PPAs for natural gas generation generally provide that the purchasers are responsible for either procuring the fuel (tolling agreements) or reimbursing Southern Power for substantially all of the cost of fuel relating to the energy delivered under such PPAs. Consequently, changes in such fuel costs are generally accompanied by a corresponding change in related fuel revenues and do not have a significant impact on net income. Southern Power is responsible for the cost of fuel for generating units that are not covered under PPAs. Power from these generating units is sold into the wholesale market or into the Southern Company power pool for capacity owned directly by Southern Power. Purchased power expenses will vary depending on demand, availability, and the cost of generating resources throughout the Southern Company system and other contract resources. Load requirements are submitted to the Southern Company power pool on an hourly basis and are fulfilled with the lowest cost alternative, whether that is generation owned by Southern Power, an affiliate company, or external parties. Such purchased power costs are generally recovered through PPA revenues. Details of Southern Power's fuel and purchased power expenses were as follows: Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Fuel $ (18) (12.2) % $ 28 7.9 % Purchased power 5 16.1 35 59.3 Total fuel and purchased power expenses $ (13) $ 63 In the second quarter 2026, total fuel and purchased power expenses decreased $13 million, or 7.3%, compared to the corresponding period in 2025. Fuel expense decreased $18 million due to a $21 million decrease associated with the average cost of fuel, partially offset by a $3 million increase related to the volume of KWHs generated. Purchased power expense increased $5 million due to an increase of $9 million related to the volume of KWHs purchased, partially offset by a $4 million decrease associated with the average cost of purchased power. For year-to-date 2026, total fuel and purchased power expenses increased $63 million, or 15.2%, as compared to the corresponding period in 2025. Fuel expense increased $28 million primarily due to an increase of $27 million associated with the average cost of fuel. Purchased power expense increased $35 million due to an increase of $32 million related to the volume of KWHs purchased and an increase of $3 million associated with the average cost of purchased power. 116 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Other Operations and Maintenance Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $4 3.0 $21 8.2 For year-to-date 2026, other operations and maintenance expenses were $278 million compared to $257 million for the corresponding period in 2025. The increase was primarily due to hail damage to solar panels at the Millers Branch solar project, partially offset by a decrease in generation expenses related to planned outages. Depreciation and Amortization Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $103 58.2 $229 69.6 In the second quarter 2026, depreciation and amortization was $280 million compared to $177 million for the corresponding period in 2025. For year-to-date 2026, depreciation and amortization was $558 million compared to $329 million for the corresponding period in 2025. The increases in the second quarter and year-to-date 2026 were largely due to increases in accelerated depreciation of $98 million and $224 million, respectively, related to wind repowering projects. See Note (K) to the Condensed Financial Statements under "Southern Power – Wind Repowering Projects" herein and Notes 5 and 15 to the financial statements under "Depreciation and A mortization – Southern Power" and "Southern Power – Wind Repowering Projects," respectively, in Item 8 of the Form 10-K for additional information. Income Taxes (Benefit) Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(75) N/M $(144) N/M In the second quarter 2026, income tax benefit was $77 million compared to $2 million for the corresponding period in 2025. For year-to-date 2026, income tax benefit was $147 million compared to $3 million for the corresponding period in 2025. The increases were primarily due to higher wind PTCs resulting from Southern Power's purchase of the noncontrolling membership interests in the SP Wind tax equity partnership, as well as a change in pre-tax earnings attributable to Southern Power, including the impact of accelerated depreciation related to wind repowering projects. See Note (G) to the Condensed Financial Statements and Note (K) to the Condensed Financial Statements under "Southern Power – Wind Repowering Projects" herein and Notes 5 and 15 to the financial statements under "Depreciation and A mortization – Southern Power" and "Southern Power," respectively, in Item 8 of the Form 10-K for additional information. Net Income (Loss) Attributable to Noncontrolling Interests Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $41 N/M $87 95.6 In the second quarter 2026, net income attributable to noncontrolling interests was $14 million compared to net loss of $27 million for the corresponding period in 2025. For year-to-date 2026, net loss attributable to noncontrolling interests was $4 million compared to $91 million for the corresponding period in 2025. The changes in the second quarter and year-to-date 2026 were primarily due to $38 million and $79 million, respectively, in lower HLBV loss allocations to tax equity partners, largely resulting from Southern Power's purchase of the noncontrolling 117 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) membership interests in the SP Wind tax equity partnership. See Note 15 to the financial statements under "Southern Power – Purchase of Renewable Facility Interests" in Item 8 of the Form 10-K for additional information. Southern Company Gas Southern Company Gas uses Heating Degree Days to measure weather and the operational effects on its business. Generally, increased Heating Degree Days result in higher demand for natural gas on Southern Company Gas' distribution system. However, Southern Company Gas has various regulatory mechanisms, such as weather and revenue normalization and straight-fixed-variable rate design, which limit positive or negative impacts to income from exposure to weather changes within typical ranges in each of its utility's respective service territory. Southern Company Gas also utilizes weather hedges to limit the negative income impacts in the event of warmer-than-normal weather in Illinois and Georgia for gas marketing services. Therefore, weather typically does not have a significant net income impact. During the Heating Season, more customers are connected to the gas distribution systems and natural gas usage is higher in periods of colder weather. Southern Company Gas' base operating expenses, excluding cost of natural gas and bad debt expense, are incurred relatively evenly throughout the year. Seasonality also affects the comparison of certain balance sheet items across quarters, including receivables, unbilled revenues, natural gas for sale, and notes payable. However, these items are comparable when reviewing Southern Company Gas' annual results. Thus, Southern Company Gas' operating results for the interim periods presented are not necessarily indicative of annual results and can vary significantly from quarter to quarter as a result of seasonality. Net Income Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $20 18.9 $49 9.4 Southern Company Gas' net income in the second quarter 2026 was $126 million compared to $106 million for the corresponding period in 2025. The increase was due to a $7 million increase in net income at gas pipeline investments, a $6 million decrease in net loss at all other, a $4 million increase in net income at gas distribution operations, and a $3 million increase in net income at gas marketing services. For year-to-date 2026, net income was $573 million compared to $524 million for the corresponding period in 2025. The increase was primarily due to a $26 million increase in net income at gas distribution operations, a $14 million increase in net income at gas pipeline investments, and an $8 million increase in net income at gas marketing services. Natural Gas Revenues In the second quarter 2026, natural gas revenues were $966 million compared to $979 million for the corresponding period in 2025. For year-to-date 2026, natural gas revenues were $3.16 billion compared to $2.82 billion for the corresponding period in 2025. Details of the changes in natural gas revenues were as follows: Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) Rates $ 58 5.9 % $ 134 4.8 % Gas costs and other cost recovery (64) (6.5) 181 6.4 Gas marketing services (13) (1.3) 19 0.6 Other 6 0.6 5 0.2 Natural gas revenues $ (13) (1.3) % $ 339 12.0 % 118 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Changes in rates resulted in increases in revenues in the second quarter and year-to-date 2026 as compared to the corresponding periods in 2025 primarily due to base rate increases at Nicor Gas and Atlanta Gas Light. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information. Revenues associated with gas costs and other cost recovery decreased in the second quarter 2026 as compared to the corresponding period in 2025 primarily due to lower cost of natural gas driven by lower natural gas prices, as well as decreases in other expenses passed through to customers. Revenues associated with gas costs and other cost recovery increased for year-to-date 2026 as compared to the corresponding period in 2025 primarily due to higher cost of natural gas driven by higher natural gas prices in the first quarter 2026, as well as increases in other expenses passed through to customers. See "Cost of Natural Gas" herein for additional information. Revenues from gas marketing services decreased in the second quarter 2026 as compared to the corresponding period in 2025 primarily due to lower commodity prices. Revenues from gas marketing services increased for year-to-date 2026 as compared to the corresponding period in 2025 primarily due to higher commodity prices in the first quarter 2026, partially offset by weather impacts. Cost of Natural Gas Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(78) (30.6) $174 18.7 Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from gas distribution operations. Cost of natural gas at gas distribution operations represented 87.0% and 84.7% of the total cost of natural gas in the second quarter and year-to-date 2026, respectively. See MANAGEMENT'S DISCUSSION AND ANALYSIS – RESULTS OF OPERATIONS – "Southern Company Gas – Cost of Natural Gas" in Item 7 of the Form 10-K and "Natural Gas Revenues" herein for additional information. In the second quarter 2026, cost of natural gas was $177 million compared to $255 million for the corresponding period in 2025. The decrease reflects lower gas cost recovery as a result of a 15.8% decrease in natural gas prices. For year-to-date 2026, cost of natural gas was $1.1 billion compared to $0.9 billion for the corresponding period in 2025. The increase reflects higher gas cost recovery, primarily in the first quarter 2026, as a result of an 11.9% increase in natural gas prices. The following table details the volumes of natural gas sold during all periods presented: Second Quarter Year-to-Date 2026 2025 2026 vs. 2025 2026 2025 2026 vs. 2025 Gas distribution operations (mmBtu in millions) Firm 95 102 (6.9) % 376 403 (6.7) % Interruptible 21 20 5.0 44 43 2.3 Total 116 122 (4.9) % 420 446 (5.8) % Gas marketing services (mmBtu in millions) Firm 9 8 12.5 % 36 37 (2.7) % Interruptible large commercial and industrial 2 3 (33.3) 5 7 (28.6) Total 11 11 — % 41 44 (6.8) % 119 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Other Operations and Maintenance Expenses Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $40 13.3 $66 10.7 In the second quarter 2026, other operations and maintenance expenses were $341 million compared to $301 million for the corresponding period in 2025. The increase was primarily due to increases of $9 million in employee compensation and benefit expenses, $9 million in charges related to the disallowance of certain capital investments at Nicor Gas, $5 million in certain deferred expenses, $5 million in expenses related to energy service contracts, $4 million in certain technology infrastructure and application production costs, and $4 million in expenses for gas mains. For year-to-date 2026, other operations and maintenance expenses were $683 million compared to $617 million for the corresponding period in 2025. The increase was primarily due to increases of $30 million in employee compensation and benefit expenses, $12 million in certain deferred expenses, $11 million in charges related to the disallowance of certain capital investments at Nicor Gas, $9 million in certain technology infrastructure and application production costs, $8 million in expenses for gas mains, and $6 million in expenses passed through to customers at gas distribution operations, partially offset by a decrease of $20 million in legal expenses. Depreciation and Amortization Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $13 7.6 $28 8.2 In the second quarter 2026, depreciation and amortization was $185 million compared to $172 million for the corresponding period in 2025. For year-to-date 2026, depreciation and amortization was $369 million compared to $341 million for the corresponding period in 2025. The increases were primarily due to additional plant in service related to continued investments at the natural gas distribution utilities. Earnings from Equity Method Investments Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $9 39.1 $16 25.8 In the second quarter 2026, earnings from equity method investments were $32 million compared to $23 million for the corresponding period in 2025. The increase was primarily due to higher revenue from short-term natural gas storage and borrowing services and lower legal expenses, both at SNG. For year-to-date 2026, earnings from equity method investments were $78 million compared to $62 million for the corresponding period in 2025. The increase was primarily due to higher revenue from short-term natural gas storage and borrowing services, prior period customer refunds, and lower legal expenses, all at SNG. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information. 120 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Interest Expense, Net of Amounts Capitalized Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $9 9.8 $23 12.6 In the second quarter 2026, inte rest expense, net of amounts capitalized was $101 million compared to $92 million for the corresponding period in 2025. For year-to-date 2026, interest expense, net of amounts capitalized was $206 million compared to $183 million for the corresponding period in 2025. The increases were primarily associated with higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" herein for additional information on borrowings. Other Income (Expense), Net Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $7 38.9 $7 20.6 In the second quarter 2026, other income (expense), net was $25 million compared to $18 million for the corresponding period in 2025. For year-to-date 2026, other income (expense), net was $41 million compared to $34 million for the corresponding period in 2025. The increases were primarily due to lower non-service cost-related retirement benefits income. Income Taxes Second Quarter 2026 vs. Second Quarter 2025 Year-to-Date 2026 vs. Year-to-Date 2025 (change in millions) (% change) (change in millions) (% change) $(1) (3.0) $14 8.6 In the second quarter 2026, income taxes were $32 million compared to $33 million for the corresponding period in 2025. The decrease was primarily due to tax benefits related to certain state tax filing positions, largely offset by higher pre-tax earnings and a decrease in the flowback of excess state deferred income taxes. For year-to-date 2026 , income taxes were $176 million compared to $162 million for the corresponding period in 2025. The increase was primarily due to higher pre-tax earnings and a decrease in the flowback of excess state deferred income taxes, partially offset by tax benefits related to certain state tax filing positions. See Note (G) to the Condensed Financial Statements herein for additional information. 121 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Segment Information Operating revenues, operating expenses, and net income for each segment are provided in the table below. See Note (L) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information. 2026 2025 Operating Revenues Operating Expenses Net Income (Loss) Operating Revenues Operating Expenses Net Income (Loss) (in millions) Second Quarter Gas distribution operations $ 885 $ 695 $ 95 $ 885 $ 707 $ 91 Gas pipeline investments 8 3 22 8 2 15 Gas marketing services 73 58 11 83 71 8 All other 2 7 (2) 5 7 (8) Intercompany eliminations (2) 1 — (2) 2 — Consolidated $ 966 $ 764 $ 126 $ 979 $ 789 $ 106 Year-to-Date Gas distribution operations $ 2,785 $ 2,063 $ 432 $ 2,454 $ 1,789 $ 406 Gas pipeline investments 16 5 55 16 5 41 Gas marketing services 358 244 82 345 241 74 All other 4 10 4 9 9 3 Intercompany eliminations (6) (1) — (6) 1 — Consolidated $ 3,157 $ 2,321 $ 573 $ 2,818 $ 2,045 $ 524 Gas Distribution Operations The gas distribution operations segment is the largest component of Southern Company Gas' business and is subject to regulation and oversight by regulatory agencies in each of the states it serves. These agencies approve natural gas rates designed to provide Southern Company Gas with the opportunity to generate revenues to recover the cost of natural gas delivered to its customers and its fixed and variable costs, including depreciation, interest expense, operations and maintenance, taxes, and overhead costs, and to earn a reasonable return on its investments. With the exception of Atlanta Gas Light, Southern Company Gas' second largest utility that operates in a deregulated natural gas market and has a straight-fixed-variable rate design that minimizes the variability of its revenues based on usage, the earnings of the natural gas distribution utilities can be affected by customer usage patterns that are largely a function of price levels for natural gas and general economic conditions that may impact customers' ability to pay for service. Southern Company Gas has various regulatory and other mechanisms, such as weather and revenue normalization mechanisms, that limit its exposure to changes in customer usage, including weather changes within typical ranges in its natural gas d istribution utilities' service territories. See Note 2 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information. In the second quarter 2026, net income increased $4 million, or 4.4%, when compared to the corresponding period in 2025, as described further below: • Operating revenues were flat as lower gas cost recovery was offset by base rate increases. Gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas. 122 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) • Operating expenses decreased $12 million primarily due to a $62 million decrease in cost of natural gas as a result of lower natural gas prices compared to 2025, partially offset by a $14 million increase in depreciation primarily due to additional plant in service related to continued investments at the natural gas distribution utilities, $9 million in charges related to the disallowance of certain capital investments at Nicor Gas, a $7 million increase related to employee compensation and benefit expenses, a $6 million increase in expenses related to energy service contracts, a $5 million increase related to certain deferred expenses, and a $4 million increase in expenses for gas mains. • Interest expense, net of amounts capitalized increased $8 million primarily due to higher average outstanding borrowings. • Income taxes increased $4 million primarily as a result of higher pre-tax earnings. For year-to-date 2026, net income increased $26 million, or 6.4%, when compared to the corresponding period in 2025, as described further below: • Operating revenues increased $331 million primarily due to higher gas cost recovery and base rate increases. Gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas. • Operating expenses increased $274 million primarily due to a $177 million increase in cost of natural gas as a result of higher natural gas prices in the first quarter 2026 compared to 2025, a $30 million increase in depreciation primarily due to additional plant in service related to continued investments at the natural gas distribution utilities, a $22 million increase related to employee compensation and benefit expenses, a $12 million increase related to certain deferred expenses, and $11 million in charges related to the disallowance of certain capital investments at Nicor Gas, partially offset by a $20 million decrease in legal expenses. • Interest expense, net of amounts capitalized increased $17 million primarily due to higher average outstanding borrowings. • Income taxes increased $16 million primarily as a result of higher pre-tax earnings. Gas Pipeline Investments The gas pipeline investments segment consists primarily of joint ventures in natural gas pipeline investments including SNG and Dalton Pipeline. See Note (E) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information. In the second quarter 2026, net income increased $7 million, or 46.7%, when compared to the corresponding period in 2025. The increase was primarily due to higher revenue from short-term natural gas storage and borrowing services and lower legal expenses, both at SNG. For year-to-date 2026, net income increased $14 million, or 34.1%, when compared to the corresponding period in 2025. The increase was primarily due to higher revenue from short-term natural gas storage and borrowing services, prior period customer refunds, and lower legal expenses, all at SNG. Gas Marketing Services The gas marketing services segment provides energy-related products and services to natural gas markets and participants in customer choice programs that were approved in various states to increase competition. These programs allow customers to choose their natural gas supplier while the local distribution utility continues to provide distribution and transportation services. Gas marketing services is weather sensitive and uses a variety of hedging strategies, such as weather derivative instruments and other risk management tools, to partially mitigate potential weather impacts. For year-to-date 2026, net income increased $8 million, or 10.8%, when compared to the corresponding period in 2025. The increase was primarily due to higher retail margins, partially offset by higher operations and maintenance expenses and income taxes. 123 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) All Other All other includes a renewable natural gas business, AGL Services Company, and Southern Company Gas Capital, as well as various corporate operating expenses that are not allocated to the reportable segments and interest income (expense) associated with affiliate financing arrangements. See Note 15 to the financial statements in Item 8 of the Form 10-K for additional information. In the second quarter 2026, net loss decreased $6 million when compared to the corresponding period in 2025 primarily due to tax benefits related to certain state tax filing positions. FUTURE EARNINGS POTENTIAL Each Registrant's results of operations are not necessarily indicative of its future earnings potential. The level of the Registrants' future earnings depends on numerous factors that affect the opportunities, challenges, and risks of the Registrants' primary businesses of selling electricity and/or distributing natural gas, as described further herein. The Registrants are unable to predict changes in law, regulations, regulatory guidance, legal interpretations, policy positions, and implementation actions that may occur in the future. For the traditional electric operating companies, these factors include the ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs during a time of increasing customer affordability concerns and costs, including those related to projected long-term demand growth, stringent environmental standards, including CCR rules, safety, system reliability and resiliency, fuel, restoration following major storms, and capital expenditures, including constructing new electric generating plants, extending the retirement dates of certain fossil fuel plants, and expanding and improving the transmission and distribution systems; continued customer growth; and the trends of an uncertain inflationary environment and reduced electricity usage per customer, especially in residential and commercial markets. Earnings in the electricity business will also depend upon maintaining and growing sales and pricing of large customers such that incremental costs are met with adequate incremental revenues, considering, among other things, recent trends driving projected growth in electricity consumption including the increasing digitization of the economy and growth in data centers, an increase in industrial activity in the Southern Company system's electric service territory, and continued electrification of transportation. The traditional electric operating companies enter into large load contracts that support economic development and benefit existing customers. Since 2023, the traditional electric operating companies have contracts with new data centers and other large load customers covering approximately 11 gigawatts of electric load, with each contract individually representing a maximum electric load greater than 100 MWs, that have been reviewed by the applicable state PSC. Additional contracts totaling approximately five gigawatts of electric load have been agreed with customers and are subject to review by the applicable state PSC. The approximately 16 gigawatts of new contracts (Large Load Contracts) fully ramp up over several years after commencement of service. Some of the Large Load Contracts are currently in effect and have commenced service. Service under the remaining Large Load Contracts is expected to begin through 2028. All of the Large Load Contracts contain minimum bill provisions. Large Load Contracts totaling approximately 13 gigawatts of electric load (including substantially all signed after 2024) also contain minimum duration, termination payment requirements, and financial security requiring customers to post collateral or provide an acceptable guarantee based on the customer's credit ratings. Certain Large Load Contracts requiring construction of specifically dedicated assets contain provisions for contribution by the customer to construction costs. These terms and conditions are designed to generate adequate incremental revenues associated with incremental costs to serve these customers. These growth opportunities may be affected by a variety of factors, such as energy efficiency, changes in technology, reliability and operational factors, customer demand, and government policies, which could increase or decrease the associated pace of growth. In addition, these opportunities present risks such as capital access and cost 124 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) recovery risks. See Note 2 to the financial statements under "Georgia Power – Integrated Resource Plans" in Item 8 of the Form 10-K for additional information regarding Georgia Power's related regulatory proceedings. The level of future earnings for Southern Power's competitive wholesale electric business depends on numerous factors including the parameters of the wholesale market and the efficient operation of its wholesale generating assets; Southern Power's ability to execute its growth strategy through the development, construction, or acquisition of generating facilities and other energy projects while containing costs; regulatory matters; customer creditworthiness; total electric generating capacity available in Southern Power's market areas; Southern Power's ability to successfully remarket capacity as current contracts expire; renewable portfolio standards; continued availability of federal and state ITCs and PTCs under current and future tax legislation and U.S. Treasury guidance; transmission constraints; cost of generation from units within the Southern Company power pool; and operational limitations. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Income Tax Matters" in Item 7 of the Form 10-K for information regarding the IRA's expansion of the availability of federal ITCs and PTCs and the OBBB's restrictions on federal ITCs and PTCs. Also see Note (K) to the Condensed Financial Statements under "Southern Power" herein for information regarding construction projects. The level of future earnings for Southern Company Gas' primary business of distributing natural gas and its complementary businesses in the gas pipeline investments and gas marketing services sectors depends on numerous factors. These factors include the natural gas distribution utilities' ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs, including those related to projected long-term demand growth, safety, system reliability and resiliency, natural gas, and capital expenditures, including expanding and improving the natural gas distribution systems; the completion and subsequent operation of ongoing infrastructure and other construction projects; customer creditworthiness; and certain policies to limit the use of natural gas, such as the potential in Illinois and across certain other parts of the United States for state or municipal bans on the use of natural gas or policies designed to promote electrification. The volatility of natural gas prices has an impact on Southern Company Gas' customer rates, its long-term competitive position against other energy sources, and the ability of Southern Company Gas' gas marketing services business to capture value from locational and seasonal spreads. Additionally, changes in commodity prices, primarily driven by tight gas supplies, geopolitical events, and diminished gas production, subject a portion of Southern Company Gas' operations to earnings variability and may result in higher natural gas prices. Additional economic factors may contribute to this environment. The demand for natural gas may increase, including from large customers, which may cause natural gas prices to rise and drive higher volatility in the natural gas markets on a longer-term basis. Alternatively, a significant drop in oil and natural gas prices could lead to a consolidation of natural gas producers or reduced levels of natural gas production. Earnings for both the electricity and natural gas businesses are subject to a variety of other factors. These factors include weather; competition; developing new and maintaining existing energy contracts and associated load requirements with wholesale customers; demand growth from data centers and other large load customers and associated load and operating requirements; customer energy conservation practices; the use of alternative energy sources by customers; government incentives to reduce overall energy usage; fuel, labor, and material prices in an environment of heightened inflation and material and labor supply chain disruptions; and the price elasticity of demand. Demand for electricity and natural gas in the Registrants' service territories is primarily driven by the pace of economic growth or decline that may be affected by changes in regional and global economic conditions and could be influenced by changes in technology, public policy, utility efficiency programs, and customer behavior. Geopolitical conflicts (such as the current Middle East conflict) and significant changes in fiscal, monetary, or trade policies could affect actual economic activity and historical economic relationships in ways not anticipated in economic outlooks or Southern Company system plans. Additionally, changes in inflation, interest rates, and credit market conditions could affect the cost of doing business. All of these factors may impact future earnings. See RESULTS OF OPERATIONS herein for information on energy sales in the Southern Company system's service territory during the first six months of 2026. As part of its ongoing effort to adapt to changing market conditions, Southern Company continues to evaluate and consider a wide array of potential business strategies. These strategies may include business combinations, 125 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) partnerships, strategic alliances, joint ventures, and acquisitions involving other utility or non-utility businesses or properties, disposition of, or the sale of interests in, certain assets or businesses, internal restructuring, or some combination thereof. Furthermore, Southern Company may engage in new business ventures that arise from competitive and regulatory changes in the utility industry. Pursuit of any of the above strategies, or any combination thereof, may significantly affect the business operations, risks, and financial condition of Southern Company. In addition, Southern Power and Southern Company Gas regularly consider and evaluate joint development arrangements as well as acquisitions and/or dispositions of businesses and assets as part of their business strategies. See Note 15 to the financial statements in Item 8 of the Form 10-K, Note (K) to the Condensed Financial Statements herein, and "Construction Programs" herein for additional information. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL in Item 7 of the Form 10-K. Environmental Matters See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" and – FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" in Item 7 and Note 3 to the financial statements under "Environmental Remediation" and Note 6 to the financial statements in Item 8 of the Form 10-K, as well as Note (C) to the Condensed Financial Statements under "General Litigation Matters" and "Environmental Remediation" herein, for additional information. Environmental Laws and Regulations Water Quality On May 18, 2026, the EPA published the Unmanaged Combustion Residual Leachate (UCRL) proposed rule, which revises the UCRL requirements from the 2024 ELG Rule. The UCRL proposed rule offers a range of regulatory and technology options to address UCRL. The ultimate impacts of this proposed rule cannot be determined at this time; however, a final rule could result in significant compliance costs. Coal Combustion Residuals On April 13, 2026, the EPA published a proposed rule that, if finalized, would make several revisions to the existing federal CCR regulations, including rescinding CCR management unit provisions. The proposal also provides additional clarity around the scope of beneficial use and provides for site-specific groundwater, closure, and corrective action flexibilities under federal or state CCR permits. On July 14, 2026, the EPA proposed the approval of the State of Alabama's partial CCR permit program. If approved, the state's permit program will operate in lieu of the federal CCR program. The ultimate impact of these actions cannot be determined at this time. Based on compliance requirements for closure and monitoring of landfills and surface impoundments pursuant to state and federal CCR rules, the traditional electric operating companies have periodically updated, and expect to continue periodically updating, their related cost estimates and ARO liabilities for each CCR unit as additional information related to compliance monitoring, closure methodologies and strategies, schedules, and/or costs becomes available. Some of these updates have been, and future updates may be, material. The cost estimates for Alabama Power are based on closure-in-place for all surface impoundments. The cost estimates for Georgia Power and Mississippi Power are based on a combination of closure-in-place for some surface impoundments and closure by removal for others. Additionally, the closure designs and plans in the States of Alabama and Georgia are subject to approval by environmental regulatory agencies. Absent continued recovery of ARO costs through regulated rates, results of operations, cash flows, and financial condition for Southern Company and the traditional electric operating companies could be materially impacted. 126 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Regulatory Matters See Note 2 to the financial statements in Item 8 of the Form 10-K, OVERVIEW – "Recent Developments" herein, and Note (B) to the Condensed Financial Statements herein for a discussion of regulatory matters related to Alabama Power, Georgia Power, Mississippi Power, and Southern Company Gas, including items that could impact the applicable Registrants' future earnings, cash flows, and/or financial condition. Georgia Power On June 12, 2026, the NRC approved Southern Nuclear's subsequent license renewal application for Plant Hatch Units 1 and 2, renewing both units' operating licenses for an additional 20 years (through 2054 and 2058 for Units 1 and 2, respectively). Construction Programs The Southern Company system strategy continues to include developing and constructing new electric generating and battery energy storage facilities, expanding and improving the electric transmission and electric and natural gas distribution systems, and undertaking projects to comply with environmental laws and regulations. The traditional electric operating companies are engaged in continuous construction programs to accommodate existing and estimated future loads on their respective systems. Major generation construction projects are subject to state PSC approval in order to be included in retail rates, through which the traditional electric operating companies recover their approved investment and a return on investment. See Note 2 to the financial statements under "Georgia Power – Integrated Resource Plans" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Georgia Power – Construction" herein for information regarding Georgia Power's current construction projects. Southern Power's construction program includes the Millers Branch solar project, the Kay, Grant, Grant Plains, Wake, and Bethel wind repowering projects, and the incremental capacity upgrade projects at the Franklin and Wansley natural gas facilities. The repowering projects result in accelerated depreciation related to the equipment being replaced that will continue until the projects' completion dates, which are projected to occur through the third quarter 2027. At June 30, 2026, the remaining pre-tax accelerated depreciation is projected to total approximately $200 million in 2026 and $100 million in 2027. The ultimate impact of these matters cannot be determined at this time. See Note (K) to the Condensed Financial Statements under "Southern Power" herein and Note 5 to the financial statements under "Depreciation and Amortization – Southern Power" in Item 8 of the Form 10-K for additional information. Southern Company Gas is engaged in various infrastructure improvement programs designed to update or expand the natural gas distribution systems of the natural gas distribution utilities to improve reliability and resiliency, reduce emissions, and meet operational flexibility and growth. The natural gas distribution utilities recover their approved investment and a return on investment associated with these infrastructure programs through their regulated rates, as approved by their applicable state regulatory agency. See Note 2 to the financial statements under "Southern Company Gas – Infrastructure Replacement Programs and Capital Projects" in Item 8 of the Form 10-K for additional information on Southern Company Gas' construction program. See FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" herein for additional information regarding the Registrants' capital requirements for their construction programs. 127 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Income Tax Matters See Note (G) to the Condensed Financial Statements herein and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Income Tax Matters" in Item 7 of the Form 10-K for additional information. Federal Tax Legislation The OBBB modified certain renewable energy tax incentives and added eligibility restrictions for certain credits related to renewable facilities that are controlled or influenced by, or that receive material assistance from, a prohibited foreign entity. The U.S. Treasury issued a notice on February 12, 2026, which provides interim safe harbors related to the evaluation of material assistance from a prohibited foreign entity. Southern Company is assessing this guidance and its potential implications for eligibility of technology-neutral tax credits for renewable projects for which construction begins in 2026. The U.S. Treasury has indicated that additional guidance and regulations are expected later in 2026. The ultimate outcome of this matter cannot be determined at this time. Corporate Alternative Minimum Tax On February 18, 2026, the U.S. Treasury issued guidance regarding the calculation of the CAMT. The CAMT, enacted as part of the IRA, generally imposes a 15% minimum tax on a corporation's adjusted financial statement income (AFSI) for taxable years beginning after December 31, 2022, subject to applicable thresholds and adjustments under the Internal Revenue Code. The guidance includes provisions that, in certain circumstances, would permit taxpayers to reflect certain repair-related tax deductions as reductions to AFSI for purposes of computing CAMT. Regulated utilities industry participants have engaged with the U.S. Treasury regarding the interaction of repair-related costs, regulatory accounting, and the CAMT framework. Southern Company is evaluating the guidance, including its applicability to Southern Company's specific facts and circumstances. If applicable, the guidance could reduce Southern Company's potential CAMT exposure by permitting the inclusion of certain repair-related deductions in the computation of AFSI, which could affect Southern Company's income taxes and cash tax position in future periods. Southern Company will continue to assess the impact of the guidance and any further administrative guidance or regulatory developments. Georgia State Tax Legislation On May 11, 2026, the State of Georgia enacted tax legislation that reduced the corporate income tax rate from 5.19% to 4.99% effective for the 2026 tax year. This legislation reduced the amount of Southern Company's and certain subsidiaries' income taxes in the State of Georgia and existing state net accumulated deferred tax liabilities and increased regulatory liabilities at Georgia Power and Southern Company Gas. The legislation is not expected to have a material impact on the net income of the applicable Registrants in 2026. General Litigation and Other Matters The Registrants are involved in various matters being litigated and/or regulatory and other matters that could affect future earnings, cash flows, and/or financial condition. The ultimate outcome of such pending or potential litigation against each Registrant and any subsidiaries or regulatory and other matters cannot be determined at this time; however, for current proceedings and/or matters not specifically reported herein or in Notes (B) and (C) to the Condensed Financial Statements herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings and/or matters would have a material effect on such Registrant's financial statements. See Notes (B) and (C) to the Condensed Financial Statements for a discussion of various contingencies, including matters being litigated, regulatory matters, and other matters which may affect future earnings potential. 128 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) ACCOUNTING POLICIES See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES in Item 7 of the Form 10-K for a complete discussion of the Registrants' critical accounting policies and estimates, as well as recently issued accounting standards. Application of Critical Accounting Policies and Estimates The Registrants prepare their financial statements in accordance with GAAP. Significant accounting policies are described in the notes to the financial statements in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on the Registrants' results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. FINANCIAL CONDITION AND LIQUIDITY Overview See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" in Item 7 of the Form 10-K for additional information. The financial condition of each Registrant remained stable at June 30, 2026. The Registrants intend to continue to monitor their access to short-term and long-term capital markets as well as their bank credit arrangements to meet future capital and liquidity needs. See "Cash Requirements," "Sources of Capital," and "Financing Activities" herein for additional information. At the end of the second quarter 2026, the market price of Southern Company's common stock was $95.71 per share (based on the closing price as reported on the NYSE) and the book value was $34.40 per share, representing a market-to-book ratio of 278%, compared to $87.20, $32.18, and 271%, respectively, at the end of 2025. Southern Company's common stock dividend for the second quarter 2026 was $0.76 per share compared to $0.74 per share in the second quarter 2025. Cash Requirements See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" in Item 7 of the Form 10-K for a description of the Registrants' significant cash requirements. The Registrants' significant cash requirements include estimated capital expenditures associated with their construction programs. The construction programs are subject to periodic review and revision, and actual construction costs may vary from these estimates because of numerous factors. These factors include: changes in business conditions; changes in load projections; changes in environmental laws and regulations; the outcome of any legal challenges to environmental rules; changes in electric generating plants, including unit retirements and replacements and adding or changing fuel sources at existing electric generating units or extending the retirement dates of certain generating plants, to meet regulatory requirements; changes in FERC rules and regulations; state regulatory agency approvals; changes in the expected environmental compliance program; changes in legislation, regulation, and/or tariff policy; the cost, availability, and efficiency of construction labor, equipment, and materials; project scope and design changes; abnormal weather; delays in construction due to public or political considerations or judicial or regulatory action; storm impacts; and the cost of capital. In addition, with respect to the traditional electric operating companies and the natural gas distribution utilities, there can be no assurance that any costs related to capital expenditures and AROs will be fully recovered. Additionally, expenditures associated with Southern Power's planned acquisitions may vary due to market opportunities and the execution of its growth strategy. In the first quarter 2026, Southern Power committed to development projects to upgrade certain turbines at the Franklin and Wansley natural gas facilities. The remaining aggregate construction costs for these projects are expected to be between $580 million and $645 million. See Note (K) to the Condensed Financial Statements under "Southern Power – Natural Gas Turbine Upgrade Projects" herein for additional information regarding Southern Power's construction projects. 129 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Long-term debt maturities and the interest payable on long-term debt each represent a significant cash requirement for the Registrants. See "Financing Activities" herein for information on changes in the Registrants' long-term debt balances since December 31, 2025. Fuel and purchased power costs represent a significant component of funding ongoing operations for the traditional electric operating companies and Southern Power. Fuel costs include purchases of coal (for the traditional electric operating companies) and natural gas (for the traditional electric operating companies and Southern Power), as well as the related transportation and storage. Since December 31, 2025, Alabama Power and Georgia Power have entered into additional commitments for natural gas primarily related to Alabama Power's conversion of Plant Barry Unit 5 from coal to natural gas and Georgia Power's ongoing construction of generation projects. Total estimated costs for these additional fuel commitments at June 30, 2026 are provided in the table below. See Note (B) to the Condensed Financial Statements under "Georgia Power – Construction" herein and Note 2 to the financial statements under "Alabama Power – Environmental Accounting Order" in Item 8 of the Form 10-K for additional information. 2027 2028 2029 2030 Thereafter (in millions) Southern Company $ 136 $ 762 $ 751 $ 751 $ 6,571 Alabama Power — 21 27 27 335 Georgia Power 136 741 724 724 6,236 Sources of Capital See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" in Item 7 of the Form 10-K for additional information. Southern Company intends to meet its future capital needs through operating cash flows, borrowings from financial institutions, and debt, hybrid, and/or equity issuances. Equity capital can be provided from any combination of Southern Company's stock plans, private placements, or public offerings. The Subsidiary Registrants plan to obtain the funds to meet their future capital needs from sources similar to those they used in the past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity contributions from Southern Company. In addition, Alabama Power and Georgia Power plan to utilize borrowings from the FFB. Operating cash flows provide a substantial portion of the Registrants' cash needs. See Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information. The amount, type, and timing of any financings in 2026, as well as in subsequent years, will be contingent on investment opportunities and the Registrants' capital requirements and will depend upon prevailing market conditions, regulatory approvals (for certain of the Subsidiary Registrants), and other factors. See "Cash Requirements" and "Financing Activities" herein for additional information. By regulation, Nicor Gas is restricted, up to its retained earnings balance, in the amount it can dividend or loan to affiliates and is not permitted to make money pool loans to affiliates. At June 30, 2026, the amount of subsidiary retained earnings restricted to dividend totaled $2.0 billion. This restriction did not impact Southern Company Gas' ability to meet its cash obligations, nor does management expect such restriction to materially impact Southern Company Gas' ability to meet its currently anticipated cash obligations. Certain Registrants' current liabilities frequently exceed their current assets because of long-term debt maturities and the periodic use of short-term debt as a funding source, as well as significant seasonal fluctuations in cash 130 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) needs. The Registrants generally plan to refinance long-term debt as it matures. The following table shows the amount by which current liabilities exceeded current assets at June 30, 2026 for the applicable Registrants: At June 30, 2026 Southern Company Georgia Power Mississippi Power Southern Company Gas (in millions) Current liabilities in excess of current assets $ 3,356 $ 1,870 $ 109 $ 457 The Registrants believe the need for working capital can be adequately met by utilizing operating cash flows, as well as commercial paper, lines of credit, and short-term bank notes, as market conditions permit. In addition, under certain circumstances, the Subsidiary Registrants may utilize equity contributions and/or loans from Southern Company. Bank Credit Arrangements At June 30, 2026, unused committed credit arrangements with banks were as follows: At June 30, 2026 Southern Company parent Alabama Power (a) Georgia Power (b) Mississippi Power Southern Power (c) Southern Company Gas (d) SEGCO Southern Company (in millions) Unused committed credit $ 2,999 $ 1,365 $ 2,042 $ 275 $ 600 $ 1,598 $ 30 $ 8,909 (a) Includes $15 million at Alabama Property Company, a wholly-owned subsidiary of Alabama Power. Alabama Power is not party to this arrangement. (b) Georgia Power had $26 million of letters of credit outstanding under an uncommitted letter of credit facility at June 30, 2026. (c) At June 30, 2026, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $21 million was unused. In addition, Southern Power Company had $23 million of letters of credit outstanding under an uncommitted letter of credit facility at June 30, 2026. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities. (d) Includes $798 million and $800 million at Southern Company Gas Capital and Nicor Gas, respectively. Subject to applicable market conditions, the Registrants, Nicor Gas, and SEGCO expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, the Registrants, Nicor Gas, and SEGCO may extend the maturity dates and/or increase or decrease the lending commitments thereunder. A portion of the unused credit with banks is allocated to provide liquidity support to certain revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. At June 30, 2026, outstanding variable rate demand revenue bonds of the traditional electric operating companies with allocated liquidity support totaled approximately $1.5 billion (comprised of approximately $796 million at Alabama Power, $667 million at Georgia Power, and $58 million at Mississippi Power). In addition, at June 30, 2026, Georgia Power had approximately $210 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months. Variable rate demand revenue bonds and fixed rate revenue bonds required to be remarketed within the next 12 months are classified as long-term debt on the balance sheets as a result of available long-term committed credit. See Note 8 to the financial statements in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements under "Bank Credit Arrangements" herein for additional information. Short-term Borrowings The Registrants, Nicor Gas, and SEGCO make short-term borrowings primarily through commercial paper programs that have the liquidity support of the committed bank credit arrangements described above. Southern Power's subsidiaries are not issuers or obligors under its commercial paper program. Commercial paper and short- 131 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) term bank term loans are included in notes payable in the balance sheets. Details of the Registrants' short-term borrowings were as follows: Short-term Debt at June 30, 2026 Short-term Debt During the Period (*) Amount Outstanding Weighted Average Interest Rate Average Amount Outstanding Weighted Average Interest Rate Maximum Amount Outstanding (in millions) (in millions) (in millions) Southern Company $ 2,132 4.0 % $ 1,677 4.0 % $ 2,843 Alabama Power — — 20 3.8 100 Georgia Power 230 4.0 290 4.0 937 Mississippi Power 38 4.0 34 3.9 66 Southern Power — — 150 4.0 316 Southern Company Gas: Southern Company Gas Capital 235 4.0 192 4.0 291 (*) Average and maximum amounts are based upon daily balances during the three-month period ended June 30, 2026. Analysis of Cash Flows Net cash flows provided from (used for) operating, investing, and financing activities for the six months ended June 30, 2026 and 2025 are presented in the following table: Net cash provided from (used for): Southern Company Alabama Power Georgia Power Mississippi Power Southern Power Southern Company Gas (in millions) Six Months Ended June 30, 2026 Operating activities $ 4,280 $ 1,078 $ 1,577 $ 93 $ 449 $ 1,508 Investing activities (6,758) (878) (4,312) (209) (417) (889) Financing activities 3,828 (364) 2,748 112 141 (416) Six Months Ended June 30, 2025 Operating activities $ 3,431 $ 678 $ 1,335 $ 78 $ 232 $ 1,210 Investing activities (5,734) (1,169) (3,218) (145) (418) (735) Financing activities 2,467 300 1,859 76 161 (294) Fluctuations in cash flows from financing activities vary from year to year based on capital needs and the maturity or redemption of securities. Southern Company Net cash provided from operating activities increased $849 million for the six months ended June 30, 2026 as compared to the corresponding period in 2025 primarily due to higher net income after non-cash adjustments, the timing of vendor payments and customer receivable collections, and customer refunds in 2025 associated with a nuclear fuel disposal cost award at Alabama Power, partially offset by the timing of materials and supplies purchases. See Note 3 to the financial statements under "Nuclear Fuel Disposal Costs" in Item 8 of the Form 10-K for additional information. The net cash used for investing activities for the six months ended June 30, 2026 was primarily related to the Subsidiary Registrants' construction programs. 132 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) The net cash provided from financing activities for the six months ended June 30, 2026 was primarily related to issuances of common stock through the settlement of forward sale contracts, net issuances of long-term debt, and an increase in notes payable, partially offset by common stock dividend payments. See Note (F) to the Condensed Financial Statements under "Equity Distribution Agreement" herein for additional information. Alabama Power Net cash provided from operating activities increased $400 million for the six months ended June 30, 2026 as compared to the corresponding period in 2025 primarily due to customer refunds in 2025 associated with a nuclear fuel disposal cost award, timing of accounts receivables collections, and monetization of §45U PTCs in 2025. See Note 3 to the financial statements under "Nuclear Fuel Disposal Costs" in Item 8 of the Form 10-K for additional information. The net cash used for investing activities for the six months ended June 30, 2026 was primarily related to gross property additions, partially offset by contributions in aid of construction. The net ca sh used for finan cing activities for the six months ended June 30, 2026 was primarily related to common stock dividend payments, partially offset by capital contributions from Southern Company. Georgia Power Net cash provided from operating activities increased $242 million for the six months ended June 30, 2026 as compared to the corresponding period in 2025 primarily due to the timing of vendor payments, partially offset by the timing of materials and supplies purchases. The net cash used for investing activities for the six months ended June 30, 2026 was primarily related to gross property additions. The net cash provided from financing activities for the six months ended June 30, 2026 was primarily related to capital contributions from Southern Company, net issuances of senior notes, and net borrowings from the FFB, partially offset by common stock dividend payments and the repayment of bank loans. See Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information. Mississippi Power N et cas h provided from operating activities increased $15 million for the six months ended June 30, 2026 as compared to the corresponding period in 2025 primarily due to increased fuel cost recovery and the timing of customer receivable collections, partially offset by the timing of fossil fuel stock purchases. The net cash used for investing activities for the six months ended June 30, 2026 was primarily related to gross property additions. The net cash provided from financing activities for the six months ended June 30, 2026 was primarily related to capital contributions from Southern Company, the issuance of senior notes, and an increase in commercial paper borrowings, partially offset by common stock dividend payments. Southern Power Net cash provided from operating activities increased $217 million for the six months ended June 30, 2026 as compared to the corresponding period in 2025 primarily due to an increase in the utilization of federal tax credit carryforwards, an increase in wholesale revenues driven by higher market prices of energy, and the timing of customer receivable collections. The net cash used for investing activities for the six months ended June 30, 2026 was primarily related to ongoing construction activities. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information. The net cash provided from financing activities for the six months ended June 30, 2026 was primarily related to an issuance of senior notes and capital contributions from Southern Company, partially offset by the repayment of 133 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) senior notes at maturity, common stock dividend payments, a reduction in commercial paper borrowings, and net distributions to noncontrolling interests. Southern Co mpany Gas Net cash provided from operating activities increased $298 million for the six months ended June 30, 2026 as compared to the corresponding period in 2025 primarily due to increased customer billings, the timing of customer receivable collections, and higher natural gas cost recovery as a result of higher natural gas prices, partially offset by higher volumes of natural gas purchases and the timing of payments for natural gas. The net cash used for investing activities for the six months ended June 30, 2026 was primarily related to construction of transmission and distribution assets recovered through base rates. The net cash used for financing activities for the six months ended June 30, 2026 was primarily related to maturities of long-term debt, common stock dividend payments, and a reduction in commercial paper borrowings, partially offset by the issuance of junior subordinated notes. Significant Balance Sheet Changes Southern Company Significant balance sheet changes for the six months ended June 30, 2026 included: • an increase of $4.0 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants' construction programs; • an increase of $3.5 billion in total stockholders' equity primarily related to issuances of common stock largely through the settlement of forward sale contracts and net income, partially offset by common stock dividend payments; • an increase of $1.6 billion in long-term debt (including securities due within one year) primarily due to net issuances of junior subordinated notes and senior notes and borrowings from the FFB, partially offset by the repayment of bank loans; • an increase of $1.4 billion in notes payable primarily due to an increase in commercial paper borrowings; and • an increase of $1.3 billion in cash and cash equivalents, as reflected in the statements of cash flows and discussed further under "Analysis of Cash Flows – Southern Company" herein. See "Financing Activities" and Note (F) to the Condensed Financial Statements under "Equity Distribution Agreement" and "DOE Loan Guarantee Borrowings" herein for additional information. Alabama Power Significant balance sheet changes for the six months ended June 30, 2026 included: • an increase of $537 million in common stockholder's equity primarily due to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company; • an increase of $261 million in other deferred credits and liabilities primarily due to contributions in aid of construction funds to be used for the construction of generation, transmission, and distribution facilities; and • an increase of $255 million in total property, plant, and equipment primarily related to the construction of transmission and distribution facilities. Georgia Power Significant balance sheet changes for the six months ended June 30, 2026 included: • an increase of $4.8 billion in total property, plant, and equipment primarily related to the construction of generation, transmission, and distribution facilities; • an increase of $2.9 billion in long-term debt (including securities due within one year) primarily due to net borrowings from the FFB and net issuances of senior notes, partially offset by the repayment of bank loans; and 134 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) • an increase of $2.6 billion in common stockholder's equity primarily due to capital contributions from Southern Company and net income, partially offset by dividends paid to Southern Company. See "Financing Activities – Georgia Power" and Notes (B) and (F) to the Condensed Financial Statements under "Georgia Power – Construction" and "DOE Loan Guarantee Borrowings," respectively, herein for additional information. Mississippi Power Significant balance sheet changes for the six months ended June 30, 2026 included: • an increase of $113 million in common stockholder's equity related to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company; • an increase of $75 million in long-term debt (including securities due within one year) primarily due to the issuance of senior notes; • a decrease of $55 million in accrued taxes primarily due to the payment of ad valorem taxes; • a decrease of $40 million in other deferred credits and liabilities primarily due to contributions in aid of construction funds used for the construction of transmission and distribution facilities; and • an increase of $38 million in notes payable primarily due to an increase in commercial paper borrowings. See "Financing Activities – Mississippi Power" herein for additional information. Southern Power Significant balance sheet changes for the six months ended June 30, 2026 included: • an increase of $221 million in total stockholders' equity primarily due to capital contributions from Southern Company, partially offset by dividends paid to Southern Company, net distributions to noncontrolling interests, and net loss; • a decrease of $181 million in total property, plant, and equipment primarily due to the continued depreciation of assets, partially offset by the continued construction of the wind repowering and the natural gas turbine upgrade projects; • an increase of $173 million in cash and cash equivalents, as reflected in the statements of cash flows and discussed further under "Analysis of Cash Flows – Southern Power" herein; and • a decrease of $138 million in notes payable due to a reduction in commercial paper borrowings. See Note (K) to the Condensed Financial Statements under "Southern Power" herein and Note 15 to the financial statements under "Southern Power – Purchase of Renewable Facility Interests" in Item 8 of the Form 10-K for additional information. Southern Company Gas Significant balance sheet changes for the six months ended June 30, 2026 included: • an increase of $518 million in total property, plant, and equipment primarily due to the construction of transmission and distribution assets; • a decrease of $416 million in total accounts receivable primarily due to lower customer billings resulting from lower natural gas volumes and prices, partially offset by base rate increases; • an increase of $314 million in common stockholder's equity primarily due to net income, partially offset by dividends paid to Southern Company; • an increase of $199 million in cash and cash equivalents, as reflected in the statements of cash flows and discussed further under "Analysis of Cash Flows – Southern Company Gas" herein; • a decrease of $198 million in natural gas for sale primarily due to seasonality; and • a decrease of $190 million in notes payable due to a reduction in commercial paper borrowings. 135 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Financing Activities The following table outlines long-term debt financing activities for the first six months of 2026: Issuances and Reofferings Maturities and Redemptions Company Senior Notes Other Long- Term Debt Senior Notes Other Long- Term Debt (a) (in millions) Southern Company parent $ — $ 1,300 $ — $ 1,250 Alabama Power — — — 47 Georgia Power 1,300 1,016 325 450 Mississippi Power 75 — — 1 Southern Power 600 — 564 — Southern Company Gas — 500 350 100 Other — — — 1 Elimination (b) — — — (3) Southern Company $ 1,975 $ 2,816 $ 1,239 $ 1,846 (a) Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization payments totaling $43 million for FFB borrowings. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for additional information. (b) Represents reductions in affiliate finance lease obligations at Georgia Power, which are eliminated in Southern Company's consolidated financial statements. Except as otherwise described herein, the Registrants used the proceeds of debt issuances for their redemptions and maturities shown in the table above, to repay short-term indebtedness, and for general corporate purposes, including working capital. The Subsidiary Registrants also used the proceeds for their construction programs. In addition to any financings that may be necessary to meet capital requirements and contractual obligations, the Registrants plan to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit. Southern Company During the first six months of 2026, Southern Company issued approximately 31.1 million shares of common stock primarily through forward sale contract settlements and employee equity compensation plans. Proceeds from settlements of the forward sale contracts totaled approximately $2.5 billion. Also during the first six months of 2026, Southern Company entered into additional forward sale contracts for the issuance of shares of common stock that may be settled through June 2028. See Note (F) to the Condensed Financial Statements under "Equity Distribution Agreement" herein for additional information. In January 2026, Southern Company redeemed all $1.25 billion aggregate principal amount of its Series 2020B 4.00% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due January 15, 2051. In January 2026, Southern Company borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a floating rate, which was repaid in June 2026. In March 2026, Southern Company issued $1.3 billion aggregate principal amount of Series 2026A 6.00% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due April 1, 2058. Subsequent to June 30, 2026, Southern Company repaid at maturity $1.75 billion aggregate principal amount of its Series 2016E 3.25% Senior Notes. Also subsequent to June 30, 2026, Southern Company borrowed $200 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a floating rate. 136 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Alabama Power In March 2026, Alabama Power repaid at maturity its three bank term loan agreements with an aggregate principal amount of $45 million. Georgia Power In February 2026, Georgia Power borrowed $250 million pursuant to a short-term uncommitted bank credit arrangement which is payable on demand, following specified notice by the bank, and bears interest at a rate agreed upon by Georgia Power and the bank from time to time. In March 2026, April 2026, and May 2026, Georgia Power repaid the short-term uncommitted bank credit arrangement in installments of $50 million, $50 million, and $150 million, respectively. In March 2026, Georgia Power made initial borrowings under a multi-advance term loan facility with the FFB in an aggregate principal amount of approximately $1.0 billion at an interest rate of 5.041% through the final maturity date of December 10, 2055. The proceeds were used to reimburse Georgia Power for eligible costs relating to certain generation, battery energy storage, and transmission facilities. See Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information. In April 2026, Georgia Power repaid at maturity $325 million aggregate principal amount of its Series 2016A 3.25% Senior Notes. In May 2026, Georgia Power issued $150 million aggregate principal amount of additional Series 2025B 4.85% Senior Notes due March 15, 2031, $600 million aggregate principal amount of Series 2026A Floating Rate Senior Notes due November 22, 2027, and $550 million aggregate principal amount of Series 2026B 4.60% Senior Notes due June 15, 2029. In June 2026, Georgia Power repaid at maturity both of its long-term floating rate bank loans totaling $400 million. Mississippi Power In March 2026, Mississippi Power issued approximately $75 million aggregate principal amount of Series 2026A Floating Rate Senior Notes due May 15, 2076. Subsequent to June 30, 2026, Mississippi Power repaid at maturity $65 million aggregate principal amount of its Series 2023A 5.64% Senior Notes. Southern Power In June 2026, Southern Power issued $600 million aggregate principal amount of Series 2026A 4.80% Senior Notes due June 15, 2031. Also in June 2026, Southern Power repaid at maturity €500 million (approximately $564 million) aggregate principal amount of its Series 2016B 1.85% Senior Notes. Southern Company Gas In May 2026, Southern Company Gas Capital issued $500 million aggregate principal amount of Series 2026A 6.05% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due September 15, 2056, guaranteed by Southern Company Gas. In June 2026, Southern Company Gas Capital repaid at maturity $350 million aggregate principal amount of its 3.250% Senior Notes. Also in June 2026, Nicor Gas repaid at maturity $100 million aggregate principal amount of its 2.66% Series First Mortgage Bonds. 137 Table of Contents Index to Financial Statements MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (Continued) Credit Rating Risk At June 30, 2026, the Registrants did not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change of certain Registrants to BBB and/or Baa2 or below. These contracts are primarily for physical electricity and natural gas purchases and sales, fuel purchases, fuel transportation and storage, energy price risk management, transmission, interest rate management, and equipment purchases related to construction of facilities. The maximum potential collateral requirements under these contracts at June 30, 2026 were as follows: Credit Ratings Southern Company (*) Alabama Power Georgia Power Mississippi Power Southern Power (*) Southern Company Gas (in millions) At BBB and/or Baa2 $ 32 $ 1 $ — $ — $ 31 $ — At BBB- and/or Baa3 459 2 36 — 420 — At BB+ and/or Ba1 or below 3,723 382 2,430 287 1,422 32 (*) Southern Power has PPAs that could require collateral, but not accelerated payment, in the event of a downgrade of Southern Power's credit. The PPAs require credit assurances without stating a specific credit rating. The amount of collateral required would depend upon actual losses resulting from a credit downgrade. Southern Power had $106 million of cash collateral posted related to PPA requirements at June 30, 2026. The amounts in the previous table for the traditional electric operating companies and Southern Power include certain agreements that could require collateral if either Alabama Power or Georgia Power has a credit rating change to below investment grade. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. Additionally, a credit rating downgrade could impact the ability of the Registrants to access capital markets and would be likely to impact the cost at which they do so. 138 Table of Contents Index to Financial Statements Item 3. Quantitative and Qualitative Disclosures About Market Risk. During the six months ended June 30, 2026, there were no material changes to Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' disclosures about market risk. For an in-depth discussion of each Registrant's market risks, see MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Market Price Risk" in Item 7 of the Form 10-K and Note 1 to the financial statements under "Financial Instruments" and Notes 13 and 14 to the financial statements in Item 8 of the Form 10-K, as well as Notes (I) and (J) to the Condensed Financial Statements herein. Item 4. Controls and Procedures. (a) Evaluation of disclosure controls and procedures. As of the end of the period covered by this Quarterly Report on Form 10-Q, Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas conducted separate evaluations under the supervision and with the participation of each company's management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended). Based upon these evaluations, the Chief Executive Officer and the Chief Financial Officer, in each case, concluded that the disclosure controls and procedures are effective. (b) Changes in internal control over financial reporting. There have been no changes in Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended) during the second quarter 2026 that have materially affected or are reasonably likely to materially affect Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' internal control over financial reporting. 139 Table of Contents Index to Financial Statements PART II — OTHER INFORMATION Item 1. Legal Proceedings. See the Notes to the Condensed Financial Statements herein for information regarding certain legal and administrative proceedings in which the Registrants are involved. The Registrants' threshold for disclosing material environmental legal proceedings involving a governmental authority where potential monetary sanctions are involved is $1 million. Item 1A. Risk Factors. See RISK FACTORS in Item 1A of the Form 10-K for a discussion of the risk factors of the Registrants. There have been no material changes to these risk factors from those previously disclosed in the Form 10-K. Item 5. Other Information. The following table reports information regarding the adoption of "Rule 10b5-1 trading arrangements" or "non-Rule 10b5-1 trading arrangements," as defined in Item 408(a) of Regulation S-K,