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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, 2025

☐ 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)

Ten Peachtree Place, N.E.

Atlanta, Georgia 30309

(404) 584-4000

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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 $5 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
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

Alabama Power Company

Georgia Power Company

Mississippi Power Company

Southern Power Company

Southern Company Gas

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, 2025
The Southern Company	Par Value $5 Per Share	1,100,047,407
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.

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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	93
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	143
Item 4.	Controls and Procedures	143

	PART II—OTHER INFORMATION

Item 1.	Legal Proceedings	144
Item 1A.	Risk Factors	144
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	144
Item 6.	Exhibits	144

	Signatures	147

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DEFINITIONS


Term			Meaning
2022 ARP			Alternate Rate Plan approved by the Georgia PSC in 2022 for Georgia Power for the years 2023 through 2025
2023 IRP Update			Georgia Power's updated IRP filed in 2023 and approved by the Georgia PSC in April 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 May 2024 revising the steam effluent guidelines
2024 GHG Rules			Final rules published by the EPA in May 2024 for existing fossil fuel-fired steam electric generating units and new fossil fuel-fired combustion turbines and combined cycle generation facilities
2024 Legacy Rule			Final rule published by the EPA in May 2024 related to legacy surface impoundments and CCR management units
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




CCR			Coal combustion residuals
CCR Rule			Disposal of Coal Combustion Residuals from Electric Utilities final rule published by the EPA in 2015
Chattanooga Gas			Chattanooga Gas Company, a wholly-owned subsidiary of Southern Company Gas
Clean Air Act			Clean Air Act Amendments of 1990
CO2			Carbon dioxide
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
ECCR			Georgia Power's Environmental Compliance Cost Recovery tariff
ECO Plan			Mississippi Power's environmental compliance overview plan
ELG			Effluent limitations guidelines
EPA			U.S. Environmental Protection Agency
EPC Contractor			Westinghouse and its affiliate, WECTEC Global Project Services Inc.; the former engineering, procurement, and construction contractor for Plant Vogtle Units 3 and 4

FCC			Federal Communications Commission
FERC			Federal Energy Regulatory Commission
FFB			Federal Financing Bank
Fitch			Fitch Ratings, Inc.
FP&L			Florida Power and Light Company
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, 2024, as applicable
GAAP			U.S. generally accepted accounting principles
Georgia Power			Georgia Power Company
GHG			Greenhouse gas

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DEFINITIONS

(continued)


Term			Meaning
Guarantee Settlement Agreement			The 2017 settlement agreement between the Vogtle Owners and Toshiba related to certain payment obligations of the EPC Contractor guaranteed by Toshiba
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
IGCC			Integrated coal gasification combined cycle, the technology originally approved for Mississippi Power's Kemper County energy facility
IIC			Intercompany Interchange Contract

Internal Revenue Code			Internal Revenue Code of 1986, as amended
IRP			Integrated resource plan
IRS			Internal Revenue Service
ITC			Investment tax credit
KWH			Kilowatt-hour
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)
NCCR			Georgia Power's Nuclear Construction Cost Recovery tariff
NDR			Alabama Power's Natural Disaster Reserve
Nicor Gas			Northern Illinois Gas Company, a wholly-owned subsidiary of Southern Company Gas

NRC			U.S. Nuclear Regulatory Commission

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

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DEFINITIONS

(continued)


Term			Meaning
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
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, in which Southern Power is the controlling partner in a tax equity arrangement
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
Toshiba			Toshiba Corporation, the parent company of Westinghouse
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
WACOG			Weighted average cost of gas
Westinghouse			Westinghouse Electric Company LLC

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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 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, matters related to the abandonment of the Kemper IGCC, completion of announced acquisitions, 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 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, including litigation and other disputes related to the Kemper County energy facility and Plant Vogtle Units 3 and 4;

•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;

•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 tariffs; 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 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;

•advances in technology, including the pace and extent of development of low- to no-carbon energy and battery energy storage technologies and negative carbon concepts;

•performance of counterparties under ongoing renewable energy partnerships and development agreements;

•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;

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

(continued)

•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;

•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, earthquakes, explosions, floods, tornadoes, hurricanes and other storms, droughts, pandemic health events, political unrest, wars, 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.

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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			26
Condensed Statements of 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			31
Condensed Consolidated Statements of Comprehensive Income			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

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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,
	2025		2024		2025		2024
	(in millions)				(in millions)
Operating Revenues:
Retail electric revenues	$	4,758	$	4,486	$	9,358	$	8,427
Wholesale electric revenues	681		627		1,425		1,198
Other electric revenues	220		210		463		409
Natural gas revenues (includes alternative revenue programs of $(9), $11, $(28), and $45, respectively)	979		831		2,818		2,538
Other revenues	335		309		684		537
Total operating revenues	6,973		6,463		14,748		13,109
Operating Expenses:
Fuel	1,116		1,032		2,408		2,028
Purchased power	260		222		510		420
Cost of natural gas	255		149		929		754
Cost of other sales	167		167		366		298
Other operations and maintenance	1,685		1,388		3,305		2,860
Depreciation and amortization	1,323		1,182		2,608		2,327
Taxes other than income taxes	403		384		848		780




Total operating expenses	5,209		4,524		10,974		9,467
Operating Income	1,764		1,939		3,774		3,642
Other Income and (Expense):
Allowance for equity funds used during construction	80		51		153		109
Earnings from equity method investments	10		31		43		77
Interest expense, net of amounts capitalized	(874)		(694)		(1,588)		(1,358)

Other income (expense), net	162		151		310		302
Total other income and (expense)	(622)		(461)		(1,082)		(870)
Earnings Before Income Taxes	1,142		1,478		2,692		2,772
Income taxes	289		290		569		513
Consolidated Net Income	853		1,188		2,123		2,259


Net loss attributable to noncontrolling interests	(27)		(15)		(91)		(73)
Consolidated Net Income Attributable to Southern Company	$	880	$	1,203	$	2,214	$	2,332
Common Stock Data:
Earnings per share -
Basic	$	0.80	$	1.10	$	2.01	$	2.13
Diluted	$	0.79	$	1.09	$	2.00	$	2.12
Average number of shares of common stock outstanding (in millions)
Basic	1,101		1,096		1,100		1,095
Diluted	1,108		1,102		1,107		1,101

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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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,
	2025		2024		2025		2024
	(in millions)				(in millions)
Consolidated Net Income	$	853	$	1,188	$	2,123	$	2,259
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $11, $(1), $16, and $(1), respectively	35		(5)		49		(4)
Reclassification adjustment for amounts included in net income, net of tax of $(10), $5, $(14), and $17, respectively	(31)		15		(43)		47
Pension and other postretirement benefit plans:
Benefit plan net gain (loss), net of tax of $—, $—, $—, and $1, respectively	—		—		1		3

Total other comprehensive income	4		10		7		46
Comprehensive Income	857		1,198		2,130		2,305


Comprehensive loss attributable to noncontrolling interests	(27)		(15)		(91)		(73)
Consolidated Comprehensive Income Attributable to Southern Company	$	884	$	1,213	$	2,221	$	2,378

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months Ended June 30,
	2025		2024
	(in millions)
Operating Activities:
Consolidated net income	$	2,123	$	2,259
Adjustments to reconcile consolidated net income to net cash provided from operating activities —
Depreciation and amortization, total	2,860		2,572
Deferred income taxes	453		247

Allowance for equity funds used during construction	(153)		(109)

Pension, postretirement, and other employee benefits	(253)		(232)
Settlement of asset retirement obligations	(285)		(267)
Stock based compensation expense	102		97










Storm damage cost recovery – long-term	(238)		—
Other, net	76		(116)
Changes in certain current assets and liabilities —
-Receivables	(130)		(284)
-Retail fuel cost under recovery	158		421
-Prepayments	(109)		(49)

-Materials and supplies	35		(139)
-Natural gas for sale, net of temporary LIFO liquidation	233		188

-Other current assets	61		(86)
-Accounts payable	(695)		(247)
-Accrued taxes	(245)		(19)
-Accrued compensation	(421)		(372)



-Customer refunds	(80)		(26)
-Natural gas cost over recovery	(87)		(43)
-Other current liabilities	26		204
Net cash provided from operating activities	3,431		3,999
Investing Activities:


Property additions	(5,237)		(3,895)


Nuclear decommissioning trust fund purchases	(777)		(739)
Nuclear decommissioning trust fund sales	777		738
Proceeds from dispositions	2		345
Cost of removal, net of salvage	(304)		(282)
Change in construction payables, net	(42)		(217)


Other investing activities	(153)		(172)
Net cash used for investing activities	(5,734)		(4,222)
Financing Activities:
Decrease in notes payable, net	(150)		(1,125)
Proceeds —
Long-term debt	6,319		3,963

Short-term borrowings	200		700
Common stock	62		84

Redemptions and repurchases —
Long-term debt	(2,254)		(880)



Short-term borrowings	—		(550)

Distributions to noncontrolling interests	(66)		(57)

Payment of common stock dividends	(1,494)		(1,487)

Other financing activities	(150)		(135)
Net cash provided from financing activities	2,467		513
Net Change in Cash, Cash Equivalents, and Restricted Cash	164		290
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,101		921
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	1,265	$	1,211
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $61 and $52 capitalized for 2025 and 2024, respectively)	$	1,287	$	1,235
Income taxes, net (excludes credit transfers)	199		62
Noncash transactions —
Accrued property additions at end of period	1,091		805




Right-of-use assets obtained under operating leases	114		98
Right-of-use assets obtained under finance leases	14		—
Reassessment of right-of-use assets under operating leases	—		(7)

Issuance of common stock under dividend reinvestment plan	112		67

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


Assets	At June 30, 2025		At December 31, 2024
	(in millions)
Current Assets:
Cash and cash equivalents	$	1,264	$	1,070

Receivables —
Customer accounts	2,301		2,228

Unbilled revenues	895		825
Under recovered fuel clause revenues	684		713

Other accounts and notes	553		597
Accumulated provision for uncollectible accounts	(83)		(74)
Materials and supplies	2,138		2,178
Fossil fuel for generation	740		803
Natural gas for sale	197		388

Prepaid expenses	482		294

Assets from risk management activities, net of collateral	70		39
Regulatory assets – asset retirement obligations	389		353


Other regulatory assets	732		804
Other current assets	439		476
Total current assets	10,801		10,694
Property, Plant, and Equipment:
In service	140,888		137,143
Less: Accumulated depreciation	41,703		40,126
Plant in service, net of depreciation	99,185		97,017
Other utility plant, net	363		410
Nuclear fuel, at amortized cost	907		873
Construction work in progress	7,686		6,389
Total property, plant, and equipment	108,141		104,689
Other Property and Investments:
Goodwill	5,161		5,161
Nuclear decommissioning trusts, at fair value	2,762		2,621
Equity investments in unconsolidated subsidiaries	1,425		1,416
Other intangible assets, net of amortization of $428 and $412, respectively	316		332

Miscellaneous property and investments	699		668
Total other property and investments	10,363		10,198
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,405		1,386
Deferred charges related to income taxes	899		889
Prepaid pension costs	2,881		2,674

Unamortized loss on reacquired debt	195		203
Deferred under recovered fuel clause revenues	325		485
Regulatory assets – asset retirement obligations, deferred	5,115		5,458
Other regulatory assets, deferred	7,338		7,037


Other deferred charges and assets	1,390		1,467
Total deferred charges and other assets	19,548		19,599
Total Assets	$	148,853	$	145,180

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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, 2025		At December 31, 2024
	(in millions)
Current Liabilities:
Securities due within one year	$	5,365	$	4,718

Notes payable	988		1,338

Accounts payable	2,948		3,701
Customer deposits	468		486
Accrued taxes —
Accrued income taxes	20		57

Other accrued taxes	800		997
Accrued interest	775		682

Accrued compensation	825		1,261
Asset retirement obligations	683		731
Liabilities from risk management activities, net of collateral	86		160




Operating lease obligations	200		200
Natural gas cost over recovery	107		193
Other regulatory liabilities	264		369
Other current liabilities	1,041		1,100
Total current liabilities	14,570		15,993
Long-term Debt	62,983		58,768
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	12,294		11,730
Deferred credits related to income taxes	4,446		4,434
Accumulated deferred ITCs	2,017		2,056
Employee benefit obligations	993		1,011
Operating lease obligations, deferred	1,288		1,253
Asset retirement obligations, deferred	8,862		9,203


Other cost of removal obligations	2,028		2,016
Other regulatory liabilities, deferred	671		692

Other deferred credits and liabilities	1,359		1,350
Total deferred credits and other liabilities	33,958		33,745
Total Liabilities	111,511		108,506



















Total Stockholders' Equity (See accompanying statements)	37,342		36,674
Total Liabilities and Stockholders' Equity	$	148,853	$	145,180

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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, 2023	1,092	(1)	$	5,423	$	13,775	$	(59)	$	12,482	$	(177)		$	3,781		$	35,225
Consolidated net income (loss)	—	—	—		—		—		1,129		—			(58)			1,071
Other comprehensive income	—	—	—		—		—		—		37			—			37
Stock issued	3	—	8		53		—		—		—			—			61
Stock-based compensation	—	—	—		8		—		—		—			—			8

Dividends of $0.70 per share	—	—	—		—		—		(766)		—			—			(766)

Capital contributions from noncontrolling interests	—	—	—		—		—		—		—			9			9
Distributions to noncontrolling interests	—	—	—		—		—		—		—			(38)			(38)



Other	—	—	—		10		(2)		(1)		—			—			7
Balance at March 31, 2024	1,095	(1)	5,431		13,846		(61)		12,844		(140)			3,694			35,614
Consolidated net income (loss)	—	—	—		—		—		1,203		—			(15)			1,188
Other comprehensive income	—	—	—		—		—		—		10			—			10
Stock issued	1	—	5		85		—		—		—			—			90
Stock-based compensation	—	—	—		13		—		—		—			—			13

Dividends of $0.72 per share	—	—	—		—		—		(788)		—			—			(788)

Capital contributions from noncontrolling interests	—	—	—		—		—		—		—			2			2
Distributions to noncontrolling interests	—	—	—		—		—		—		—			(19)			(19)




Other	—	—	—		3		(2)		—		—			—			1
Balance at June 30, 2024	1,096	(1)	$	5,436	$	13,947	$	(63)	$	13,259	$	(130)		$	3,662		$	36,111






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

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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,
	2025		2024		2025		2024
	(in millions)				(in millions)
Operating Revenues:
Retail revenues	$	1,718	$	1,647	$	3,441	$	3,213
Wholesale revenues, non-affiliates	98		84		189		169
Wholesale revenues, affiliates	36		27		105		68
Other revenues	116		115		245		214
Total operating revenues	1,968		1,873		3,980		3,664
Operating Expenses:
Fuel	337		335		723		666
Purchased power, non-affiliates	54		47		124		99
Purchased power, affiliates	67		44		121		87
Other operations and maintenance	472		429		935		840
Depreciation and amortization	371		364		741		725
Taxes other than income taxes	120		118		250		238
Total operating expenses	1,421		1,337		2,894		2,655
Operating Income	547		536		1,086		1,009
Other Income and (Expense):
Allowance for equity funds used during construction	18		12		36		26
Interest expense, net of amounts capitalized	(116)		(114)		(225)		(224)
Other income (expense), net	47		37		84		78
Total other income and (expense)	(51)		(65)		(105)		(120)
Earnings Before Income Taxes	496		471		981		889
Income taxes	115		102		226		187
Net Income	$	381	$	369	$	755	$	702

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)				(in millions)
Net Income	$	381	$	369	$	755	$	702
Other comprehensive income:
Qualifying hedges:

Reclassification adjustment for amounts included in net income, net of tax of $—, $—, $—, and $—, respectively	—		1		1		1
Total other comprehensive income	—		1		1		1
Comprehensive Income	$	381	$	370	$	756	$	703

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months Ended June 30,
	2025		2024
	(in millions)
Operating Activities:
Net income	$	755	$	702
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	803		796

Deferred income taxes	116		(40)

Pension, postretirement, and other employee benefits	(89)		(93)
Settlement of asset retirement obligations	(120)		(117)

Retail fuel cost under recovery – long-term	(62)		—

Other, net	(44)		(20)
Changes in certain current assets and liabilities —
-Receivables	(94)		(80)
-Fossil fuel stock	32		9
-Prepayments	(89)		(70)

-Retail fuel cost under recovery	—		131
-Other current assets	(40)		(47)
-Accounts payable	(251)		(331)
-Accrued taxes	25		96
-Accrued compensation	(93)		(68)

-Customer refunds	(110)		(22)
-Other current liabilities	(61)		31
Net cash provided from operating activities	678		877
Investing Activities:
Property additions	(1,034)		(829)
Nuclear decommissioning trust fund purchases	(270)		(328)
Nuclear decommissioning trust fund sales	270		328
Cost of removal, net of salvage	(92)		(77)
Change in construction payables, net of joint owner portion	(32)		(36)
Other investing activities	(11)		(9)
Net cash used for investing activities	(1,169)		(951)
Financing Activities:
Increase in notes payable, net	—		40
Proceeds —
Senior notes	600		—


Short-term borrowings	—		50
Other long-term debt	4		4
Redemptions —

Senior notes	(250)		—


Revenue bonds	—		(21)


Capital contributions from parent company	562		474
Payment of common stock dividends	(609)		(591)
Other financing activities	(7)		(2)
Net cash provided from (used for) financing activities	300		(46)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(191)		(120)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	585		409
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	394	$	289
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $10 and $8 capitalized for 2025 and 2024, respectively)	$	205	$	213
Income taxes, net	217		208
Noncash transactions —
Accrued property additions at end of period	116		101

Right-of-use assets obtained under operating leases	7		10
Right-of-use assets obtained under finance leases	1		—

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)


Assets	At June 30, 2025		At December 31, 2024
	(in millions)
Current Assets:
Cash and cash equivalents	$	394	$	585
Receivables —
Customer accounts	512		512
Unbilled revenues	226		187


Affiliated	139		91
Other accounts and notes	78		126
Accumulated provision for uncollectible accounts	(21)		(22)
Fossil fuel stock	307		339
Materials and supplies	714		699

Prepaid expenses	219		63

Other regulatory assets	327		332
Other current assets	96		79
Total current assets	2,991		2,991
Property, Plant, and Equipment:
In service	37,344		36,501
Less: Accumulated provision for depreciation	12,181		11,741
Plant in service, net of depreciation	25,163		24,760
Other utility plant, net	363		410
Nuclear fuel, at amortized cost	292		262
Construction work in progress	1,358		1,377
Total property, plant, and equipment	27,176		26,809
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,456		1,386
Equity investments in unconsolidated subsidiaries	45		48
Miscellaneous property and investments	133		129
Total other property and investments	1,634		1,563
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	84		84
Deferred charges related to income taxes	267		264
Prepaid pension and other postretirement benefit costs	886		841

Regulatory assets – asset retirement obligations	1,562		1,780
Other regulatory assets, deferred	1,934		1,815
Other deferred charges and assets	423		391
Total deferred charges and other assets	5,156		5,175
Total Assets	$	36,957	$	36,538

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)


Liabilities and Stockholder's Equity	At June 30, 2025		At December 31, 2024
	(in millions)
Current Liabilities:
Securities due within one year	$	624	$	655

Accounts payable —
Affiliated	298		299
Other	397		625
Customer deposits	115		113


Accrued taxes	134		78
Accrued interest	128		120

Accrued compensation	171		240

Asset retirement obligations	271		364
Other regulatory liabilities	35		165
Other current liabilities	94		219
Total current liabilities	2,267		2,878
Long-term Debt	10,881		10,499
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	4,327		4,178
Deferred credits related to income taxes	1,404		1,398
Accumulated deferred ITCs	109		113
Employee benefit obligations	153		148
Operating lease obligations	76		76
Asset retirement obligations, deferred	3,482		3,694

Other regulatory liabilities, deferred	208		271

Other deferred credits and liabilities	250		195
Total deferred credits and other liabilities	10,009		10,073
Total Liabilities	23,157		23,450









Common Stockholder's Equity (See accompanying statements)	13,800		13,088
Total Liabilities and Stockholder's Equity	$	36,957	$	36,538

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

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, 2023	31	$	1,222	$	7,125	$	3,993	$	(7)	$	12,333
Net income	—	—		—		333		—		333

Capital contributions from parent company	—	—		427		—		—		427

Cash dividends on common stock	—	—		—		(295)		—		(295)
Other	—	—		—		(1)		—		(1)
Balance at March 31, 2024	31	1,222		7,552		4,030		(7)		12,797
Net income	—	—		—		369		—		369

Capital contributions from parent company	—	—		50		—		—		50
Other comprehensive income	—	—		—		—		1		1
Cash dividends on common stock	—	—		—		(296)		—		(296)

Balance at June 30, 2024	31	$	1,222	$	7,602	$	4,103	$	(6)	$	12,921









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

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

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,
	2025		2024		2025		2024
	(in millions)				(in millions)
Operating Revenues:
Retail revenues	$	2,765	$	2,597	$	5,395	$	4,752
Wholesale revenues	107		63		250		120

Other revenues	238		215		503		401
Total operating revenues	3,110		2,875		6,148		5,273
Operating Expenses:
Fuel	476		441		1,000		830
Purchased power, non-affiliates	180		151		340		291
Purchased power, affiliates	197		182		461		363
Other operations and maintenance	645		438		1,283		953
Depreciation and amortization	512		447		1,015		872
Taxes other than income taxes	173		164		342		311

Total operating expenses	2,183		1,823		4,441		3,620
Operating Income	927		1,052		1,707		1,653
Other Income and (Expense):
Allowance for equity funds used during construction	56		33		104		72
Interest expense, net of amounts capitalized	(198)		(185)		(385)		(359)
Other income (expense), net	58		54		112		104
Total other income and (expense)	(84)		(98)		(169)		(183)
Earnings Before Income Taxes	843		954		1,538		1,470
Income taxes	236		192		334		271
Net Income	$	607	$	762	$	1,204	$	1,199

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)				(in millions)
Net Income	$	607	$	762	$	1,204	$	1,199
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $1, $—, $1, and $4, respectively	4		—		2		12
Reclassification adjustment for amounts included in net income, net of tax of $—, $—, $—, and $1, respectively	—		1		1		2
Total other comprehensive income	4		1		3		14
Comprehensive Income	$	611	$	763	$	1,207	$	1,213

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months Ended June 30,
	2025		2024
	(in millions)
Operating Activities:
Net income	$	1,204	$	1,199
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,167		1,020
Deferred income taxes	238		77

Allowance for equity funds used during construction	(104)		(72)


Pension, postretirement, and other employee benefits	(128)		(118)

Settlement of asset retirement obligations	(149)		(130)





Storm damage cost recovery – long-term	(238)		—
Other, net	(39)		(152)
Changes in certain current assets and liabilities —
-Receivables	(270)		(431)
-Retail fuel cost under recovery	186		283




-Other current assets	5		(22)
-Accounts payable	(396)		29
-Accrued taxes	(196)		(46)




-Other current liabilities	55		43
Net cash provided from operating activities	1,335		1,680
Investing Activities:
Property additions	(2,991)		(2,113)
Nuclear decommissioning trust fund purchases	(507)		(411)
Nuclear decommissioning trust fund sales	507		411
Cost of removal, net of salvage	(152)		(146)
Change in construction payables, net of joint owner portion	(27)		(192)
Payments pursuant to LTSAs	(7)		(63)

Proceeds from dispositions	—		342

Other investing activities	(41)		(27)
Net cash used for investing activities	(3,218)		(2,199)
Financing Activities:
Increase (decrease) in notes payable, net	285		(689)
Proceeds —
Senior notes	1,600		1,400
Short-term borrowings	200		350



Redemptions and repurchases —

Senior notes	(700)		—
Short-term borrowings	—		(250)
FFB loan	(43)		(43)



Capital contributions from parent company	1,671		862
Payment of common stock dividends	(1,105)		(1,026)


Other financing activities	(49)		(53)
Net cash provided from financing activities	1,859		551
Net Change in Cash, Cash Equivalents, and Restricted Cash	(24)		32
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	118		75
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	94	$	107
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $33 and $31 capitalized for 2025 and 2024, respectively)	$	341	$	329
Income taxes, net (excludes credit transfers)	25		(7)
Noncash transactions —
Accrued property additions at end of period	699		467
Right-of-use assets obtained under operating leases	28		112
Right-of-use assets obtained under finance leases	13		44

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)


Assets	At June 30, 2025		At December 31, 2024
	(in millions)
Current Assets:
Cash and cash equivalents	$	94	$	97

Receivables —
Customer accounts, net	1,088		985
Unbilled revenues	525		341
Under recovered retail fuel clause revenues	655		713
Joint owner accounts	92		101

Affiliated	134		65
Other accounts and notes	55		92

Fossil fuel stock	374		385
Materials and supplies	952		968




Regulatory assets – asset retirement obligations	258		222

Other regulatory assets	346		373

Other current assets	226		262
Total current assets	4,799		4,604
Property, Plant, and Equipment:
In service	56,751		55,036
Less: Accumulated provision for depreciation	15,378		14,806
Plant in service, net of depreciation	41,373		40,230

Nuclear fuel, at amortized cost	615		611
Construction work in progress	4,418		3,197
Total property, plant, and equipment	46,406		44,038
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,306		1,236
Equity investments in unconsolidated subsidiaries	40		43
Miscellaneous property and investments	205		192
Total other property and investments	1,551		1,471
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,271		1,331
Deferred charges related to income taxes	604		596
Prepaid pension costs	974		897
Deferred under recovered retail fuel clause revenues	325		453
Regulatory assets – asset retirement obligations, deferred	3,324		3,436
Other regulatory assets, deferred	3,986		3,814
Other deferred charges and assets	611		615
Total deferred charges and other assets	11,095		11,142
Total Assets	$	63,851	$	61,255

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)


Liabilities and Stockholder's Equity	At June 30, 2025		At December 31, 2024
	(in millions)
Current Liabilities:
Securities due within one year	$	996	$	966
Notes payable	285		200
Accounts payable —
Affiliated	834		984
Other	1,465		1,837
Customer deposits	260		256


Accrued taxes	569		803
Accrued interest	218		190

Accrued compensation	179		276
Operating lease obligations	174		169
Asset retirement obligations	333		309


Other regulatory liabilities	101		150


Other current liabilities	306		296
Total current liabilities	5,720		6,436
Long-term Debt	18,606		17,384
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	4,671		4,385
Deferred credits related to income taxes	2,080		2,047
Accumulated deferred ITCs	341		343
Employee benefit obligations	206		205
Operating lease obligations, deferred	1,116		1,159
Asset retirement obligations, deferred	5,046		5,106

Other deferred credits and liabilities	608		509
Total deferred credits and other liabilities	14,068		13,754
Total Liabilities	38,394		37,574









Common Stockholder's Equity (See accompanying statements)	25,457		23,681
Total Liabilities and Stockholder's Equity	$	63,851	$	61,255

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

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, 2023	9	$	398	$	17,923	$	3,071	$	(9)	$	21,383
Net income	—	—		—		437		—		437

Capital contributions from parent company	—	—		750		—		—		750
Other comprehensive income	—	—		—		—		13		13
Cash dividends on common stock	—	—		—		(513)		—		(513)

Balance at March 31, 2024	9	398		18,673		2,995		4		22,070
Net income	—	—		—		762		—		762

Capital contributions from parent company	—	—		113		—		—		113
Other comprehensive income	—	—		—		—		1		1
Cash dividends on common stock	—	—		—		(513)		—		(513)

Balance at June 30, 2024	9	$	398	$	18,786	$	3,244	$	5	$	22,433








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

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)				(in millions)
Operating Revenues:
Retail revenues	$	274	$	242	$	522	$	462
Wholesale revenues, non-affiliates	62		54		133		113
Wholesale revenues, affiliates	55		58		136		109
Other revenues	9		10		30		22
Total operating revenues	400		364		821		706
Operating Expenses:
Fuel and purchased power	143		117		309		229


Other operations and maintenance	82		83		166		171
Depreciation and amortization	52		47		105		93
Taxes other than income taxes	36		32		69		63

Total operating expenses	313		279		649		556
Operating Income	87		85		172		150
Other Income and (Expense):

Interest expense, net of amounts capitalized	(20)		(20)		(40)		(39)
Other income (expense), net	9		11		16		25
Total other income and (expense)	(11)		(9)		(24)		(14)
Earnings Before Income Taxes	76		76		148		136
Income taxes	17		15		34		25
Net Income	$	59	$	61	$	114	$	111

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)				(in millions)
Net Income	$	59	$	61	$	114	$	111
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $—, $—, $—, and $2, respectively	—		—		—		5

Total other comprehensive income	—		—		—		5
Comprehensive Income	$	59	$	61	$	114	$	116

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months Ended June 30,
	2025		2024
	(in millions)
Operating Activities:
Net income	$	114	$	111
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	115		101
Deferred income taxes	4		(5)



Pension, postretirement, and other employee benefits	(8)		(8)
Settlement of asset retirement obligations	(7)		(9)



Other, net	(7)		7
Changes in certain current assets and liabilities —
-Receivables	(26)		(26)
-Retail fuel cost under recovery	(28)		7
-Fossil fuel stock	20		(22)
-Prepaid income taxes	9		—
-Other current assets	(1)		(4)
-Accounts payable	(22)		(16)
-Accrued taxes	(49)		(41)

-Accrued compensation	(22)		(16)

-Over recovered regulatory clause revenues	(15)		7


-Other current liabilities	1		(1)
Net cash provided from operating activities	78		85
Investing Activities:
Property additions	(166)		(165)
Contributions in aid of construction	57		—
Cost of removal, net of salvage	(17)		(21)
Change in construction payables, net of joint owner portion	(5)		(20)



Payments pursuant to LTSAs	(11)		(10)
Other investing activities	(3)		(2)
Net cash used for investing activities	(145)		(218)
Financing Activities:
Increase in notes payable, net	18		102

Proceeds — Senior notes	100		250







Redemptions — Senior notes	—		(200)







Capital contributions from parent company	57		58

Payment of common stock dividends	(97)		(94)
Other financing activities	(2)		(2)
Net cash provided from financing activities	76		114
Net Change in Cash, Cash Equivalents, and Restricted Cash	9		(19)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	13		38
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	22	$	19
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest	$	37	$	38
Income taxes, net	21		24
Noncash transactions —
Accrued property additions at end of period	30		16

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)


Assets	At June 30, 2025		At December 31, 2024
	(in millions)
Current Assets:
Cash and cash equivalents	$	22	$	13
Receivables —
Customer accounts, net	75		45
Unbilled revenues	47		39

Affiliated	50		33
Other accounts and notes	24		24

Fossil fuel stock	36		56
Materials and supplies	103		103

Other regulatory assets	38		43

Other current assets	14		28
Total current assets	409		384
Property, Plant, and Equipment:
In service	5,873		5,697
Less: Accumulated provision for depreciation	1,906		1,833
Plant in service, net of depreciation	3,967		3,864

Construction work in progress	233		253
Total property, plant, and equipment	4,200		4,117
Other Property and Investments	148		152
Deferred Charges and Other Assets:

Deferred charges related to income taxes	27		27
Prepaid pension costs	134		124
Deferred under recovered retail fuel clause revenues	—		32
Regulatory assets – asset retirement obligations	230		243
Other regulatory assets, deferred	266		259
Accumulated deferred income taxes	74		82

Other deferred charges and assets	70		74
Total deferred charges and other assets	801		841
Total Assets	$	5,558	$	5,494

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)


Liabilities and Stockholder's Equity	At June 30, 2025		At December 31, 2024
	(in millions)
Current Liabilities:
Securities due within one year	$	12	$	12


Notes payable	32		14

Accounts payable —
Affiliated	69		68
Other	72		83
Customer deposits	19		20


Accrued taxes	66		115


Accrued compensation	29		46

Asset retirement obligations	29		32
Over recovered retail fuel clause revenues	—		32

Other regulatory liabilities	3		5


Other current liabilities	68		75
Total current liabilities	399		502



Long-term Debt	1,780		1,681
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	493		492
Deferred credits related to income taxes	213		219

Employee benefit obligations	65		65

Asset retirement obligations, deferred	102		116

Other cost of removal obligations	133		170
Other regulatory liabilities, deferred	117		121
Other deferred credits and liabilities	92		39
Total deferred credits and other liabilities	1,215		1,222
Total Liabilities	3,394		3,405








Common Stockholder's Equity (See accompanying statements)	2,164		2,089
Total Liabilities and Stockholder's Equity	$	5,558	$	5,494

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

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, 2023	1	$	38	$	4,721	$	(2,756)	$	—	$	2,003
Net income	—	—		—		50		—		50

Capital contributions from parent company	—	—		1		—		—		1

Other comprehensive income	—	—		—		—		5		5
Cash dividends on common stock	—	—		—		(47)		—		(47)

Balance at March 31, 2024	1	38		4,722		(2,753)		5		2,012
Net income	—	—		—		61		—		61


Capital contributions from parent company	—	—		58		—		—		58

Cash dividends on common stock	—	—		—		(47)		—		(47)

Balance at June 30, 2024	1	$	38	$	4,780	$	(2,739)	$	5	$	2,084









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

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

Table of Contents Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)				(in millions)
Operating Revenues:
Wholesale revenues, non-affiliates	$	424	$	427	$	870	$	797
Wholesale revenues, affiliates	114		86		229		179
Other revenues	8		11		14		21
Total operating revenues	546		524		1,113		997
Operating Expenses:
Fuel	147		132		355		288
Purchased power	31		22		59		40

Other operations and maintenance	135		119		257		241
Depreciation and amortization	177		127		329		245
Taxes other than income taxes	13		13		25		22



Total operating expenses	503		413		1,025		836
Operating Income	43		111		88		161
Other Income and (Expense):
Interest expense, net of amounts capitalized	(24)		(30)		(50)		(59)
Other income (expense), net	3		3		6		6
Total other income and (expense)	(21)		(27)		(44)		(53)
Earnings Before Income Taxes	22		84		44		108
Income taxes (benefit)	(2)		13		(3)		(1)
Net Income	24		71		47		109
Net loss attributable to noncontrolling interests	(27)		(15)		(91)		(73)
Net Income Attributable to Southern Power	$	51	$	86	$	138	$	182

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)				(in millions)
Net Income	$	24	$	71	$	47	$	109
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $11, $(1), $17, and $(5), respectively	35		(4)		52		(15)
Reclassification adjustment for amounts included in net income, net of tax of $(10), $2, $(15), and $6, respectively	(33)		7		(48)		18
Pension and other postretirement benefit plans:
Benefit plan net gain (loss), net of tax of $—, $—, $—, and $—, respectively	—		—		—		1


Total other comprehensive income	2		3		4		4
Comprehensive Income	26		74		51		113
Comprehensive loss attributable to noncontrolling interests	(27)		(15)		(91)		(73)
Comprehensive Income Attributable to Southern Power	$	53	$	89	$	142	$	186

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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,
	2025		2024
	(in millions)
Operating Activities:
Net income	$	47	$	109
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	340		252
Deferred income taxes	(2)		13

Amortization of ITCs	(29)		(29)








Other, net	(18)		(24)
Changes in certain current assets and liabilities —
-Receivables	(71)		(61)


-Other current assets	2		(3)
-Accounts payable	(20)		(22)


-Accrued compensation	(11)		(11)
-Other current liabilities	(6)		6
Net cash provided from operating activities	232		230
Investing Activities:

Property additions	(392)		(114)




Payments pursuant to LTSAs	(26)		(20)


Other investing activities	—		7
Net cash used for investing activities	(418)		(127)
Financing Activities:
Increase in notes payable, net	201		87









Capital contributions from parent company	146		8

Capital contributions from noncontrolling interests	23		11
Distributions to noncontrolling interests	(66)		(57)

Payment of common stock dividends	(139)		(131)
Other financing activities	(4)		(3)
Net cash provided from (used for) financing activities	161		(85)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(25)		18
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	168		144
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	143	$	162
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $8 and $4 capitalized for 2025 and 2024, respectively)	$	59	$	64
Income taxes, net (excludes credit transfers)	52		14
Noncash transactions —


Accrued property additions at end of period	60		47

Right-of-use assets obtained under operating leases	2		5
Reassessment of right-of-use assets under operating leases	—		(7)

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

Table of Contents Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


Assets	At June 30, 2025		At December 31, 2024
	(in millions)
Current Assets:
Cash and cash equivalents	$	143	$	159
Receivables —
Customer accounts, net	184		122
Affiliated	44		39
Other	87		90

Materials and supplies	111		107






Other current assets	98		82
Total current assets	667		599
Property, Plant, and Equipment:
In service	15,005		14,961
Less: Accumulated provision for depreciation	4,789		4,540
Plant in service, net of depreciation	10,216		10,421
Construction work in progress	658		317

Total property, plant, and equipment	10,874		10,738
Other Property and Investments:

Intangible assets, net of amortization of $178 and $168, respectively	213		223

Net investment in sales-type leases	140		143
Total other property and investments	353		366
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	483		484
Prepaid LTSAs	194		234




Other deferred charges and assets	246		232
Total deferred charges and other assets	923		950
Total Assets	$	12,817	$	12,653

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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, 2025		At December 31, 2024
	(in millions)
Current Liabilities:
Securities due within one year	$	1,485	$	500
Notes payable	200		—
Accounts payable —
Affiliated	78		80
Other	74		100

Accrued taxes	27		18

Accrued interest	21		26
Operating lease obligations	29		29



Other current liabilities	74		96
Total current liabilities	1,988		849
Long-term Debt	1,262		2,180
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	711		712
Accumulated deferred ITCs	1,412		1,440





Operating lease obligations, deferred	511		511
Other deferred credits and liabilities	241		279
Total deferred credits and other liabilities	2,875		2,942
Total Liabilities	6,125		5,971










Total Stockholders' Equity (See accompanying statements)	6,692		6,682
Total Liabilities and Stockholders' Equity	$	12,817	$	12,653

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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, 2023	$	1,088	$	1,846	$	(17)	$	2,917	$	3,781	$	6,698
Net income (loss)	—		96		—		96		(58)		38


Other comprehensive income	—		—		2		2		—		2
Cash dividends on common stock	—		(65)		—		(65)		—		(65)

Capital contributions from noncontrolling interests	—		—		—		—		9		9
Distributions to noncontrolling interests	—		—		—		—		(38)		(38)



Other	—		(1)		—		(1)		—		(1)
Balance at March 31, 2024	1,088		1,876		(15)		2,949		3,694		6,643
Net income (loss)	—		86		—		86		(15)		71

Capital contributions from parent company	8		—		—		8		—		8
Other comprehensive income	—		—		3		3		—		3
Cash dividends on common stock	—		(66)		—		(66)		—		(66)

Capital contributions from noncontrolling interests	—		—		—		—		2		2
Distributions to noncontrolling interests	—		—		—		—		(19)		(19)




Other	1		—		—		1		—		1
Balance at June 30, 2024	$	1,097	$	1,896	$	(12)	$	2,981	$	3,662	$	6,643




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

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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,
	2025		2024		2025		2024
	(in millions)				(in millions)
Operating Revenues:
Natural gas revenues (includes revenue taxes of $27, $23, $90, and $76, respectively)	$	979	$	831	$	2,818	$	2,538


Total operating revenues	979		831		2,818		2,538
Operating Expenses:
Cost of natural gas	255		149		929		754

Other operations and maintenance	301		288		617		581
Depreciation and amortization	172		158		341		313
Taxes other than income taxes	61		56		158		143




Total operating expenses	789		651		2,045		1,791
Operating Income	190		180		773		747
Other Income and (Expense):
Earnings from equity method investments	23		32		62		76
Interest expense, net of amounts capitalized	(92)		(83)		(183)		(167)
Other income (expense), net	18		15		34		35
Total other income and (expense)	(51)		(36)		(87)		(56)
Earnings Before Income Taxes	139		144		686		691
Income taxes	33		36		162		174
Net Income	$	106	$	108	$	524	$	517

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)


	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)				(in millions)
Net Income	$	106	$	108	$	524	$	517
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(2), $1, $2, and $(1), respectively	(6)		2		6		(3)
Reclassification adjustment for amounts included in net income, net of tax of $—, $2, $—, and $9, respectively	(1)		5		—		22
Pension and other postretirement benefit plans:

Reclassification adjustment for amounts included in net income, net of tax of $—, $—, $—, and $—, respectively	—		—		(1)		—
Total other comprehensive income (loss)	(7)		7		5		19
Comprehensive Income	$	99	$	115	$	529	$	536

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

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SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)


	For the Six Months Ended June 30,
	2025		2024
	(in millions)
Operating Activities:
Net income	$	524	$	517
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	338		310
Deferred income taxes	67		211









Other, net	26		50
Changes in certain current assets and liabilities —
-Receivables	209		310
-Natural gas for sale, net of temporary LIFO liquidation	233		188


-Other current assets	37		(48)
-Accounts payable	(105)		(112)


-Natural gas cost over recovery	(87)		(43)
-Other current liabilities	(32)		(113)
Net cash provided from operating activities	1,210		1,270
Investing Activities:
Property additions	(677)		(657)
Cost of removal, net of salvage	(42)		(38)
Change in construction payables, net	15		20



Other investing activities	(31)		(21)
Net cash used for investing activities	(735)		(696)
Financing Activities:
Increase (decrease) in notes payable, net	16		(274)




Proceeds — Other long-term debt	—		9






Return of capital to parent company	(23)		—

Capital contributions from parent company	22		3
Payment of common stock dividends	(297)		(302)
Other financing activities	(12)		(10)
Net cash used for financing activities	(294)		(574)
Net Change in Cash, Cash Equivalents, and Restricted Cash	181		—
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	44		35
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	225	$	35
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $9 and $10 capitalized for 2025 and 2024, respectively)	$	185	$	164
Income taxes, net	66		(52)
Noncash transactions —
Accrued property additions at end of period	101		159
Right-of-use assets obtained under operating leases	60		1
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.

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SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


Assets	At June 30, 2025		At December 31, 2024
	(in millions)
Current Assets:
Cash and cash equivalents	$	225	$	43
Receivables —

Customer accounts	327		399
Unbilled revenues	85		244



Other accounts and notes	68		45
Accumulated provision for uncollectible accounts	(50)		(33)
Materials and supplies	62		66
Natural gas for sale	197		388


Prepaid expenses	52		45




Other regulatory assets	151		187
Other current assets	38		55
Total current assets	1,155		1,439
Property, Plant, and Equipment:
In service	23,185		22,338
Less: Accumulated depreciation	6,100		5,887
Plant in service, net of depreciation	17,085		16,451
Construction work in progress	869		1,057
Total property, plant, and equipment	17,954		17,508
Other Property and Investments:
Goodwill	5,015		5,015
Equity investments in unconsolidated subsidiaries	1,300		1,279
Other intangible assets, net of amortization of $176 and $173, respectively	6		9
Miscellaneous property and investments	24		25
Total other property and investments	6,345		6,328
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	92		38
Prepaid pension costs	202		191


Other regulatory assets, deferred	487		481


Other deferred charges and assets	141		192
Total deferred charges and other assets	922		902
Total Assets	$	26,376	$	26,177

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

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SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)


Liabilities and Stockholder's Equity	At June 30, 2025		At December 31, 2024
	(in millions)
Current Liabilities:
Securities due within one year	$	752	$	302
Notes payable	471		455

Accounts payable —
Affiliated	54		75
Other	384		437
Customer deposits	74		98


Accrued taxes	89		85
Accrued interest	88		88

Accrued compensation	85		129




Temporary LIFO liquidation	42		—

Natural gas cost over recovery	107		193
Other regulatory liabilities	43		7
Other current liabilities	137		149
Total current liabilities	2,326		2,018
Long-term Debt	7,786		8,229
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,874		1,796
Deferred credits related to income taxes	736		755

Employee benefit obligations	63		78


Operating lease obligations	88		30
Other cost of removal obligations	1,894		1,846
Accrued environmental remediation	187		198



Other deferred credits and liabilities	224		231
Total deferred credits and other liabilities	5,066		4,934
Total Liabilities	15,178		15,181







Common Stockholder's Equity (See accompanying statements)	11,198		10,996
Total Liabilities and Stockholder's Equity	$	26,376	$	26,177

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

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SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDER'S EQUITY (UNAUDITED)


	Paid-In Capital		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Total
	(in millions)
Balance at December 31, 2023	$	10,836	$	(49)	$	16	$	10,803
Net income	—		409		—		409


Capital contributions from parent company	2		—		—		2
Other comprehensive income	—		—		12		12
Cash dividends on common stock	—		(151)		—		(151)
Other	—		(1)		—		(1)
Balance at March 31, 2024	10,838		208		28		11,074
Net income	—		108		—		108

Capital contributions from parent company	6		—		—		6
Other comprehensive income	—		—		7		7
Cash dividends on common stock	—		(151)		—		(151)

Balance at June 30, 2024	$	10,844	$	165	$	35	$	11,044









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

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

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	46
C	Contingencies	51
D	Revenue from Contracts with Customers and Lease Income	53
E	Consolidated Entities and Equity Method Investments	60
F	Financing	61
G	Income Taxes	65
H	Retirement Benefits	66
I	Fair Value Measurements	70
J	Derivatives	74
K	Acquisitions and Dispositions	86
L	Segment and Related Information	87

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

Southern Company

Alabama Power

Georgia Power

Mississippi Power

Southern Power

Southern Company Gas

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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, 2024 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, 2025 and 2024. 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, 2025 and December 31, 2024 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.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Other intangible assets were as follows:


	At June 30, 2025						At December 31, 2024
	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	$	(184)	$	28	$	212	$	(182)	$	30
Trade names	64		(63)		1		64		(59)		5
PPA fair value adjustments	390		(178)		212		390		(168)		222
Other	3		(3)		—		3		(3)		—
Total subject to amortization	$	669	$	(428)	$	241	$	669	$	(412)	$	257
Not subject to amortization:
FCC licenses	75		—		75		75		—		75
Total other intangible assets	$	744	$	(428)	$	316	$	744	$	(412)	$	332

Southern Power(*)
PPA fair value adjustments	$	390	$	(178)	$	212	$	390	$	(168)	$	222

Southern Company Gas(*)

Gas marketing services
Customer relationships	$	156	$	(151)	$	5	$	156	$	(150)	$	6
Trade names	26		(25)		1		26		(23)		3
Total other intangible assets	$	182	$	(176)	$	6	$	182	$	(173)	$	9

(*)All subject to amortization.

Amortization associated with other intangible assets was as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)
Southern Company(a)	$	8	$	9	$	16	$	18
Southern Power(b)	5		5		10		10
Southern Company Gas
Gas marketing services	1		1		3		3

(a)Includes $5 million for the three months ended June 30, 2025 and 2024 and $10 million for the six months ended June 30, 2025 and 2024 recorded as a reduction to operating revenues.

(b)Recorded as a reduction to operating revenues.

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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		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
At June 30, 2025
Cash and cash equivalents	$	1,264	$	94	$	143	$	225
Restricted cash(*):
Other current assets	1		—		—		—

Total cash, cash equivalents, and restricted cash	$	1,265	$	94	$	143	$	225

At December 31, 2024
Cash and cash equivalents	$	1,070	$	97	$	159	$	43
Restricted cash(*):
Other current assets	31		21		9		1

Total cash, cash equivalents, and restricted cash	$	1,101	$	118	$	168	$	44

(*)For Georgia Power, reflects remaining proceeds held at December 31, 2024 from the issuance of solid waste disposal facility revenue bonds in 2022. For Southern Power, reflects remaining proceeds held at December 31, 2024 from an arbitration award held to fund future replacement costs. For Southern Company, also reflects collateral of $1 million for life insurance and long-term disability insurance, which was included at Southern Holdings and Southern Company Gas at June 30, 2025 and December 31, 2024, respectively.

Natural Gas for Sale

With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG 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 decrement at June 30, 2025 is expected to be restored prior to year-end.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Storm Damage Reserves

See Note 1 to the financial statements under "Storm Damage and Reliability Reserves" in Item 8 of the Form 10-K for additional information.

Storm damage reserve activity for the traditional electric operating companies during the six months ended June 30, 2025 was as follows:


	Southern Company		Alabama Power		Georgia Power		Mississippi Power
	(in millions)
Balance at December 31, 2024	$	(705)	$	70	$	(827)	$	52
Accrual(*)	36		13		16		7
Weather-related damages	(198)		(85)		(106)		(7)
Balance at June 30, 2025	$	(867)	$	(2)	$	(917)	$	52

(*)For Alabama Power, includes $7 million of undistributed customer bill credits related to the nuclear fuel disposal costs litigation award, as directed by the Alabama PSC in its December 2024 order. See Note 3 to the financial statements under "Nuclear Fuel Disposal Costs" in Item 8 of the Form 10-K for additional information.

Depreciation and Amortization

See Note 5 to the financial statements under "Depreciation and Amortization" in Item 8 of the Form 10-K for additional information.

On April 1, 2025, the Mississippi PSC approved a stipulation between Mississippi Power and the Mississippi Public Utilities Staff for an $8 million increase in total annual depreciation effective January 1, 2025.

Asset Retirement Obligations

See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

In June 2025, Alabama Power recorded a net decrease of approximately $257 million to its AROs related to the CCR Rule and the related state rule resulting from changes in estimates, including lower future inflation rates, higher discount rates, and timing of closure activities.

Also in June 2025, Mississippi Power, as a joint owner of Alabama Power's Plant Greene County Units 1 and 2, recorded a net decrease of approximately $13 million to its AROs related to the CCR Rule and the related Alabama state rule resulting from changes in estimates, including lower future inflation rates, higher discount rates, and timing of closure activities.

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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 fuel and natural gas cost recovery balances for the traditional electric operating companies and Southern Company Gas, respectively, at June 30, 2025 and December 31, 2024 were as follows:


Regulatory Clause	Balance Sheet Line Item	At June 30, 2025		At December 31, 2024
		(in millions)
Alabama Power







Rate ECR	Other regulatory assets, deferred	$	62	$	—
	Other regulatory liabilities, current	—		29

Georgia Power
Fuel Cost Recovery	Receivables – under recovered retail fuel clause revenues	$	655	$	713
	Deferred under recovered retail fuel clause revenues	325		453


Mississippi Power
Fuel Cost Recovery(*)	Receivables – customer accounts, net	$	28	$	—
	Deferred under recovered retail fuel clause revenues	—		32
	Over recovered retail fuel clause revenues	—		32


Southern Company Gas

Natural Gas Cost Recovery	Natural gas cost over recovery	$	107	$	193

(*)Mississippi Power also has wholesale MRA and Market Based (MB) fuel cost recovery factors. At June 30, 2025 and December 31, 2024, wholesale MRA fuel costs were over recovered $5 million and $19 million, respectively, and were included in other current liabilities on Mississippi Power's balance sheets. The wholesale MB fuel cost recovery was immaterial for both periods presented.

Alabama Power

Petition for Certificate of Convenience and Necessity

On June 6, 2025, the FERC approved Alabama Power's acquisition of Tenaska Alabama Partners, L.P., which owns and operates the Lindsay Hill Generating Station, an approximately 855-MW combined cycle generation facility in Autauga County, Alabama. The total purchase price is approximately $622 million, subject to working capital adjustments. The completion of the acquisition is subject to the satisfaction or waiver of customary closing conditions, including, among others, approval by the Alabama PSC. Alabama Power expects to complete the acquisition by the end of the third quarter 2025. The ultimate outcome of this matter cannot be determined at this time.

Jurisdictional Separation Study Order

On June 5, 2025, the Alabama PSC approved an order authorizing Alabama Power to implement changes related to the Jurisdictional Separation Study (JSS) under Rate RSE, which allocates costs between retail and other electric services. For 2026, a revised JSS allocation factor will account for system capacity previously allocated to wholesale electric services that will be used for retail electric service starting January 1, 2026. In addition, Alabama Power is authorized to establish a regulatory asset to defer certain costs associated with this capacity for 2026, and those costs are estimated to be approximately $100 million. Beginning in 2027, Alabama Power will amortize the regulatory asset on a levelized basis over a period not exceeding 10 years.

Rate NDR

Beginning with July 2025 billings, the NDR reserve maintenance charge was suspended and the reserve establishment charge was activated as a result of the NDR balance falling below $50 million. Alabama Power

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

expects to collect $18 million in the second half of 2025 and approximately $36 million annually beginning in 2026 under Rate NDR unless the NDR balance exceeds $75 million. At June 30, 2025, Alabama Power's regulatory asset balance related to NDR was $2 million. Rate NDR is intended to allow recovery of any existing deferred storm-related operations and maintenance costs and any future reserve deficits over a 48-month period. The Alabama PSC gives Alabama Power authority to record a deficit balance in the NDR when costs of storm damage exceed any established reserve balance.

Reliability Reserve Accounting Order

On June 19, 2025, Alabama Power notified the Alabama PSC of its intent to use a portion of its $131 million reliability reserve balance during 2025. The ultimate outcome of this matter cannot be determined at this time.

Georgia Power

2022 ARP

On July 1, 2025, the Georgia PSC approved a settlement agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors to extend the 2022 ARP for an additional three-year term through December 31, 2028 (ARP Extension). Under the ARP Extension, base rates will not be adjusted in 2026, 2027, or 2028 (ARP Extension Period) except for reasonable and prudent storm damage costs incurred through December 31, 2025, which will be determined in a separate regulatory proceeding.

Under the ARP Extension, Georgia Power's retail ROE set point will continue at 10.50% and its equity ratio will continue at 56%. Additionally, the retail ROE range approved by the Georgia PSC in the 2022 ARP, of 9.50% to 11.90%, will continue. The ARP Extension includes, among other things, the following modifications to the 2022 ARP:

•Storm damage costs will be included in a separate regulatory proceeding to be filed no sooner than February 1, 2026 and no later than July 1, 2026 to recover the actual reasonable and prudent storm costs incurred through December 31, 2025. Subject to Georgia PSC approval, new rates would be effective approximately 90 days after the filing is made. The Georgia PSC will determine the period over which any such storm damage costs will be recovered.

•Amortization of regulatory assets and liabilities in the 2022 ARP, which were subsequently included in current rates through annual compliance filings, will continue through the ARP Extension Period. This includes those regulatory asset and liability balances that were projected to be fully amortized through 2025 or during the ARP Extension Period.

•The amounts previously deferred during the 2022 ARP for ITCs and PTCs will be amortized through the ARP Extension Period. The acceleration of amortization during the ARP Extension Period is subject to the Internal Revenue Code normalization rules and other guidance (if any) released by the IRS. Certain amounts of ITCs generated during the ARP Extension Period will be amortized over five years, and additional ITC amounts will be deferred to a regulatory liability during the ARP Extension Period. Sixty percent (60%) of PTC benefits generated (excluding PTCs generated under Internal Revenue Code §45J) during the ARP Extension Period will be credited to income tax expense as generated. The remaining forty percent (40%) will be deferred to a regulatory liability.

•The period for depreciation and amortization related to certain generating plants and net book values of retired generating plants will be 13 years effective January 1, 2026.

Using the retail ROE range approved by the Georgia PSC in the 2022 ARP, earnings above 11.90% retail ROE will continue to be subject to sharing whereby 40% of earnings above the band would be applied to regulatory assets, 40% would be directly refunded to customers, and the remaining 20% would be retained by Georgia Power. There will be no recovery of any earnings shortfall below 9.50% retail ROE on an actual basis. However, if at any time during the term of the ARP Extension Period, Georgia Power projects that its retail earnings will be less than the lower end of the approved retail ROE range for any calendar year of the ARP Extension Period, it may petition the Georgia PSC for implementation of the Interim Cost Recovery (ICR) tariff to adjust Georgia Power's retail rates to

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

achieve a retail ROE equal to the lower end of the approved retail ROE range. Any ICR tariff would expire at the earlier of January 1, 2029 or the end of the calendar year in which the ICR tariff becomes effective. In lieu of requesting implementation of an ICR tariff, or if the Georgia PSC chooses not to implement the ICR tariff, Georgia Power may file a full base rate case.

Except as provided above, Georgia Power will not file a base rate increase while the ARP Extension is in effect. Georgia Power is required to file a general base rate case by July 1, 2028.

Integrated Resource Plans

On June 20, 2025, Georgia Power requested certification from the Georgia PSC for a Georgia Power-owned battery energy storage facility with a capacity of 200 MWs and a projected COD in 2027. Georgia Power expects the Georgia PSC to render a final decision in September 2025.

On July 30, 2025, Georgia Power requested certification from the Georgia PSC, for which a final decision is expected to be rendered in December 2025, for the following resources:

•As included in the 2022 IRP final order, Georgia Power initiated a request for proposals (RFP) of up to 8,500 MWs of capacity from a variety of resources with projected CODs or delivery commencement dates between 2028 and 2030. The RFP resulted in 18 resources, totaling 7,999 MWs, being selected which consist of four PPAs (including two affiliate PPAs with Southern Power that are subject to approval by the FERC) with capacity totaling 1,195 MWs commencing between 2028 and 2030, three project sites consisting of five Georgia Power-owned combined cycle units with capacity totaling 3,692 MWs and projected CODs commencing between 2029 and 2030, nine Georgia Power-owned battery energy storage facilities with capacity totaling 2,762 MWs and projected CODs commencing between 2028 and 2030, and two Georgia Power-owned battery energy storage facilities with solar with capacity totaling 350 MWs and projected CODs commencing in 2028.

•In July 2025, Georgia Power extended 50 MWs of an existing 750-MW affiliate PPA with Mississippi Power for an additional year through December 31, 2029.

•Additionally, in July 2025, Georgia Power executed a 20-year non-affiliate PPA for 930 MWs commencing in 2030 and five 25-year non-affiliate PPAs totaling 646 MWs commencing in 2027.

•Georgia Power entered into agreements to initiate acquisition of property and construction of a 260-MW Georgia Power-owned battery energy storage facility with a projected COD in 2027 to be paired with an existing non-affiliate solar PPA.

The certification requests on June 20, 2025 and July 30, 2025 associated with these Georgia Power-owned projects and related transmission investments total approximately $16.7 billion, excluding AFUDC.

As required by the 2025 IRP decision, Georgia Power will update its load forecast to support the certification requests from the RFP of up to 8,500 MWs. The Georgia PSC will determine the necessary generation resources to certify. See "2025 IRP" herein for information regarding the 2025 IRP.

The ultimate outcome of these matters cannot be determined at this time.

2025 IRP

On July 15, 2025, the Georgia PSC approved Georgia Power's 2025 IRP, as modified by a stipulation among Georgia Power, the staff of the Georgia PSC, and certain intervenors. In the 2025 IRP decision, the Georgia PSC approved the following requests:

•Extended operation of Plant Scherer Unit 3 (614 MWs based on 75% ownership) through at least December 31, 2035 and Plant Gaston Units 1 through 4 (500 MWs based on 50% ownership through SEGCO) through at least December 31, 2034. See Note 7 to the financial statements under "SEGCO" in Item 8 of the Form 10-K for additional information.

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•Installation of environmental controls and natural gas co-firing at Plant Bowen Units 1 through 4 (3,160 MWs), Plant Scherer Units 1 and 2 (137 MWs based on 8.4% ownership), and Plant Scherer Unit 3 for compliance with both ELG supplemental rules and GHG rules.

•Upgrades to Plant McIntosh Units 10 and 11 (1,319 MWs) for a projected 194 MWs of incremental capacity by 2028 and Plant McIntosh Units 1 through 8 (640 MWs) for a projected 74 MWs of incremental capacity by 2033.

•Upgrades to Plant Vogtle Units 1 and 2 (1,060 MWs based on 45.7% ownership) for a projected 54 MWs of incremental capacity, some of which could be available as early as 2028.

•Investments related to the continued reliable hydro operations of four facilities, as well as the authority to spend up to $25 million to undertake engineering studies related to two additional hydro facilities.

•RFP for at least 1,100 MWs of utility scale and distributed generation renewable resources.

•Issuance of a capacity RFP to procure resources to meet capacity needs in 2032 and 2033.

•Strategic power delivery infrastructure plan necessary to help ensure adequate reliability and serve the projected future load growth expected in Georgia.

•Certification of approximately 187 MWs of wholesale capacity associated with Plant Scherer Unit 3 to be placed in retail rate base, some of which will be available beginning in 2026.

In addition, the 2025 IRP assumes Plant Bowen Units 1 and 2 will operate through at least the end of 2035.

Fuel Cost Recovery

On May 14, 2025, Georgia Power submitted an Interim Fuel Rider (IFR) notification and plan informing the Georgia PSC that Georgia Power's under recovered fuel balance exceeded the IFR threshold of $200 million, established in a Georgia PSC stipulation approved in May 2023. Georgia Power proposed no fuel cost recovery rate change and is required to monitor and report to the Georgia PSC monthly as long as the under recovered fuel balance is above $200 million. On July 15, 2025, Georgia Power filed its most recent IFR plan and notification which also proposed no fuel cost recovery rate change. Georgia Power is scheduled to file its next fuel case no later than February 28, 2026. See Note 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information.

Nuclear Construction

Georgia Power placed Plant Vogtle Units 3 and 4 in service on July 31, 2023 and April 29, 2024, respectively. As of June 30, 2025, site demobilization efforts were largely complete. Georgia Power is finalizing remaining contractor obligations. Georgia Power's net capital costs incurred through June 30, 2025 in connection with Plant Vogtle Units 3 and 4, and its approximate proportionate share of remaining capital costs to be incurred after June 30, 2025, is as follows:


	(in millions)
Total project capital cost forecast(a)(b)	$	10,732
Net investment at June 30, 2025(b)	(10,690)
Remaining estimate to complete	$	42

(a)Includes approximately $1.2 billion of costs that are not shared with the other Vogtle Owners. Excludes financing costs capitalized through AFUDC of approximately $440 million accrued through Unit 4's in-service date.

(b)Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds.

Other Construction

At June 30, 2025, Georgia Power had recorded approximately $1.3 billion of combined capital costs, excluding AFUDC, for the projects reflected in the table below. The total certified amounts related to these projects are

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approximately $2.8 billion, excluding AFUDC. The ultimate outcome of these matters cannot be determined at this time.

Project

Resource

Approximate Nameplate Capacity

(MW)

Projected COD

Regulatory Approval

Projects Under Construction at June 30, 2025

McGrau Ford

Battery energy storage

265

Fourth quarter 2026

2022 IRP

Plant Yates Units 8 through 10

Combustion turbine

1,326

Fourth quarter 2026 through third quarter 2027

2023 IRP Update

Various facilities

Battery energy storage

500

Second quarter 2026 through fourth quarter 2026

2023 IRP Update

Mississippi Power

Performance Evaluation Plan

On June 17, 2025, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2025, resulting in an annual increase in revenues of approximately 4.0%, or $41 million, primarily due to increases in investment and depreciation. In accordance with the PEP rate schedule, an increase of 2.0% of total retail revenues, or approximately $22 million, became effective with the first billing cycle of April 2025, and the remaining approximately $19 million became effective with the first billing cycle of July 2025.

Integrated Resource Plans

On July 8, 2025, Mississippi Power extended 50 MWs of an existing 750-MW affiliate PPA with Georgia Power for an additional year through December 31, 2029, subject to approval by the Georgia PSC. The ultimate outcome of this matter cannot be determined at this time. See "Georgia Power – Integrated Resource Plans" herein for additional information.

Environmental Compliance Overview Plan

On April 1, 2025, the Mississippi PSC approved Mississippi Power's annual ECO Plan filing for 2025, resulting in a $6 million annual increase in revenues effective with the first billing cycle of May 2025.

Ad Valorem Tax Adjustment

On June 30, 2025, Mississippi Power submitted its annual ad valorem tax adjustment filing for 2025 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 17, 2025, the Mississippi PSC approved Mississippi Power's annual SRR filing for 2025, with no change in retail rates. Mississippi Power's minimum annual SRR accrual increased from $12.6 million to $13.5 million and the target property damage reserve balance increased from $75 million to $125 million. Mississippi Power will continue to record a minimum annual accrual until a target property damage reserve balance of $125 million is met.

Reliability Reserve Accounting Order

On March 17, 2025, Mississippi Power notified the Mississippi PSC of its intent to use a portion of its $57 million reliability reserve balance during 2025, through the annual PEP filing. On June 17, 2025, the Mississippi PSC approved the annual PEP filing which allowed the use of $10.9 million of the reliability reserve balance, which Mississippi Power used for reliability-related generation, transmission, and distribution expenses in the second quarter 2025. See "Performance Evaluation Plan" herein for information regarding approval of the annual PEP filing.

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Plant Daniel

On June 19, 2025, the Florida PSC issued a final order approving the transfer of FP&L's 50% ownership interest in Plant Daniel Units 1 and 2 to Mississippi Power. On July 30, 2025, Mississippi Power completed the acquisition of FP&L's 50% interest in Plant Daniel Units 1 and 2 and, as part of the acquisition, received approximately $36 million from FP&L.

Municipal and Rural Associations Tariff

On April 3, 2025, the FERC approved a settlement agreement filed by Mississippi Power and Cooperative Energy in December 2024. The settlement agreement provides for (i) a $1 million increase in annual wholesale base revenues and a refund to customers of approximately $4 million, (ii) a rate escalation of 2.5% on an annual basis in periods subsequent to December 31, 2024 and continuing through the end of the shared service agreement on December 31, 2035, and (iii) a waiver of rights by Mississippi Power and Cooperative Energy to file for any changes in non-fuel rates through the end of the term of the shared service agreement.

Southern Company Gas

Infrastructure Replacement Programs and Capital Projects

On March 26, 2025, the Illinois Supreme Court denied Nicor Gas' petition for leave to appeal $14 million of the 2019 Qualifying Infrastructure Plant disallowance. This matter is concluded and had no impact on the current period financial statements.

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

On July 11, 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 plaintiffs' alleged conspiracy, including Southern Nuclear. The plaintiffs seek to recover, among other relief, unspecified monetary damages, including treble damages and attorneys' fees, and injunctive relief. An adverse outcome could have a material impact on Southern Company's financial statements.

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Southern Company and Mississippi Power

In 2010, the DOE, through a cooperative agreement with SCS, agreed to fund $270 million of the Kemper County energy facility through the grants awarded to the project by the DOE under the Clean Coal Power Initiative Round 2. In 2016, additional DOE grants in the amount of $137 million were awarded to the Kemper County energy facility. In 2018, Mississippi Power filed with the DOE its request for property closeout certification under the contract related to the $387 million of total grants received. In 2020, Mississippi Power and Southern Company executed an agreement with the DOE completing Mississippi Power's request, which enabled Mississippi Power to proceed with full dismantlement of the abandoned gasifier-related assets and site restoration activities. In connection with the DOE closeout discussions, in 2019, the Civil Division of the Department of Justice informed Southern Company and Mississippi Power of a civil investigation related to the DOE grants. In August 2023, the U.S. District Court for the Northern District of Georgia unsealed a civil action in which defendants Southern Company, SCS, and Mississippi Power are alleged to have violated certain provisions of the False Claims Act by fraudulently inducing the DOE to disburse funds pursuant to the grants. The federal government declined to intervene in the action. In October 2023, the plaintiff, a former SCS employee, filed an amended complaint, again alleging certain violations of the False Claims Act. The plaintiff seeks to recover all damages incurred personally and on behalf of the federal government caused by the defendants' alleged violations, as well as treble damages and attorneys' fees, among other relief. In February 2024, the defendants moved to dismiss the amended complaint. In August 2024, the court granted the defendants' motion in part and denied it in part, dismissing the plaintiff's False Claims Act count along with its accompanying treble damages and attorneys' fees but allowing the employment retaliation claim to proceed. In October 2024, the plaintiff requested interlocutory appeal of the court's decision, which was denied on February 25, 2025, and the defendants asserted counterclaims for conversion and misappropriation of trade secrets. In November 2024, the defendants filed a motion for judgment on the pleadings on the plaintiff's employment retaliation claim. In December 2024, the plaintiff filed a motion to dismiss the defendants' counterclaims. On July 15, 2025, the court denied the plaintiff's motion to dismiss the defendants' counterclaims and the defendants' motion for judgment on the pleadings. An adverse outcome could have a material impact on Southern Company's and Mississippi Power's financial statements.

Alabama Power

In September 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. In December 2022, Alabama Power filed a motion to dismiss the case. In January 2024, the lawsuit was dismissed without prejudice by the U.S. District Court judge. In February 2024, the plaintiff filed a motion to reconsider, which was denied by the U.S. District Court judge in July 2024. In August 2024, 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.

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 September 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.

On July 29, 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 violates the RCRA and regulations governing CCR. Among other relief requested, Coosa Riverkeeper seeks declaratory judgment that Alabama Power is in violation of RCRA and regulations governing CCR, and preliminary and injunctive relief to

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require Alabama Power to close the CCR unit and operate a groundwater monitoring system in a different manner to satisfy RCRA and the regulations governing CCR requirements.

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 $13 million at both June 30, 2025 and December 31, 2024. 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 $216 million and $222 million at June 30, 2025 and December 31, 2024, 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.

Other Matters

Mississippi Power

On March 31, 2025, the Mississippi Department of Revenue (Mississippi DOR) completed an audit of sales and use taxes paid by Mississippi Power from October 2019 to July 2024 and entered a final assessment, indicating a total amount due of $29 million, including associated penalties and interest. Mississippi Power does not agree with the audit findings and filed an administrative appeal with the Mississippi DOR on May 29, 2025. Mississippi Power's sales and use taxes are generally authorized for rate recovery. The ultimate outcome of this matter cannot be determined at this time.

(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.

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The following table disaggregates revenue from contracts with customers for the three and six months ended June 30, 2025 and 2024:


	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

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	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

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2024
Operating revenues
Retail electric revenues
Residential	$	2,049	$	736	$	1,236	$	77	$	—	$	—
Commercial	1,613		508		1,023		82		—		—
Industrial	962		445		434		83		—		—
Other	30		3		25		2		—		—
Total retail electric revenues	4,654		1,692		2,718		244		—		—
Natural gas distribution revenues
Residential	287		—		—		—		—		287
Commercial	69		—		—		—		—		69
Transportation	304		—		—		—		—		304
Industrial	5		—		—		—		—		5
Other	63		—		—		—		—		63
Total natural gas distribution revenues	728		—		—		—		—		728
Wholesale electric revenues
PPA energy revenues	265		55		22		1		192		—
PPA capacity revenues	153		23		32		15		99		—
Non-PPA revenues	54		27		2		95		50		—
Total wholesale electric revenues	472		105		56		111		341		—
Other natural gas revenues
Gas marketing services	68		—		—		—		—		68
Other	6		—		—		—		—		6
Total other natural gas revenues	74		—		—		—		—		74
Other revenues	419		62		185		10		11		—
Total revenue from contracts with customers	6,347		1,859		2,959		365		352		802
Other revenue sources(*)	116		14		(84)		(1)		172		29
Total operating revenues	$	6,463	$	1,873	$	2,875	$	364	$	524	$	831

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Six Months Ended June 30, 2024
Operating revenues
Retail electric revenues
Residential	$	3,900	$	1,501	$	2,252	$	147	$	—	$	—
Commercial	3,084		976		1,955		153		—		—
Industrial	1,834		855		817		162		—		—
Other	60		6		50		4		—		—
Total retail electric revenues	8,878		3,338		5,074		466		—		—
Natural gas distribution revenues
Residential	1,032		—		—		—		—		1,032
Commercial	245		—		—		—		—		245
Transportation	666		—		—		—		—		666
Industrial	21		—		—		—		—		21
Other	176		—		—		—		—		176
Total natural gas distribution revenues	2,140		—		—		—		—		2,140
Wholesale electric revenues
PPA energy revenues	537		112		40		2		394		—
PPA capacity revenues	304		46		64		31		196		—
Non-PPA revenues	112		68		2		187		110		—
Total wholesale electric revenues	953		226		106		220		700		—
Other natural gas revenues
Gas marketing services	300		—		—		—		—		300
Other	11		—		—		—		—		11
Total other natural gas revenues	311		—		—		—		—		311
Other revenues	746		114		337		22		21		—
Total revenue from contracts with customers	13,028		3,678		5,517		708		721		2,451
Other revenue sources(*)	81		(14)		(244)		(2)		276		87
Total operating revenues	$	13,109	$	3,664	$	5,273	$	706	$	997	$	2,538

(*)Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs 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.

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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, 2025 and December 31, 2024:


	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At June 30, 2025	$	3,106	$	778	$	1,485	$	133	$	132	$	451
At December 31, 2024	3,048		783		1,244		113		106		660
Contract Assets
At June 30, 2025	$	304	$	—	$	134	$	—	$	—	$	74
At December 31, 2024	323		3		184		—		—		72
Contract Liabilities
At June 30, 2025	$	170	$	14	$	73	$	2	$	1	$	—
At December 31, 2024	140		11		34		—		2		3

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 the 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, 2025 and December 31, 2024, Southern Company's unregulated distributed generation business had contract assets of $95 million and $67 million, respectively, and contract liabilities of $81 million and $95 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, 2025, which were included in contract liabilities at December 31, 2024, were $44 million and $72 million, respectively, for Southern Company, $11 million and $16 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

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to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at June 30, 2025 are expected to be recognized as follows:


	2025 (remaining)		2026		2027		2028		2029		Thereafter
	(in millions)
Southern Company	$	548	$	535	$	405	$	343	$	309	$	2,636
Alabama Power	49		6		4		1		—		—
Georgia Power	37		43		18		15		2		27
Mississippi Power(*)	31		66		69		73		—		—
Southern Power(*)	183		331		340		316		312		2,609

(*)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, 2025 and 2024 was as follows:


	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
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

Three Months Ended June 30, 2024
Lease income - interest income on sales-type leases	$	7	$	—	$	—	$	5	$	2	$	—
Lease income - operating leases	35		2		9		1		22		9
Variable lease income	129		—		—		—		139		—
Total lease income	$	171	$	2	$	9	$	6	$	163	$	9

Six Months Ended June 30, 2024
Lease income - interest income on sales-type leases	$	14	$	—	$	—	$	9	$	5	$	—
Lease income - operating leases	71		5		16		2		43		18
Variable lease income	201		—		—		—		218		—
Total lease income	$	286	$	5	$	16	$	11	$	266	$	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.

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(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, 2025 and December 31, 2024, Southern Holdings had equity method investments totaling $115 million and $128 million, respectively, primarily related to investments in venture capital funds focused on energy and utility investments. The net losses from these investments totaled $14 million and $20 million for the three and six months ended June 30, 2025, respectively. Earnings/losses from these investments for the three and six months ended June 30, 2024 were immaterial.

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 and SP Wind

At June 30, 2025 and December 31, 2024, SP Solar had total assets of $5.3 billion and $5.4 billion, respectively, total liabilities of $360 million and $372 million, respectively, and noncontrolling interests of $1.0 billion. 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.

At June 30, 2025 and December 31, 2024, SP Wind had total assets of $2.0 billion, total liabilities of $247 million and $177 million, respectively, and noncontrolling interests of $34 million and $35 million, respectively. Under the terms of the limited liability agreement, distributions without Class A member consent are limited to available cash and SP Wind is obligated to distribute all such available cash to its members each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. Cash distributions from SP Wind are generally allocated 60% to Southern Power and 40% to the three financial investors in accordance with the limited liability agreement.

Southern Power consolidates both SP Solar and SP Wind, as the primary beneficiary, since it controls the most significant activities of each entity, including operating and maintaining their assets. Certain transfers and sales of the assets in the VIEs 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.

Subsequent to June 30, 2025, Southern Power notified the Class A members of its intent to exercise the option to purchase all Class A membership interests in the SP Wind tax equity partnership on December 31, 2025 under the terms of the limited liability agreement.

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, 2025 and December 31, 2024, the other VIEs had total assets of $1.6 billion, total liabilities of $229 million and $224 million, respectively, and noncontrolling interests of $657 million and $691 million, respectively.

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(UNAUDITED)

Under the terms of the partnership agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent.

Southern Company Gas

The carrying amounts of Southern Company Gas' equity method investments at June 30, 2025 and December 31, 2024 were as follows:


Investment Balance	At June 30, 2025		At December 31, 2024
	(in millions)
SNG	$	1,266	$	1,245
Other	34		34
Total	$	1,300	$	1,279

The earnings from Southern Company Gas' equity method investment in SNG were $23 million and $32 million for the three months ended June 30, 2025 and 2024, respectively, and $62 million and $76 million for the six months ended June 30, 2025 and 2024, respectively. The earnings from Southern Company Gas' other equity method investments were immaterial for all periods presented.

(F) FINANCING

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, 2025, committed credit arrangements with banks were as follows:


	Expires
Company	2026		2027		2030		Total		Unused		Expires within One Year
	(in millions)
Southern Company parent(a)	$	—	$	500	$	2,500	$	3,000	$	2,999	$	—
Alabama Power(b)	665		—		700		1,365		1,364		—
Georgia Power	—		—		2,050		2,050		2,026		—
Mississippi Power(a)	—		125		150		275		275		—
Southern Power(a)(c)	—		—		600		600		600		—
Southern Company Gas(d)	—		—		1,600		1,600		1,598		—
SEGCO	30		—		—		30		30		30
Southern Company	$	695	$	625	$	7,600	$	8,920	$	8,892	$	30

(a)Arrangement expiring in 2030 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, Southern Power, and Mississippi Power may be adjusted.

(b)Includes $15 million expiring in 2026 at Alabama Property Company, a wholly-owned subsidiary of Alabama Power, of which $14 million was unused at June 30, 2025. Alabama Power is not party to this arrangement.

(c)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 2028, respectively, of which $17 million and $4 million, respectively, was unused at June 30, 2025. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(d)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 2030. Southern Company Gas' committed credit arrangement expiring in 2030 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 2030, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

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(UNAUDITED)

As reflected in the table above, in March 2025, (i) Southern Company and Southern Power amended and restated their combined multi-year credit arrangement to include Mississippi Power, increase the total credit arrangement from $2.45 billion to $3.25 billion (currently allocated $2.50 billion for Southern Company, $600 million for Southern Power, and $150 million for Mississippi Power), and extend the maturity date from 2029 to 2030; (ii) Southern Company increased its $150 million credit arrangement to $500 million and extended the maturity date from 2025 to 2027; (iii) Georgia Power increased its $1.75 billion credit arrangement to $2.05 billion and extended the maturity date from 2029 to 2030; and (iv) Southern Company Gas Capital, along with Nicor Gas, increased its $1.5 billion credit arrangement to $1.6 billion (currently allocated $800 million for each of Southern Company Gas Capital and Nicor Gas). Also in March 2025, (i) Georgia Power terminated $300 million of credit arrangements expiring in 2025, (ii) Mississippi Power terminated $150 million of credit arrangements expiring in 2027, and (iii) Nicor Gas terminated a $100 million credit arrangement expiring in 2025. Alabama Power and Southern Company Gas Capital, along with Nicor Gas, entered into agreements in March 2025 to extend the maturity date of each of their respective multi-year credit agreements in May 2025 from 2029 to 2030. In May and June 2025, SEGCO amended its credit arrangements aggregating $30 million, which extended the maturity dates from 2025 to 2026.

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, 2025, 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, 2025, 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 $69 million at Mississippi Power). Subsequent to June 30, 2025, Mississippi Power repaid at maturity approximately $11 million of its $69 million variable rate demand revenue bonds. In addition, at June 30, 2025, Alabama Power and Georgia Power had approximately $280 million and $501 million, respectively, of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months. Alabama Power's $280 million of fixed rate revenue bonds are classified as securities due within one year on its balance sheets as they are not covered by long-term committed credit. All other 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.

Convertible Senior Notes

In May 2025, Southern Company issued $1.65 billion aggregate principal amount of Series 2025A 3.25% Convertible Senior Notes due June 15, 2028 (Series 2025A Convertible Senior Notes). Southern Company used a portion of the proceeds from the Series 2025A Convertible Senior Notes to repurchase approximately $781.6 million of the $1.725 billion aggregate principal amount outstanding of its Series 2023A 3.875% Convertible Senior Notes due December 15, 2025 and approximately $328.1 million of the $1.5 billion aggregate principal amount outstanding of its Series 2024A 4.50% Convertible Senior Notes due June 15, 2027, in each case, through privately negotiated transactions with a limited number of holders thereof. Southern Company evaluated these repurchases and determined that all of the repurchased notes were accounted for as extinguishment of debt. As a result of these transactions, Southern Company recognized a $129 million loss on extinguishment of debt in the second quarter 2025 within interest expense in the consolidated statements of income.

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(UNAUDITED)

Interest on the Series 2025A Convertible Senior Notes is payable semiannually, beginning December 15, 2025. The Series 2025A Convertible Senior Notes will mature on June 15, 2028, unless earlier converted or repurchased, but are not redeemable at the option of Southern Company. The Series 2025A Convertible Senior Notes are direct, unsecured, and unsubordinated obligations of Southern Company, ranking equally with all of Southern Company's other unsecured and unsubordinated indebtedness from time to time outstanding, and are effectively subordinated to all secured indebtedness of Southern Company.

Holders may convert their Series 2025A Convertible Senior Notes at their option prior to the close of business on the business day preceding March 15, 2028, but only under the following circumstances:

•during any calendar quarter (and only during such calendar quarter), if the last reported sale price of Southern Company's common stock for at least 20 trading days (whether or not consecutive) during the period of 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day as determined by Southern Company;

•during the five business day period after any 10 consecutive trading day period (Measurement Period) in which the trading price per $1,000 principal amount of Series 2025A Convertible Senior Notes, as determined by Southern Company following a request by a holder of Series 2025A Convertible Senior Notes, for each trading day of the Measurement Period was less than 98% of the product of the last reported sale price of the common stock and the conversion rate on each such trading day; or

•upon the occurrence of certain corporate events specified in the indenture governing the Series 2025A Convertible Senior Notes.

On or after March 15, 2028, a holder may convert all or any portion of its Series 2025A Convertible Senior Notes at any time prior to the close of business on the second scheduled trading day immediately preceding the maturity date regardless of the foregoing conditions.

Southern Company will settle conversions of the Series 2025A Convertible Senior Notes by paying cash up to the aggregate principal amount of the Series 2025A Convertible Senior Notes to be converted and paying or delivering, as the case may be, cash, shares of common stock, or a combination of cash and shares of common stock, at Southern Company's election, in respect of the remainder, if any, of Southern Company's conversion obligation in excess of the aggregate principal amount of the Series 2025A Convertible Senior Notes being converted. The Series 2025A Convertible Senior Notes are initially convertible at a rate of 8.8077 shares of common stock per $1,000 principal amount converted, which is approximately equal to $113.54 per share of common stock. The conversion rate will be subject to adjustment upon the occurrence of certain specified events but will not be adjusted for accrued and unpaid interest. In addition, upon the occurrence of a make-whole fundamental change (as defined in the indenture governing the Series 2025A Convertible Senior Notes), Southern Company will, in certain circumstances, increase the conversion rate by a number of additional shares of common stock for conversions in connection with the make-whole fundamental change.

Upon the occurrence of a fundamental change, other than an excluded fundamental change (each as defined in the indenture governing the Series 2025A Convertible Senior Notes), holders of the Series 2025A Convertible Senior Notes may require Southern Company to purchase all or a portion of their Series 2025A Convertible Senior Notes, in principal amounts equal to $1,000 or an integral multiple thereof, for cash at a price equal to 100% of the principal amount of the Series 2025A Convertible Senior Notes to be purchased plus any accrued and unpaid interest.

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(UNAUDITED)

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.

The table below reflects shares of Southern Company common stock sold under separate forward sale contracts with forward purchasers during the six months ended June 30, 2025.


Shares Sold	Initial Forward Price per Share	To be Settled On or Before
292,694(a)	$83.3293	December 31, 2025
563,386	$87.9027	December 31, 2025
1,000,000	$88.7502	June 30, 2026
1,000,000	$88.7739	June 30, 2026
1,000,000	$91.2856	June 30, 2026
1,000,000	$89.1444	June 30, 2026
1,000,000	$88.8490	June 30, 2026
1,000,000	$88.8903	June 30, 2026
1,000,000	$90.9196	June 30, 2026
1,255,000	$91.0566	June 30, 2026
1,324,942	$88.7048	December 31, 2026
2,277,113	$88.3227	December 31, 2026
3,130,641	$88.2823	December 31, 2026
3,255,866	$89.4692	December 31, 2026
1,849,629(b)	$90.6617(b)	December 31, 2026

(a)The total number of shares sold under this forward sale contract is 436,614, of which the first 143,920 shares were sold in December 2024.

(b)The total number of shares sold under this forward sale contract is 3,850,000, of which the remaining 2,000,371 shares were sold subsequent to June 30, 2025. The initial forward price was determined after the completion of sales by the forward seller in July 2025.

As of June 30, 2025, Southern Company had entered into separate forward sale contracts with forward purchasers for a total of 25,093,562 shares of common stock, of which 23,093,191 shares had been sold by the forward sellers, and no shares had been settled under the forward sale contracts.

Each initial forward price is subject to adjustment under certain circumstances as specified in the forward sales contract. Southern Company may settle these forward transactions in shares, cash, or net shares.

Earnings per Share

For Southern Company, the only difference in computing basic and diluted earnings per share (EPS) is attributable to awards outstanding under stock-based compensation plans, forward sale contracts pursuant to the equity distribution agreement, and convertible senior notes. EPS dilution resulting from stock-based compensation plans and the forward sale contracts is determined using the treasury stock method, and EPS dilution resulting from the convertible senior notes is determined using the net share settlement method. See "Convertible Senior Notes" and "Equity Distribution Agreement" herein and Note 8 to the financial statements under "Convertible Senior Notes"

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(UNAUDITED)

and "Equity Distribution Agreement" 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,
	2025	2024	2025	2024
	(in millions)
As reported shares	1,101	1,096	1,100	1,095
Effect of stock-based compensation	6	6	6	6
Effect of convertible senior notes	1	—	1	—
Diluted shares	1,108	1,102	1,107	1,101

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.

For the three and six months ended June 30, 2025, dilution resulting from forward sale contracts was immaterial.

(G) INCOME TAXES

See Note 10 to the financial statements in Item 8 of the Form 10-K for additional tax information.

Current and Deferred Income Taxes

In 2024, Alabama Power, Georgia Power, and Southern Power entered into agreements with non-affiliated parties to transfer ITCs and PTCs at a discount to the generated credit value in 2024, 2025, and 2026. During the first six months of 2025, Alabama Power, Georgia Power, and Southern Power received cash of $44 million, $28 million, and $13 million, respectively, from credits transferred. 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. The Southern Company system continues to explore the ability to efficiently monetize its tax credits through third-party transfer agreements.

Pursuant to certain joint ownership agreements, Georgia Power paid $81 million in the second quarter 2025 to the other Vogtle Owners for advanced nuclear PTCs for Plant Vogtle Units 3 and 4. The gain was recognized in 2025 as an income tax benefit and was immaterial.

Tax Credit and Net Operating Loss Carryforwards

Southern Company's federal PTC and ITC carryforwards are expected to be fully utilized by 2030. The utilization of each Registrant's estimated federal and state tax attributes and related valuation allowances could be impacted by numerous factors, including the acquisition of additional renewable energy and battery energy storage projects, changes in taxable income projections, and potential income tax rate changes. See Notes (B) and (K) under "Georgia Power" and "Southern Power," respectively, herein for information regarding current renewable energy and battery energy storage projects.

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 21.1% for the six months ended June 30, 2025 compared to 18.5% for the corresponding period in 2024. The effective tax rate increase was primarily due to charges to a valuation allowance on certain state tax credit carryforwards at Georgia Power, the recognition of certain state tax positions

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(UNAUDITED)

from amended returns in the second quarter 2024 at Georgia Power, and a decrease in the flowback of certain excess deferred income taxes at Alabama Power, partially offset by increases in the flowback of excess state deferred income taxes and in the generation of advanced nuclear PTCs at Georgia Power.

Alabama Power

Alabama Power's effective tax rate was 23.0% for the six months ended June 30, 2025 compared to 21.0% for the corresponding period in 2024. The effective tax rate increase was primarily due to a decrease in the flowback of certain excess deferred income taxes.

Georgia Power

Georgia Power's effective tax rate was 21.7% for the six months ended June 30, 2025 compared to 18.4% for the corresponding period in 2024. The effective tax rate increase was primarily due to charges to a valuation allowance on certain state tax credit carryforwards and the recognition of certain state tax positions from amended returns in the second quarter 2024, partially offset by increases in the flowback of excess state deferred income taxes and in the generation of advanced nuclear PTCs.

Mississippi Power

Mississippi Power's effective tax rate was 22.8% for the six months ended June 30, 2025 compared to 18.4% for the corresponding period in 2024. The effective tax rate increase was primarily due to a decrease in the flowback of certain excess deferred income taxes.

Southern Power

Southern Power's effective tax benefit rate was (7.0)% for the six months ended June 30, 2025 compared to (0.8)% for the corresponding period in 2024. The effective tax rate decrease was primarily due to a change in pre-tax earnings attributable to Southern Power, including the impact of accelerated depreciation related to wind repowering projects and changes in tax rates resulting from tax legislation enacted by the State of Georgia in the second quarters of 2024 and 2025. See Note (K) under "Southern Power – Wind Repowering Projects" herein for additional information.

Southern Company Gas

Southern Company Gas' effective tax rate was 23.7% for the six months ended June 30, 2025 compared to 25.1% for the corresponding period in 2024. The effective tax rate decrease was primarily due to an increase in the flowback of excess state deferred income taxes.

Unrecognized Tax Benefits

Southern Company's, Alabama Power's, and Georgia Power's unrecognized tax positions balances at June 30, 2025 were $382 million, $144 million, and $188 million, respectively. At December 31, 2024, Southern Company's and Georgia Power's unrecognized tax positions balances were $82 million and $34 million, respectively, and Alabama Power had no unrecognized tax positions. The increases from prior periods are related to Alabama Power's and Georgia Power's ability to meet prevailing wage requirements related to existing zero-emission nuclear power PTCs and will not impact Southern Company's, Alabama Power's, and Georgia Power's effective tax rates if recognized. The ultimate outcome of this unrecognized tax benefit, which is expected to be resolved within the next 12 months, is dependent on acceptance by the IRS and cannot be determined at this time.

(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, 2025. The Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly

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(UNAUDITED)

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, 2025 and 2024 are presented in the following tables.

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(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)

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(UNAUDITED)


	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2024
Pension Plans
Service cost	$	73	$	17	$	17	$	3	$	1	$	7
Interest cost	158		37		48		7		2		11
Expected return on plan assets	(315)		(76)		(98)		(15)		(4)		(21)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	13		4		4		2		1		—
Net periodic pension income	$	(71)	$	(18)	$	(28)	$	(3)	$	—	$	—

Postretirement Benefits
Service cost	$	3	$	1	$	1	$	—	$	—	$	—
Interest cost	17		4		5		—		—		2
Expected return on plan assets	(22)		(8)		(8)		—		—		(2)
Amortization:

Regulatory asset	—		—		—		—		—		2
Net gain	(4)		(2)		—		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(6)	$	(5)	$	(2)	$	—	$	—	$	1

Six Months Ended June 30, 2024
Pension Plans
Service cost	$	146	$	34	$	35	$	6	$	3	$	14
Interest cost	317		74		96		14		4		21
Expected return on plan assets	(631)		(153)		(197)		(29)		(8)		(43)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		8
Net loss	27		8		9		2		1		—
Net periodic pension income	$	(141)	$	(37)	$	(56)	$	(7)	$	—	$	(1)

Postretirement Benefits
Service cost	$	7	$	2	$	2	$	—	$	—	$	—
Interest cost	33		8		11		1		—		4
Expected return on plan assets	(44)		(17)		(16)		—		—		(4)
Amortization:
Prior service costs	1		—		—		—		—		—
Regulatory asset	—		—		—		—		—		3
Net gain	(8)		(2)		(1)		(1)		—		(3)
Net periodic postretirement benefit income	$	(11)	$	(9)	$	(4)	$	—	$	—	$	—

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

(I) FAIR VALUE MEASUREMENTS

At June 30, 2025, 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, 2025	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)	$	11	$	122	$	—	$	—	$	133
Interest rate derivatives	—		9		—		—		9
Foreign currency derivatives	—		34		—		—		34
Investments in trusts:(b)
Domestic equity	876		268		—		—		1,144
Foreign equity	164		206		—		—		370
U.S. Treasury and government agency securities	—		355		—		—		355
Municipal bonds	—		48		—		—		48
Pooled funds – fixed income	—		5		—		—		5
Corporate bonds	—		495		—		—		495
Mortgage- and asset-backed securities	—		122		—		—		122
Private equity	—		—		—		191		191
Cash and cash equivalents	1		—		—		—		1
Other	33		3		—		9		45
Investments, available-for-sale:
U.S. Treasury and government agency securities	1		10		—		—		11

Corporate bonds	—		2		—		—		2
Mortgage- and asset-backed securities	—		9		—		—		9
Cash equivalents and restricted cash	631		18		—		—		649
Other investments	10		37		8		—		55
Total	$	1,727	$	1,743	$	8	$	200	$	3,678
Liabilities:
Energy-related derivatives(a)	$	6	$	66	$	—	$	—	$	72
Interest rate derivatives	—		206		—		—		206
Foreign currency derivatives	—		22		—		—		22
Contingent consideration	3		—		14		—		17
Other	—		13		11		—		24
Total	$	9	$	307	$	25	$	—	$	341

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(UNAUDITED)


	Fair Value Measurements Using
At June 30, 2025	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	$	—	$	47	$	—	$	—	$	47

Nuclear decommissioning trusts:(b)
Domestic equity	470		258		—		—		728
Foreign equity	164		—		—		—		164
U.S. Treasury and government agency securities	—		17		—		—		17
Municipal bonds	—		1		—		—		1
Corporate bonds	—		299		—		—		299
Mortgage- and asset-backed securities	—		33		—		—		33
Private equity	—		—		—		191		191
Other	11		1		—		9		21
Cash equivalents	145		18		—		—		163
Other investments	—		37		—		—		37
Total	$	790	$	711	$	—	$	200	$	1,701
Liabilities:
Energy-related derivatives	$	—	$	23	$	—	$	—	$	23



Georgia Power
Assets:
Energy-related derivatives	$	—	$	35	$	—	$	—	$	35

Nuclear decommissioning trusts:(b)
Domestic equity	406		1		—		—		407
Foreign equity	—		205		—		—		205
U.S. Treasury and government agency securities	—		338		—		—		338
Municipal bonds	—		47		—		—		47
Corporate bonds	—		196		—		—		196
Mortgage- and asset-backed securities	—		89		—		—		89
Other	22		2		—		—		24

Total	$	428	$	913	$	—	$	—	$	1,341
Liabilities:
Energy-related derivatives	$	—	$	19	$	—	$	—	$	19
Interest rate derivatives	—		1		—		—		1
Total	$	—	$	20	$	—	$	—	$	20

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(UNAUDITED)


	Fair Value Measurements Using
At June 30, 2025	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	$	—	$	28	$	—	$	—	$	28

Cash equivalents	2		—		—		—		2
Total	$	2	$	28	$	—	$	—	$	30
Liabilities:
Energy-related derivatives	$	—	$	19	$	—	$	—	$	19



Southern Power
Assets:
Energy-related derivatives	$	—	$	4	$	—	$	—	$	4
Foreign currency derivatives	—		26		—		—		26

Total	$	—	$	30	$	—	$	—	$	30
Liabilities:


Contingent consideration	3		—		14		—		17
Other	—		13		11		—		24
Total	$	3	$	13	$	25	$	—	$	41

Southern Company Gas
Assets:
Energy-related derivatives(a)	$	11	$	8	$	—	$	—	$	19
Interest rate derivatives	—		4		—		—		4
Non-qualified deferred compensation trusts:
Domestic equity	—		9		—		—		9
Foreign equity	—		1		—		—		1
Pooled funds – fixed income	—		5		—		—		5
Cash and cash equivalents	1		—		—		—		1
Cash equivalents	212		—		—		—		212

Total	$	224	$	27	$	—	$	—	$	251
Liabilities:
Energy-related derivatives(a)	$	6	$	5	$	—	$	—	$	11
Interest rate derivatives	—		63		—		—		63

Total	$	6	$	68	$	—	$	—	$	74

(a)Excludes cash collateral of $6 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

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(UNAUDITED)

the three and six months ended June 30, 2025 and 2024. 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)	2025		2024		2025		2024
	(in millions)
Southern Company	$	165	$	32	$	159	$	135
Alabama Power	99		19		86		87
Georgia Power	66		13		73		48

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

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(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, 2025, 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 $200 million and unfunded commitments related to the private market investments totaled $101 million. Private market investments include high-quality private equity funds across several market sectors, funds that invest in real estate assets, and a private credit fund. 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, 2025, 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	$	68.1	$	11.5	$	19.3	$	1.8	$	2.7	$	8.5
Fair value	63.6		10.3		17.7		1.6		2.7		7.5

(*)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.

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(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 of Southern Company Gas 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.

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(UNAUDITED)

At June 30, 2025, 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(*)	415	2030	2028
Alabama Power	130	2028	—
Georgia Power	110	2028	—
Mississippi Power	102	2029	—
Southern Power	8	2030	2025
Southern Company Gas(*)	65	2027	2028

(*)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 78.6 million mmBtu long natural gas positions and 13.6 million mmBtu short natural gas positions at June 30, 2025, 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 2.4 million mmBtu for Southern Company, which includes 0.6 million mmBtu for Alabama Power, 0.9 million mmBtu for Georgia Power, 0.4 million mmBtu for Mississippi Power, and 0.5 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, 2026 is immaterial for Southern Company, 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.

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(UNAUDITED)

At June 30, 2025, 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, 2025
	(in millions)					(in millions)
Cash Flow Hedges of Forecasted Debt
Southern Company Gas	$	250	4.03%	N/A	September 2025	$	4
Georgia Power	275		4.29%	N/A	August 2025	(1)
Fair Value Hedges of Existing Debt
Southern Company parent	400		1-month SOFR + 0.80%	1.75%	March 2028	(30)
Southern Company parent	1,000		1-month SOFR + 2.48%	3.70%	April 2030	(106)
Southern Company parent	565		1-month SOFR + 1.56%	6.50%	March 2045	(1)
Southern Company Gas	500		1-month SOFR + 0.49%	1.75%	January 2031	(63)
Southern Company	$	2,990				$	(197)

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, 2026 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, including Southern Power, 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.

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(UNAUDITED)

At June 30, 2025, 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, 2025
	(in millions)			(in millions)				(in millions)
Cash Flow Hedges of Existing Debt
Southern Power	$	564	3.78%	€	500	1.85%	June 2026	$	26
Fair Value Hedges of Existing Debt
Southern Company parent	1,476		3.39%	1,250		1.88%	September 2027	(14)
Southern Company	$	2,040		€	1,750			$	12

For cash flow hedges of foreign currency derivatives, the estimated pre-tax gains expected to be reclassified from accumulated OCI to earnings for the 12-month period ending June 30, 2026 are $26 million for Southern Power.

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. These agreements may contain provisions that permit netting across product lines and against cash collateral. 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.

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(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, 2025				At December 31, 2024
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	$	57	$	38	$	33	$	82
Non-current	63		26		42		40


Total derivatives designated as hedging instruments for regulatory purposes	120		64		75		122
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Current	5		2		4		3
Non-current	4		—		4		—
Interest rate derivatives:
Current	9		57		—		61
Non-current	—		149		—		208
Foreign currency derivatives:
Current	26		22		—		36
Non-current	8		—		—		182
Total derivatives designated as hedging instruments in cash flow and fair value hedges	52		230		8		490
Energy-related derivatives not designated as hedging instruments

Current	4		6		5		3
Non-current	—		—		1		—

Total derivatives not designated as hedging instruments	4		6		6		3
Gross amounts recognized	176		300		89		615
Gross amounts offset(a)	(56)		(62)		(44)		(61)
Net amounts recognized in the Balance Sheets(b)	$	120	$	238	$	45	$	554

Alabama Power
Energy-related derivatives designated as hedging instruments for regulatory purposes

Current	$	23	$	13	$	11	$	30
Non-current	24		10		15		12
Total derivatives designated as hedging instruments for regulatory purposes	47		23		26		42






Gross amounts offset	(20)		(20)		(19)		(19)
Net amounts recognized in the Balance Sheets	$	27	$	3	$	7	$	23

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(UNAUDITED)


	At June 30, 2025				At December 31, 2024
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	$	15	$	11	$	6	$	32
Non-current	20		6		13		9
Total derivatives designated as hedging instruments for regulatory purposes	35		17		19		41
Interest rate derivatives designated as hedging instruments in cash flow and fair value hedges

Current	—		1		—		—


Energy-related derivatives not designated as hedging instruments

Current	—		2		—		1

Gross amounts recognized	35		20		19		42
Gross amounts offset	(16)		(16)		(15)		(15)
Net amounts recognized in the Balance Sheets	$	19	$	4	$	4	$	27

Mississippi Power
Energy-related derivatives designated as hedging instruments for regulatory purposes

Current	$	9	$	9	$	5	$	15
Non-current	19		10		14		19
Total derivatives designated as hedging instruments for regulatory purposes	28		19		19		34






Gross amounts offset	(16)		(16)		(17)		(17)
Net amounts recognized in the Balance Sheets	$	12	$	3	$	2	$	17

Southern Power
Derivatives designated as hedging instruments in cash flow hedges
Energy-related derivatives:
Current	$	1	$	—	$	1	$	—
Non-current	3		—		3		—
Foreign currency derivatives:
Current	26		—		—		11
Non-current	—		—		—		40
Total derivatives designated as hedging instruments in cash flow hedges	30		—		4		51







Net amounts recognized in the Balance Sheets	$	30	$	—	$	4	$	51

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(UNAUDITED)


	At June 30, 2025				At December 31, 2024
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	$	10	$	5	$	11	$	5


Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Current	4		2		3		3
Non-current	1		—		1		—
Interest rate derivatives:
Current	4		15		—		17
Non-current	—		48		—		67
Total derivatives designated as hedging instruments in cash flow and fair value hedges	9		65		4		87
Energy-related derivatives not designated as hedging instruments

Current	4		4		5		2
Non-current	—		—		1		—

Total derivatives not designated as hedging instruments	4		4		6		2
Gross amounts recognized	23		74		21		94
Gross amounts offset(a)	(4)		(10)		7		(10)
Net amounts recognized in the Balance Sheets(b)	$	19	$	64	$	28	$	84

(a)Gross amounts offset includes cash collateral held on deposit in broker margin accounts of $6 million and $17 million at June 30, 2025 and December 31, 2024, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives at June 30, 2025 and December 31, 2024.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

At June 30, 2025 and December 31, 2024, 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 Sheet
Derivative Category and Balance Sheet Location	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Company Gas
	(in millions)
At June 30, 2025:
Energy-related derivatives:
Other regulatory assets, current	$	(8)	$	(3)	$	(1)	$	(3)	$	(1)



Other regulatory liabilities, current	26		13		5		3		5
Other regulatory liabilities, deferred	37		14		14		9		—
Total energy-related derivative gains (losses)	$	55	$	24	$	18	$	9	$	4

At December 31, 2024:
Energy-related derivatives:
Other regulatory assets, current	$	(61)	$	(23)	$	(26)	$	(11)	$	(1)
Other regulatory assets, deferred	(5)		—		—		(5)		—
Other regulatory liabilities, current	8		4		—		—		4
Other regulatory liabilities, deferred	8		3		4		1		—
Total energy-related derivative gains (losses)	$	(50)	$	(16)	$	(22)	$	(15)	$	3

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

For the three and six months ended June 30, 2025 and 2024, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI for the applicable Registrants were as follows:


Gain (Loss) Recognized in OCI on Derivatives	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	(13)	$	3	$	6	$	(5)
Interest rate derivatives	9		1		5		24
Foreign currency derivatives	47		(6)		67		(20)
Fair value hedges(*):
Foreign currency derivatives	3		(4)		(13)		(4)
Total	$	46	$	(6)	$	65	$	(5)




Georgia Power
Cash flow hedges:
Interest rate derivatives	$	5	$	—	$	3	$	16


Mississippi Power
Cash flow hedges:
Interest rate derivatives	$	—	$	—	$	—	$	7

Southern Power
Cash flow hedges:
Energy-related derivatives	$	(1)	$	1	$	2	$	—

Foreign currency derivatives	47		(6)		67		(20)
Total	$	46	$	(5)	$	69	$	(20)

Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	(12)	$	2	$	4	$	(5)
Interest rate derivatives	4		1		4		1
Total	$	(8)	$	3	$	8	$	(4)

(*)Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded in OCI.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

For the three and six months ended June 30, 2025 and 2024, 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,
		2025		2024		2025		2024
		(in millions)
Southern Company
Fuel	Energy-related cash flow hedges	$	—	$	(1)	$	1	$	(2)
Cost of natural gas	Energy-related cash flow hedges	1		(7)		—		(30)
Other operations and maintenance	Energy-related cash flow hedges	—		—		—		(1)
Interest expense, net of amounts capitalized	Interest rate cash flow hedges	(3)		(4)		(6)		(8)
	Foreign currency cash flow hedges	(2)		(3)		(5)		(6)
	Interest rate fair value hedges	29		—		69		(31)
Other income (expense), net	Foreign currency cash flow hedges	45		(5)		67		(17)
	Foreign currency fair value hedges	115		(18)		155		21
	Amount excluded from effectiveness testing recognized in earnings	(3)		5		13		5







Southern Power
Fuel	Energy-related cash flow hedges	$	—	$	(1)	$	1	$	(2)
Interest expense, net of amounts capitalized	Foreign currency cash flow hedges	(2)		(3)		(5)		(6)
Other income (expense), net	Foreign currency cash flow hedges	45		(5)		67		(17)
Southern Company Gas
Cost of natural gas	Energy-related cash flow hedges	$	1	$	(7)	$	—	$	(30)
Operations and maintenance	Energy-related cash flow hedges	—		—		—		(1)

Interest expense, net of amounts capitalized	Interest rate fair value hedges	3		(6)		21		(10)

At June 30, 2025 and December 31, 2024, 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, 2025		At December 31, 2024		At June 30, 2025		At December 31, 2024
	(in millions)
Southern Company

Long-term debt	$	(3,798)	$	(2,936)	$	164	$	242

Southern Company Gas

Long-term debt	$	(442)	$	(422)	$	56	$	75

Pre-tax gains (losses) on energy-related derivatives not designated as hedging instruments were $(14) million and $16 million for the three months ended June 30, 2025 and 2024, respectively, and $(6) million and $63 million for the six months ended June 30, 2025 and 2024, respectively, and reflected in cost of natural gas on the statements of income of Southern Company and Southern Company Gas.

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(UNAUDITED)

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 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, 2025, 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 $35 million at June 30, 2025. For Southern Power, the fair value of foreign currency 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 $13 million at June 30, 2025. 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, 2025. 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, 2025, 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.

Southern Company Gas utilizes netting agreements whenever possible to mitigate exposure to counterparty credit risk. Netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty across product lines and against cash collateral, provided the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, counterparties are settled net, they are recorded on a gross basis on the balance sheet as energy marketing receivables and energy marketing payables.

The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of counterparty nonperformance.

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(UNAUDITED)

(K) ACQUISITIONS AND DISPOSITIONS

See Note 15 to the financial statements in Item 8 of the Form 10-K for additional information.

Alabama Power

On June 6, 2025, the FERC approved Alabama Power's acquisition of Tenaska Alabama Partners, L.P., which owns and operates the Lindsay Hill Generating Station. The ultimate outcome of this matter cannot be determined at this time. See Note (B) under "Alabama Power – Petition for Certificate of Convenience and Necessity" for additional information.

Mississippi Power

Southern Power

Construction Projects

During the six months ended June 30, 2025, Southern Power continued construction of the three phases of the 512-MW Millers Branch solar facility. At June 30, 2025, the total cost of construction incurred for the Millers Branch project was $537 million, which is primarily included in CWIP. The ultimate outcome of these matters cannot be determined at this time.

Project Facility

Resource

Approximate Nameplate Capacity

(MW)

Location

Projected COD

PPA Contract Period

Projects Under Construction at June 30, 2025

Millers Branch

Phase I

Solar

200

Haskell County, TX

Fourth quarter 2025

20 years

Phase II

Solar

180

Haskell County, TX

Second quarter 2026

15 years

Phase III

Solar

132

Haskell County, TX

Fourth quarter 2026

15 years

Wind Repowering Projects

During the six months ended June 30, 2025, Southern Power continued the development project to repower the Kay Wind facility. In addition, Southern Power committed to development projects to repower the Grant Plains, Grant Wind, and Wake Wind facilities. At June 30, 2025, the total cost of construction incurred related to the projects was

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

$89 million and is included 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

Projected COD

Projects Under Construction at June 30, 2025

Kay Wind(*)

Wind

200

Kay County, OK

Third quarter 2026

Grant Plains

Wind

147

Grant County, OK

Fourth quarter 2026

Grant Wind

Wind

152

Grant County, OK

Fourth quarter 2026

Wake Wind

Wind

257

Crosby & Floyd Counties, TX

Second quarter 2027

(*)The facility has a total capacity of 299 MWs, of which 200 MWs is projected to be repowered and is contracted under an amended PPA.

(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 renewable energy and 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 sale 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. Revenues from sales by Southern Power to the traditional electric operating companies were $114 million and $229 million for the three and six months ended June 30, 2025, respectively, and $86 million and $179 million for the three and six months ended June 30, 2024, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies and Southern Power were immaterial for all periods presented. The "All Other" column includes the Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications. All other inter-segment revenues are not material.

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.

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(UNAUDITED)

Financial data for business segments for the three and six months ended June 30, 2025 and 2024 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, 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(c)	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(c)	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 June 30, 2025
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	5,017	$	144	$	—	$	5,161
Total assets	108,676		12,817		(1,013)		120,480		26,376		146,856		2,417		(420)		148,853

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(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, 2024
Operating revenues	$	5,025	$	524	$	(93)	$	5,456	$	831	$	6,287	$	222	$	(46)	$	6,463
Other segment items(a)(e)	2,322		268		(93)		2,497		478		2,975		193		(43)		3,125
Depreciation and amortization	880		127		—		1,007		158		1,165		17		—		1,182
Earnings from equity method investments	—		—		—		—		32		32		(1)		—		31
Interest expense	323		30		—		353		83		436		259		(1)		694
Income taxes (benefit)	308		13		—		321		36		357		(67)		—		290
Segment net income (loss)(d)(e)	$	1,192	$	86	$	—	$	1,278	$	108	$	1,386	$	(181)	$	(2)	$	1,203

Six Months Ended June 30, 2024
Operating revenues	$	9,463	$	997	$	(189)	$	10,271	$	2,538	$	12,809	$	383	$	(83)	$	13,109
Other segment items(a)(e)	4,603		512		(189)		4,926		1,443		6,369		347		(60)		6,656
Depreciation and amortization	1,733		245		—		1,978		313		2,291		36		—		2,327
Earnings from equity method investments	2		—		—		2		76		78		(2)		1		77
Interest expense	635		59		—		694		167		861		508		(11)		1,358
Income taxes (benefit)	482		(1)		—		481		174		655		(142)		—		513
Segment net income (loss)(d)(e)	$	2,012	$	182	$	—	$	2,194	$	517	$	2,711	$	(368)	$	(11)	$	2,332

At December 31, 2024
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	5,017	$	144	$	—	$	5,161
Total assets	105,577		12,653		(1,025)		117,205		26,177		143,382		2,371		(573)		145,180

(a)Primarily consists of fuel, purchased power, cost of natural gas, cost of other sales, other operations and maintenance, 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 the Kay Wind, Grant Plains, and Grant Wind facilities of $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" herein and Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

(c)For all other, includes a pre-tax loss of $129 million ($97 million after tax) associated with the extinguishment of debt at the parent company. See Note (F) under "Convertible Senior Notes" herein for additional information.

(d)Attributable to Southern Company.

(e)For the traditional electric operating companies, includes a pre-tax credit to income at Georgia Power of $21 million ($16 million after tax) related to the estimated probable loss associated with the completion of Plant Vogtle Units 3 and 4, as well as a pre-tax gain at Georgia Power of approximately $114 million ($84 million after tax) related to the sale of transmission line assets under the integrated transmission system agreement. See Note 2 to the financial statements under "Georgia Power" in Item 8 of the Form 10-K for additional information.

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

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

services, losses (gains) on asset dispositions, impairment charges, amortization of cloud software, and, for Georgia Power, charges (credits) for estimated loss on Plant Vogtle Units 3 and 4. Alabama Power's utility operations and maintenance expenses are disaggregated into expenses related to Rate RSE and Rate CNP Compliance, which are not applicable to Georgia Power. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

Financial data for Alabama Power's and Georgia Power's significant segment expenses and other segment information for the three and six months ended June 30, 2025 and 2024 was as follows:


	Three Months Ended June 30,				Six Months Ended June 30,
	2025		2024		2025		2024
	(in millions)
Alabama Power
Operating revenues	$	1,968	$	1,873	$	3,980	$	3,664
Utility operations and maintenance
Rate RSE expenses	374		339		739		664
Rate CNP Compliance expenses	67		66		142		129
Total utility operations and maintenance	441		405		881		793
Other segment items(a)	544		519		1,152		1,033
Depreciation and amortization	371		364		741		725
Interest expense	116		114		225		224
Income taxes	115		102		226		187
Segment net income	$	381	$	369	$	755	$	702

Capital expenditures	$	599	$	470	$	1,159	$	921

Georgia Power
Operating revenues	$	3,110	$	2,875	$	6,148	$	5,273
Utility operations and maintenance	568		499		1,104		962
Other segment items(a)(b)	989		790		2,106		1,610
Depreciation and amortization	512		447		1,015		872
Interest expense	198		185		385		359
Income taxes	236		192		334		271
Segment net income(b)	$	607	$	762	$	1,204	$	1,199

Capital expenditures	$	1,676	$	1,320	$	3,313	$	2,353

(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, non-service cost-related retirement benefits income, and, for Georgia Power, charges (credits) for estimated loss on Plant Vogtle Units 3 and 4. Also includes earnings from equity method investments, which were immaterial for all periods presented.

(b)For the three and six months ended June 30, 2024, includes a pre-tax credit to income of $21 million ($16 million after tax) related to the estimated probable loss associated with the completion of Plant Vogtle Units 3 and 4, as well as a pre-tax gain of approximately $114 million ($84 million after tax) related to the sale of transmission line assets under the integrated transmission system agreement. See Note 2 to the financial statements under "Georgia Power" in Item 8 of the Form 10-K for additional information.

Mississippi Power's CODM utilizes segment expense information in the form of variances to budget to assess performance; therefore, Mississippi Power has no reportable significant segment expenses. Mississippi Power's segment information for revenues, depreciation and amortization, interest expense, and income taxes is reflected on its statements of income. Mississippi Power's earnings from equity method investments are included in other income (expense), net on its statements of income and were immaterial for all periods presented. Other segment items primarily consist of fuel and purchased power, other operations and maintenance, taxes other than income taxes, and non-service cost-related retirement benefits income and totaled $252 million and $528 million for the

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

three and six months ended June 30, 2025, respectively, and $221 million and $438 million for the three and six months ended June 30, 2024, respectively.

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. Southern Power's segment information for revenues, depreciation and amortization, interest expense, and income taxes (benefit) is reflected on its consolidated statements of income. Southern Power had no earnings from equity method investments for any period presented. Other segment items primarily consist of fuel, purchased power, other operations and maintenance, taxes other than income taxes, and net income (loss) attributable to noncontrolling interests and totaled $296 million and $599 million for the three and six months ended June 30, 2025, respectively, and $268 million and $512 million for the three and six months ended June 30, 2024, respectively.

For the three and six months ended June 30, 2025, depreciation and amortization includes accelerated depreciation of $42 million ($31 million after tax, net of noncontrolling interest impacts) and $69 million ($51 million after tax, net of noncontrolling interest impacts), respectively, related to the repowering of the Kay Wind, Grant Plains, and Grant Wind facilities. See Note (K) under "Southern Power – Wind Repowering Projects" herein and Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

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 and Illinois through SouthStar.

The "All Other" column includes segments and subsidiaries that fall below the quantitative threshold for separate disclosure, including storage and fuels operations.

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.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Financial data for business segments for the three and six months ended June 30, 2025 and 2024 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, 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	$	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 June 30, 2025	$	24,864	$	1,595	$	1,679	$	28,138	$	10,492	$	(12,254)	$	26,376

Three Months Ended June 30, 2024
Operating revenues	$	749	$	8	$	70	$	827	$	7	$	(3)	$	831
Other segment items(*)	420		2		52		474		7		(3)		478
Depreciation and amortization	152		1		4		157		1		—		158
Earnings from equity method investments	—		32		—		32		—		—		32
Interest expense	76		9		2		87		(4)		—		83
Income taxes	21		6		3		30		6		—		36
Segment net income (loss)	$	80	$	22	$	9	$	111	$	(3)	$	—	$	108

Six Months Ended June 30, 2024
Operating revenues	$	2,212	$	16	$	305	$	2,533	$	13	$	(8)	$	2,538
Other segment items(*)	1,246		4		193		1,443		8		(8)		1,443
Depreciation and amortization	303		2		7		312		1		—		313
Earnings from equity method investments	—		76		—		76		—		—		76
Interest expense	154		18		2		174		(7)		—		167
Income taxes (benefit)	127		16		29		172		2		—		174
Segment net income	$	382	$	52	$	74	$	508	$	9	$	—	$	517

Total assets at December 31, 2024	$	24,067	$	1,573	$	1,696	$	27,336	$	10,047	$	(11,206)	$	26,177

(*)Primarily consists of cost of natural gas, other operations and maintenance, taxes other than income taxes, AFUDC equity, and non-service cost-related retirement benefits income.

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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			94
Results of Operations			96
Southern Company			96
Alabama Power			104
Georgia Power			108
Mississippi Power			114
Southern Power			118
Southern Company Gas			122
Future Earnings Potential			127
Accounting Policies			133
Financial Condition and Liquidity			133

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.

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 sale of natural gas and 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 Heating Degree Days, 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

On June 6, 2025, the FERC approved Alabama Power's acquisition of Tenaska Alabama Partners, L.P., which owns and operates the Lindsay Hill Generating Station. The ultimate outcome of this matter cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Alabama Power – Petition for Certificate of Convenience and Necessity" herein for additional information.

Georgia Power

2022 ARP

On July 1, 2025, the Georgia PSC approved a settlement agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors to extend the 2022 ARP for an additional three-year term through December 31, 2028 (ARP Extension). Under the ARP Extension, base rates will not be adjusted in 2026, 2027, or 2028 except for reasonable and prudent storm damage costs incurred through December 31, 2025, which will be determined in a separate regulatory proceeding.

Table of Contents Index to Financial Statements

MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

See Note (B) to the Condensed Financial Statements under "Georgia Power – 2022 ARP" herein for additional information.

Integrated Resource Plans

On July 30, 2025, Georgia Power requested certification from the Georgia PSC, for which a final decision is expected to be rendered in December 2025, for the following resources:

•In July 2025, Georgia Power extended 50 MWs of an existing 750-MW affiliate PPA with Mississippi Power for an additional year through December 31, 2029.

•Additionally, in July 2025, Georgia Power executed a 20-year non-affiliate PPA for 930 MWs commencing in 2030 and five 25-year non-affiliate PPAs totaling 646 MWs commencing in 2027.

The ultimate outcome of these matters cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Georgia Power – Integrated Resource Plans" and FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" herein for additional information.

2025 IRP

•Upgrades to Plant Vogtle Units 1 and 2 (1,060 MWs based on 45.7% ownership) for a projected 54 MWs of incremental capacity, some of which could be available as early as 2028.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

•RFP for at least 1,100 MWs of utility scale and distributed generation renewable resources.

See Note (B) to the Condensed Financial Statements under "Georgia Power – Integrated Resource Plans" herein for additional information.

Mississippi Power

On April 3, 2025, the FERC approved a settlement agreement filed by Mississippi Power and Cooperative Energy in December 2024, as part of the MRA tariff.

On June 17, 2025, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2025, resulting in an annual increase in revenues of approximately 4.0%, or $41 million. In accordance with the PEP rate schedule, an increase of 2.0% of total retail revenues, or approximately $22 million, became effective with the first billing cycle of April 2025, and the remaining approximately $19 million became effective with the first billing cycle of July 2025.

See Note (B) to the Condensed Financial Statements under "Mississippi Power" herein for additional information.

Southern Power

During the six months ended June 30, 2025, Southern Power continued the development project to repower 200 MWs of the 299-MW Kay Wind facility. In addition, Southern Power committed to development projects to repower the full capacity of the 147-MW Grant Plains, the 152-MW Grant Wind, and the 257-MW Wake Wind facilities. The output of the development projects is contracted under new and amended PPAs, with commercial operations projected to occur between the third quarter 2026 and the second quarter 2027. The ultimate outcome of these matters cannot be determined at this time. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

At June 30, 2025, 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 96% through 2029 and 87% through 2034, with an average remaining contract duration of approximately 12 years.

RESULTS OF OPERATIONS

Southern Company

Net Income


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(323)	(26.8)	$(118)	(5.1)

Consolidated net income attributable to Southern Company was $880 million ($0.80 per share) in the second quarter 2025 compared to $1.2 billion ($1.10 per share) for the corresponding period in 2024. For year-to-date 2025, consolidated net income attributable to Southern Company was $2.2 billion ($2.01 per share) compared to $2.3

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

billion ($2.13 per share) for the corresponding period in 2024. The decreases were primarily due to increases in non-fuel operations and maintenance expenses, depreciation and amortization, interest expense, and income taxes, partially offset by increases in retail electric revenues associated with rates and pricing and sales growth, natural gas revenues associated with base rate increases, other revenues, and allowance for equity funds used during construction. Also contributing to the second quarter 2025 decrease were weather impacts, which partially offset the increase in retail electric revenues.

Retail Electric Revenues

In the second quarter 2025, retail electric revenues were $4.8 billion compared to $4.5 billion for the corresponding period in 2024. For year-to-date 2025, retail electric revenues were $9.4 billion compared to $8.4 billion for the corresponding period in 2024. Details of the changes in retail electric revenues were as follows:


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Rates and pricing	$	199	4.4	%	$	558	6.6	%
Sales growth	93		2.1		69		0.8
Weather	(100)		(2.2)		17		0.2
Fuel and other cost recovery	80		1.8		287		3.4
Retail electric revenues	$	272	6.1	%	$	931	11.0	%

Changes in rates and pricing resulted in an increase in revenues in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024 primarily due to the inclusion of Plant Vogtle Unit 4 in retail rates net of elimination of the NCCR tariff at Georgia Power, an increase in Rate RSE at Alabama Power, base tariff increases and increased ECCR tariff revenues at Georgia Power in accordance with the 2022 ARP, and higher contributions from commercial and industrial customers with variable demand-driven pricing at Georgia Power. See Note 2 to the financial statements under "Alabama Power" and "Georgia Power" in Item 8 of the Form 10-K for additional information.

Changes in sales resulted in an increase in revenues in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024. Weather-adjusted residential KWH sales increased 2.8% in the second quarter 2025 primarily due to increased customer usage and customer growth. Weather-adjusted residential KWH sales increased 0.3% for year-to-date 2025 primarily due to customer growth, largely offset by decreased customer usage. Weather-adjusted commercial KWH sales increased 3.5% and 2.0% in the second quarter and year-to-date 2025, respectively, primarily due to increased customer usage, primarily driven by data centers. Industrial KWH sales increased 2.8% and 1.7% in the second quarter and year-to-date 2025, respectively, primarily due to increases in the paper, primary metals, and transportation sectors, partially offset by a decrease in the pipeline sector.

Fuel and other cost recovery revenues increased $80 million and $287 million in the second quarter and year-to-date 2025, respectively, compared to the corresponding periods in 2024 primarily due to higher 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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Wholesale Electric Revenues


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$54	8.6	$227	18.9

In the second quarter 2025, wholesale electric revenues were $681 million compared to $627 million for the corresponding period in 2024. For year-to-date 2025, wholesale electric revenues were $1.4 billion compared to $1.2 billion for the corresponding period in 2024. The increases in the second quarter and year-to-date 2025 were due to increases in energy revenues of $60 million and $239 million, respectively, partially offset by decreases in capacity revenues of $6 million and $12 million, respectively. The increases in energy revenues were primarily due to fuel and purchased power price increases. The decreases in capacity revenues were primarily due to net decreases in MW capacity under contract from natural gas PPAs at Southern Power, partially offset by higher non-fuel revenues from wholesale capacity contracts at Georgia Power.

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 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$10	4.8	$54	13.2

For year-to-date 2025, other electric revenues were $463 million compared to $409 million for the corresponding period in 2024. The increase was primarily due to increases of $14 million in regulated sales associated with power delivery construction and maintenance projects at Georgia Power, $14 million in regulated outdoor lighting sales at Georgia Power, $11 million in open access transmission tariff sales at Alabama Power, $11 million in regulated energy services revenues at Alabama Power, $7 million related to undistributed customer bill credits at Alabama Power, which was offset by an additional NDR accrual within other operations and maintenance expenses, and $6 million in receipts associated with liquidated damages at Southern Power, partially offset by a $15 million decrease associated with transmission revenues at Southern Power. See Note 3 to the financial statements under "Nuclear Fuel Disposal Costs" in Item 8 of the Form 10-K for additional information regarding customer bill credits at Alabama Power.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Natural Gas Revenues

In the second quarter 2025, natural gas revenues were $979 million compared to $831 million for the corresponding period in 2024. For year-to-date 2025, natural gas revenues were $2.8 billion compared to $2.5 billion for the corresponding period in 2024. Details of the changes in natural gas revenues were as follows:


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Rates	$	28	3.4	%	$	71	2.8	%
Gas costs and other cost recovery	104		12.5		166		6.5
Gas marketing services	17		2.0		35		1.4
Other	(1)		(0.1)		8		0.3
Natural gas revenues	$	148	17.8	%	$	280	11.0	%

Changes in rates resulted in an increase in revenues in the second quarter and year-to-date 2025 compared to the corresponding periods in 2024 primarily due to base rate increases at Atlanta Gas Light and Virginia Natural Gas. 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 from gas costs and other cost recovery increased in the second quarter and year-to-date 2025 compared to the corresponding periods in 2024 primarily due to higher natural gas prices and gas volumes. 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 the natural gas distribution utilities.

Revenues from gas marketing services increased in the second quarter and year-to-date 2025 compared to the corresponding periods in 2024 primarily due to higher commodity prices.

Other Revenues


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$26	8.4	$147	27.4

In the second quarter 2025, other revenues were $335 million compared to $309 million for the corresponding period in 2024. For year-to-date 2025, other revenues were $684 million compared to $537 million for the corresponding period in 2024. The increases in the second quarter and year-to-date 2025 were primarily due to increases of $20 million and $81 million, respectively, at PowerSecure primarily related to distributed infrastructure projects and $13 million and $71 million, respectively, in unregulated sales at Georgia Power primarily associated with power delivery construction and maintenance, energy conservation, and renewables projects. Partially offsetting the second quarter 2025 increase was a $6 million decrease at Southern Linc related to equipment sales associated with commercial customers.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Fuel and Purchased Power Expenses


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Fuel	$	84	8.1	%	$	380	18.7	%
Purchased power	38		17.1		90		21.4
Total fuel and purchased power expenses	$	122			$	470

In the second quarter 2025, total fuel and purchased power expenses were $1.4 billion compared to $1.3 billion for the corresponding period in 2024. The increase was due to a $106 million net increase related to the average cost of fuel and purchased power and a $16 million net increase related to the volume of KWHs generated and purchased.

For year-to-date 2025, total fuel and purchased power expenses were $2.9 billion compared to $2.4 billion for the corresponding period in 2024. The increase was due to a $336 million net increase related to the average cost of fuel and purchased power and a $134 million net increase related to the volume of KWHs generated and purchased.

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 2025	Second Quarter 2024	Year-to-Date 2025	Year-to-Date 2024
Total generation (in billions of KWHs)(a)	45	47	91	92
Total purchased power (in billions of KWHs)	6	4	11	8
Sources of generation (percent) —
Gas	50	50	50	50
Nuclear(a)	18	20	19	20
Coal	19	19	19	18
Hydro	4	2	4	3
Wind, Solar, and Other	9	9	8	9
Cost of fuel, generated (in cents per net KWH)—
Gas	3.23	2.56	3.56	2.72
Nuclear(a)	0.88	0.89	0.86	0.85
Coal	3.77	3.95	3.90	3.88
Average cost of fuel, generated (in cents per net KWH)(a)	2.86	2.49	3.04	2.54
Average cost of purchased power (in cents per net KWH)(b)	4.73	5.14	5.07	5.40

(a)Excludes KWHs generated from test period energy at Plant Vogtle Unit 4 prior to its in-service date. The related fuel costs were charged to CWIP in accordance with FERC guidance. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information on Plant Vogtle Units 3 and 4.

(b)Average cost of purchased power includes fuel purchased by the Southern Company system for tolling agreements where power is generated by the provider.

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AND RESULTS OF OPERATIONS (Continued)

Cost of Natural Gas


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$106	71.1	$175	23.2

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 85% and 82% of the total cost of natural gas in the second quarter and year-to-date 2025, respectively.

In the second quarter 2025, cost of natural gas was $255 million compared to $149 million for the corresponding period in 2024. For year-to-date 2025, cost of natural gas was $929 million compared to $754 million for the corresponding period in 2024. The increases reflect higher gas cost recovery as a result of increases of 82% and 72% in natural gas prices in the second quarter and year-to-date 2025, respectively.

Cost of Other Sales


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$—	—	$68	22.8

For year-to-date 2025, cost of other sales was $366 million compared to $298 million for the corresponding period in 2024. The increase was primarily due to increases of $43 million at PowerSecure primarily related to distributed infrastructure projects and $36 million at Georgia Power primarily associated with unregulated power delivery construction and maintenance projects, partially offset by an $11 million decrease at Southern Company Gas related to energy services contracts.

Other Operations and Maintenance Expenses


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$297	21.4	$445	15.6

In the second quarter 2025, other operations and maintenance expenses were $1.7 billion compared to $1.4 billion for the corresponding period in 2024. The increase was primarily due to a $114 million gain from the sale of integrated transmission system assets at Georgia Power recorded in the second quarter 2024, an increase of $61 million in generation expenses primarily resulting from planned outages, an increase of $22 million in technology infrastructure and application production costs, a $21 million credit at Georgia Power related to the estimated loss on Plant Vogtle Units 3 and 4 recorded in the second quarter 2024, an increase of $17 million in transmission and distribution expenses at the traditional electric operating companies primarily due to line maintenance costs, an increase of $15 million in employee compensation and benefit expenses at Southern Company Gas, and a $12 million increase in certain employee compensation and benefit expenses at the traditional electric operating companies.

For year-to-date 2025, other operations and maintenance expenses were $3.3 billion compared to $2.9 billion for the corresponding period in 2024. The increase was primarily due to an increase of $134 million in generation expenses primarily resulting from planned outages, primarily at Alabama Power, and non-outage maintenance expenses, primarily at Georgia Power and Southern Power, a $114 million gain from the sale of integrated transmission system assets at Georgia Power recorded in the second quarter 2024, an increase of $34 million in certain employee compensation and benefit expenses at the traditional electric operating companies, an increase of $32 million in

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AND RESULTS OF OPERATIONS (Continued)

technology infrastructure and application production costs, an increase of $32 million in employee compensation and benefit expenses at Southern Company Gas, an increase of $21 million in transmission and distribution expenses at the traditional electric operating companies primarily due to line maintenance costs, and a $21 million credit related to the estimated loss on Plant Vogtle Units 3 and 4 recorded in the second quarter 2024 at Georgia Power.

See Note 2 to the financial statements under "Georgia Power" in Item 8 of the Form 10-K for additional information.

Depreciation and Amortization


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$141	11.9	$281	12.1

In the second quarter 2025, depreciation and amortization was $1.3 billion compared to $1.2 billion for the corresponding period in 2024. For year-to-date 2025, depreciation and amortization was $2.6 billion compared to $2.3 billion for the corresponding period in 2024. The increases in the second quarter and year-to-date 2025 were primarily due to increases of $64 million and $141 million, respectively, associated with additional plant in service, $42 million and $69 million, respectively, in accelerated depreciation related to wind repowering projects at Southern Power, and $31 million and $62 million, respectively, in amortization of regulatory assets related to CCR AROs at Georgia Power as approved in the 2025 compliance filing under the terms of the 2022 ARP. See Note (K) to the Condensed Financial Statements under "Southern Power – Wind Repowering Projects" herein and Notes 2 and 15 to the financial statements under "Georgia Power" and "Southern Power – Development Projects," respectively, in Item 8 of the Form 10-K for additional information.

Taxes Other Than Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$19	4.9	$68	8.7

In the second quarter 2025, taxes other than income taxes were $403 million compared to $384 million for the corresponding period in 2024. For year-to-date 2025, taxes other than income taxes were $848 million compared to $780 million for the corresponding period in 2024. The increases in the second quarter and year-to-date 2025 were primarily due to increases of $4 million and $22 million, respectively, in property taxes primarily resulting from an increase in the assessed value of property, $3 million and $14 million, respectively, in municipal franchise fees resulting from higher retail revenues at Georgia Power, $4 million and $14 million, respectively, in revenue taxes resulting from higher natural gas revenues at Nicor Gas, and $4 million and $9 million, respectively, in utility license taxes resulting from an increase in the tax base at Alabama Power. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information on Plant Vogtle Unit 4.

Allowance for Equity Funds Used During Construction


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$29	56.9	$44	40.4

In the second quarter 2025, allowance for equity funds used during construction was $80 million compared to $51 million for the corresponding period in 2024. For year-to-date 2025, allowance for equity funds used during construction was $153 million compared to $109 million for the corresponding period in 2024. The increases were primarily associated with increases in capital expenditures subject to AFUDC at Georgia Power and Alabama

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AND RESULTS OF OPERATIONS (Continued)

Power. Partially offsetting the year-to-date 2025 increase was the impact of Plant Vogtle Unit 4 being placed in service in April 2024 at Georgia Power. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information on Plant Vogtle Unit 4.

Earnings from Equity Method Investments


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(21)	(67.7)	$(34)	(44.2)

In the second quarter 2025, earnings from equity method investments were $10 million compared to $31 million for the corresponding period in 2024. For year-to-date 2025, earnings from equity method investments were $43 million compared to $77 million for the corresponding period in 2024. The decreases in the second quarter and year-to-date 2025 were primarily due to decreases of $13 million and $21 million, respectively, at Southern Holdings related to investment losses and decreases of $9 million and $14 million, respectively, at Southern Company Gas related to lower rates at SNG. See Note 7 to the financial statements in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements herein under "Southern Company" and "Southern Company Gas" for additional information.

Interest Expense, Net of Amounts Capitalized


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$180	25.9	$230	16.9

In the second quarter 2025, interest expense, net of amounts capitalized was $874 million compared to $694 million for the corresponding period in 2024. For year-to-date 2025, interest expense, net of amounts capitalized was $1.6 billion compared to $1.4 billion for the corresponding period in 2024. The increases in the second quarter and year-to-date 2025 were primarily due to a $129 million loss associated with the extinguishment of debt at the parent company, as well as increases of approximately $54 million and $101 million, respectively, related to higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein and Note (F) to the Condensed Financial Statements under "Convertible Senior Notes" herein for additional information.

Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(1)	(0.3)	$56	10.9

In the second quarter 2025, income taxes were $289 million compared to $290 million for the corresponding period in 2024. The decrease was primarily due to lower pre-tax earnings and a $19 million increase in the flowback of excess state deferred income taxes at Georgia Power, largely offset by a $64 million increase in charges to a valuation allowance on certain state tax credit carryforwards and $33 million from the recognition of certain state tax positions from amended returns in the second quarter 2024, both at Georgia Power, and a $9 million decrease in the flowback of certain excess deferred income taxes at Alabama Power.

For year-to-date 2025, income taxes were $569 million compared to $513 million for the corresponding period in 2024. The increase was primarily due to a $71 million increase in charges to a valuation allowance on certain state tax credit carryforwards and $33 million from the recognition of certain state tax positions from amended returns in the second quarter 2024, both at Georgia Power, and a $19 million decrease in the flowback of certain excess deferred income taxes at Alabama Power, partially offset by increases of $34 million in the flowback of excess state

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deferred income taxes and $21 million in the generation of advanced nuclear PTCs, both at Georgia Power, as well as lower pre-tax earnings.

See Note (G) to the Condensed Financial Statements herein for additional information.

Net Loss Attributable to Noncontrolling Interests


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(12)	(80.0)	$(18)	(24.7)

Substantially all noncontrolling interests relate to renewable projects at Southern Power. In the second quarter 2025, net loss attributable to noncontrolling interests was $27 million compared to $15 million for the corresponding period in 2024. The increase was primarily due to $9 million in lower income allocations to Southern Power's equity partners and $4 million in higher HLBV loss allocations to Southern Power's tax equity partners.

For year-to-date 2025, net loss attributable to noncontrolling interests was $91 million compared to $73 million for the corresponding period in 2024. The increase was primarily due to $12 million in higher HLBV loss allocations to Southern Power's tax equity partners and $7 million in lower income allocations to Southern Power's equity partners.

Alabama Power

Net Income


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$12	3.3	$53	7.5

Alabama Power's net income in the second quarter 2025 was $381 million compared to $369 million for the corresponding period in 2024. The increase was primarily due to higher retail electric revenues resulting from changes in rates and pricing and increased customer usage, partially offset by weather impacts and an increase in non-fuel operations and maintenance expenses.

For year-to-date 2025, net income was $755 million compared to $702 million for the corresponding period in 2024. The increase was primarily due to higher retail electric revenues resulting from changes in rates and pricing, as well as an increase in other revenues, partially offset by increases in non-fuel operations and maintenance expenses and depreciation and amortization.

Retail Revenues

In the second quarter 2025, retail revenues were $1.7 billion compared to $1.6 billion for the corresponding period in 2024. For year-to-date 2025, retail revenues were $3.4 billion compared to $3.2 billion for the corresponding period in 2024. Details of the changes in retail revenues were as follows:


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Rates and pricing	$	68	4.1	%	$	159	4.9	%
Sales growth	23		1.4		—		—
Weather	(40)		(2.5)		5		0.2
Fuel and other cost recovery	20		1.2		64		2.0
Retail revenues	$	71	4.2	%	$	228	7.1	%

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AND RESULTS OF OPERATIONS (Continued)

Changes in rates and pricing resulted in increases in revenues in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024 primarily due to an increase in Rate RSE. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

Changes in sales resulted in an increase in revenues in the second quarter and no change in revenues for year-to-date 2025 when compared to the corresponding periods in 2024. Weather-adjusted residential KWH sales increased 3.9% in the second quarter 2025 primarily due to increased customer usage. Weather-adjusted residential KWH sales increased 0.2% for year-to-date 2025 primarily due to customer growth. Weather-adjusted commercial KWH sales increased 2.0% in the second quarter 2025 primarily due to increased customer usage. Weather-adjusted commercial KWH sales increased 0.3% for year-to-date 2025 primarily due to customer growth. Industrial KWH sales increased 2.2% and 1.1% in the second quarter and year-to-date 2025, respectively, primarily due to increases in the primary metals sector.

Fuel and other cost recovery revenues increased in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024 primarily as a result of higher recoverable fuel costs.

Electric rates include provisions to recognize the recovery of fuel costs, purchased power costs, PPAs certificated by the Alabama 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 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$14	16.7	$20	11.8

In the second quarter 2025, wholesale revenues from sales to non-affiliates were $98 million compared to $84 million for the corresponding period in 2024. For year-to-date 2025, wholesale revenues from sales to non-affiliates were $189 million compared to $169 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were primarily due to increases of 27.4% and 20.1%, respectively, in the price of energy due to an increase in natural gas prices.

Wholesale Revenues – Affiliates


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$9	33.3	$37	54.4

In the second quarter 2025, wholesale revenues from sales to affiliates were $36 million compared to $27 million for the corresponding period in 2024. For year-to-date 2025, wholesale revenues from sales to affiliates were $105 million compared to $68 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were primarily due to increases of 31.8% and 59.7%, respectively, 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.

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Other Revenues


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$1	0.9	$31	14.5

For year-to-date 2025, other revenues were $245 million compared to $214 million for the corresponding period in 2024. The increase was primarily due to an $11 million increase in transmission revenue primarily associated with open access transmission tariff sales, an $11 million increase in regulated energy services revenues, $7 million related to undistributed customer bill credits associated with nuclear fuel disposal costs litigation, which was offset by an additional NDR accrual within other operations and maintenance expenses, and a $4 million increase in cogeneration revenues primarily related to higher fuel prices. These increases were partially offset by a $10 million decrease in pole attachment rental revenues. See Note 3 to the financial statements under "Nuclear Fuel Disposal Costs" in Item 8 of the Form 10-K for additional information.

Fuel and Purchased Power Expenses


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Fuel	$	2	0.6	%	$	57	8.6	%
Purchased power – non-affiliates	7		14.9		25		25.3
Purchased power – affiliates	23		52.3		34		39.1
Total fuel and purchased power expenses	$	32			$	116

In the second quarter 2025, total fuel and purchased power expenses were $458 million compared to $426 million for the corresponding period in 2024. The increase was primarily due to a $19 million net increase related to the average cost of fuel and purchased power and a $13 million net increase related to the volume of KWHs generated and purchased.

For year-to-date 2025, total fuel and purchased power expenses were $968 million compared to $852 million for the corresponding period in 2024. The increase was due to a $63 million net increase related to the volume of KWHs generated and purchased and a $53 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 energy 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 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, as approved by the FERC.

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AND RESULTS OF OPERATIONS (Continued)

Details of Alabama Power's generation and purchased power and the related costs were as follows:


	Second Quarter 2025	Second Quarter 2024	Year-to-Date 2025	Year-to-Date 2024
Total generation (in billions of KWHs)	14	15	29	30
Total purchased power (in billions of KWHs)	2	2	4	3
Sources of generation (percent) —
Gas	37	37	35	35
Coal	36	37	35	33
Nuclear	16	21	20	24
Hydro	11	5	10	8
Cost of fuel, generated (in cents per net KWH) —
Gas	3.13	2.62	3.35	2.78
Coal	3.10	3.09	3.27	3.17
Nuclear	0.78	0.72	0.73	0.71
Average cost of fuel, generated (in cents per net KWH)	2.69	2.38	2.73	2.39
Average cost of purchased power (in cents per net KWH)(*)	5.35	5.68	6.26	6.60

(*)Average cost of purchased power includes fuel, energy, and transmission purchased by Alabama Power for tolling agreements where power is generated by the provider.

Other Operations and Maintenance Expenses


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$43	10.0	$95	11.3

In the second quarter 2025, other operations and maintenance expenses were $472 million compared to $429 million for the corresponding period in 2024. The increase was primarily due to increases of $14 million in generation expenses primarily associated with planned and unplanned outages, $7 million associated with an additional NDR accrual, which is offset within other revenues, $4 million in vegetation management expenses, $4 million in certain employee compensation and benefit expenses, and $3 million in technology infrastructure and application production costs. See Note 3 to the financial statements under "Nuclear Fuel Disposal Costs" in Item 8 of the Form 10-K for additional information.

For year-to-date 2025, other operations and maintenance expenses were $935 million compared to $840 million for the corresponding period in 2024. The increase was primarily due to increases of $52 million in generation expenses primarily associated with planned outages, $12 million in certain employee compensation and benefit expenses, and $8 million in technology infrastructure and application production costs.

Depreciation and Amortization


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$7	1.9	$16	2.2

For year-to-date 2025, depreciation and amortization was $741 million compared to $725 million for the corresponding period in 2024. The increase was primarily due to additional plant in service related to transmission and distribution systems.

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Taxes Other Than Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$2	1.7	$12	5.0

For year-to-date 2025, taxes other than income taxes were $250 million compared to $238 million for the corresponding period in 2024. The increase was primarily due to an increase in utility license taxes resulting from an increase in the tax base.

Allowance for Equity Funds Used During Construction


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$6	50.0	$10	38.5

In the second quarter 2025, allowance for equity funds used during construction was $18 million compared to $12 million for the corresponding period in 2024. For year-to-date 2025, allowance for equity funds used during construction was $36 million compared to $26 million for the corresponding period in 2024. The increases were primarily due to increases in capital expenditures subject to AFUDC.

Other Income (Expense), Net


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$10	27.0	$6	7.7

In the second quarter 2025, other income (expense), net was $47 million compared to $37 million for the corresponding period in 2024. The increase was primarily due to the receipt of liquidated damages associated with the termination of two solar projects.

Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$13	12.7	$39	20.9

In the second quarter 2025, income taxes were $115 million compared to $102 million for the corresponding period in 2024. For year-to-date 2025, income taxes were $226 million compared to $187 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were primarily due to higher pre-tax earnings and decreases of $9 million and $19 million, respectively, in the flowback of certain excess deferred income taxes. See Note (G) to the Condensed Financial Statements herein for additional information.

Georgia Power

Net Income


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(155)	(20.3)	$5	0.4

Georgia Power's net income in the second quarter 2025 was $607 million compared to $762 million for the corresponding period in 2024. The decrease was primarily due to higher non-fuel operations and maintenance expenses and depreciation and amortization, weather impacts on retail revenues, and higher income taxes, partially

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offset by higher retail revenues associated with increased base tariff and ECCR tariff revenues in accordance with the 2022 ARP, the inclusion of Plant Vogtle Unit 4 in retail rates, and higher contributions from customers with demand-driven pricing. Also partially offsetting this decrease were higher wholesale revenues and other revenues.

For year-to-date 2025, net income was essentially flat compared to the corresponding period in 2024. Higher retail revenues associated with the inclusion of Plant Vogtle Unit 4 in retail rates, increased base tariff and ECCR tariff revenues in accordance with the 2022 ARP, and higher contributions from customers with demand-driven pricing, as well as higher wholesale revenues and other revenues, were largely offset by higher non-fuel operations and maintenance expenses, depreciation and amortization, and income taxes.

Retail Revenues

In the second quarter 2025, retail revenues were $2.8 billion compared to $2.6 billion for the corresponding period in 2024. For year-to-date 2025, retail revenues were $5.4 billion compared to $4.8 billion for the corresponding period in 2024. Details of the changes in retail revenues were as follows:


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Rates and pricing	$	123	4.7	%	$	390	8.2	%
Sales growth	65		2.5		64		1.4
Weather	(57)		(2.2)		10		0.2
Fuel cost recovery	37		1.4		179		3.8
Retail revenues	$	168	6.4	%	$	643	13.6	%

Changes in rates and pricing resulted in an increase in revenues in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024 primarily due to the inclusion of Plant Vogtle Unit 4 in retail rates net of elimination of the NCCR tariff, base tariff increases and increased ECCR tariff revenues in accordance with the 2022 ARP, and higher contributions from commercial and industrial customers with variable demand-driven pricing. See Note 2 to the financial statements under "Georgia Power" in Item 8 of the Form 10-K for additional information.

Changes in sales resulted in an increase in revenues in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024. Weather-adjusted residential KWH sales increased 2.1% in the second quarter 2025 primarily due to customer growth and increased customer usage. Weather-adjusted residential KWH sales increased 0.4% for year-to-date 2025 primarily due to customer growth, partially offset by decreased customer usage. Weather-adjusted commercial KWH sales increased 4.4% and 2.9% in the second quarter and year-to-date 2025, respectively, primarily due to increased customer usage, primarily driven by data centers. Weather-adjusted industrial KWH sales increased 3.5% in the second quarter 2025 primarily due to increases in the transportation and paper sectors, partially offset by a decrease in the pipeline sector. Weather-adjusted industrial KWH sales increased 1.8% for year-to-date 2025 primarily due to increases in the transportation and paper sectors, partially offset by decreases in the pipeline and textiles sectors.

Fuel revenues and costs are allocated between retail and wholesale jurisdictions. Retail fuel cost recovery revenues increased in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024 due to higher 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 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.

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Wholesale Revenues


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$44	69.8	$130	108.3

In the second quarter 2025, wholesale revenues were $107 million compared to $63 million for the corresponding period in 2024. For year-to-date 2025, wholesale revenues were $250 million compared to $120 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were due to increases of $21 million and $63 million, respectively, related to the volume of KWH sales associated with higher market demand, $11 million and $35 million, respectively, related to the average cost per KWH sold due to higher Southern Company system fuel and purchased power prices, and $12 million and $32 million, respectively, related to additional non-fuel revenues from wholesale capacity contracts.

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.

Other Revenues


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$23	10.7	$102	25.4

In the second quarter 2025, other revenues were $238 million compared to $215 million for the corresponding period in 2024. The increase was primarily due to increases of $15 million in unregulated sales primarily associated with power delivery construction and maintenance projects and $5 million in outdoor lighting sales.

For year-to-date 2025, other revenues were $503 million compared to $401 million for the corresponding period in 2024. The increase was primarily due to increases of $77 million in unregulated sales primarily associated with power delivery construction and maintenance, energy conservation, and renewables projects, $14 million in regulated sales associated with power delivery construction and maintenance projects, and $9 million in outdoor lighting sales.

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Fuel and Purchased Power Expenses


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Fuel	$	35	7.9	%	$	170	20.5	%
Purchased power – non-affiliates	29		19.2		49		16.8
Purchased power – affiliates	15		8.2		98		27.0
Total fuel and purchased power expenses	$	79			$	317

In the second quarter 2025, total fuel and purchased power expenses were $853 million compared to $774 million for the corresponding period in 2024. For year-to-date 2025, total fuel and purchased power expenses were $1.8 billion compared to $1.5 billion for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were due to net increases of $69 million and $182 million, respectively, related to the volume of KWHs generated and purchased and increases of $10 million and $135 million, respectively, 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 affiliates will vary depending on the demand 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. See Note 2 to the financial statements under "Georgia Power – Integrated Resource Plans" in Item 8 of the Form 10-K for information regarding two new PPAs with Southern Power.

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Details of Georgia Power's generation and purchased power and the related costs were as follows:


	Second Quarter 2025	Second Quarter 2024	Year-to-Date 2025	Year-to-Date 2024
Total generation (in billions of KWHs)(a)	16	17	31	32
Total purchased power (in billions of KWHs)	9	7	18	14
Sources of generation (percent) —
Gas	38	41	39	44

Nuclear(a)	37	36	37	34
Coal	21	20	21	19
Hydro and other	4	3	3	3
Cost of fuel, generated (in cents per net KWH) —
Gas	3.39	2.85	3.75	3.00

Nuclear(a)	0.92	0.98	0.92	0.95
Coal	4.59	5.19	4.66	4.81
Average cost of fuel, generated (in cents per net KWH)(a)	2.68	2.63	2.87	2.63
Average cost of purchased power (in cents per net KWH)(b)	4.97	4.97	5.11	4.80

(b)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 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$207	47.3	$330	34.6

In the second quarter 2025, other operations and maintenance expenses were $645 million compared to $438 million for the corresponding period in 2024. The increase was primarily due to a $114 million gain from the sale of integrated transmission system assets in the second quarter 2024, an increase of $24 million in generation expenses primarily due to planned outages, a $21 million credit related to the estimated loss on Plant Vogtle Units 3 and 4 recorded in the second quarter 2024, and increases of $19 million in certain technology infrastructure and application production costs, $11 million in transmission and distribution expenses primarily due to line maintenance costs, and $8 million in certain employee compensation and benefit expenses.

For year-to-date 2025, other operations and maintenance expenses were $1.3 billion compared to $1.0 billion for the corresponding period in 2024. The increase was primarily due to a $114 million gain from the sale of integrated transmission system assets in the second quarter 2024, increases of $56 million in generation expenses primarily due to non-outage maintenance expenses largely resulting from Plant Vogtle Unit 4 being placed in service in April 2024, $50 million in expenses associated with unregulated power delivery construction and maintenance, energy conservation, and renewables projects, and $23 million in certain technology infrastructure and application production costs, a $21 million credit related to the estimated loss on Plant Vogtle Units 3 and 4 recorded in the second quarter 2024, and increases of $21 million in certain employee compensation and benefit expenses and $20 million in transmission and distribution expenses primarily due to line maintenance costs.

See Note 2 to the financial statements under "Georgia Power" in Item 8 of the Form 10-K for additional information.

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Depreciation and Amortization


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$65	14.5	$143	16.4

In the second quarter 2025, depreciation and amortization was $512 million compared to $447 million for the corresponding period in 2024. For year-to-date 2025, depreciation and amortization was $1.0 billion compared to $0.9 billion for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were primarily due to increases of $37 million and $87 million, respectively, associated with additional plant in service and $31 million and $62 million, respectively, in amortization of regulatory assets related to CCR AROs as approved in the 2025 compliance filing under the terms of the 2022 ARP. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Taxes Other Than Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$9	5.5	$31	10.0

In the second quarter 2025, taxes other than income taxes were $173 million compared to $164 million for the corresponding period in 2024. The increase was primarily due to increases of $4 million in property taxes primarily resulting from an increase in the assessed value of property and $3 million in municipal franchise fees resulting from higher retail revenues.

For year-to-date 2025, taxes other than income taxes were $342 million compared to $311 million for the corresponding period in 2024. The increase was primarily due to an increase of $14 million in municipal franchise fees resulting from higher retail revenues, an increase of $10 million in property taxes primarily resulting from an increase in the assessed value of property, and a decrease of $6 million in property taxes capitalized primarily due to Plant Vogtle Unit 4 being placed in service in April 2024. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information on Plant Vogtle Unit 4.

Allowance for Equity Funds Used During Construction


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$23	69.7	$32	44.4

In the second quarter 2025, allowance for equity funds used during construction was $56 million compared to $33 million for the corresponding period in 2024. For year-to-date 2025, allowance for equity funds used during construction was $104 million compared to $72 million for the corresponding period in 2024. The increases were primarily due to an increase in capital expenditures subject to AFUDC. Partially offsetting the increase for year-to-date 2025 was the impact of Plant Vogtle Unit 4 being placed in service in April 2024. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information on Plant Vogtle Unit 4.

Interest Expense, Net of Amounts Capitalized


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$13	7.0	$26	7.2

In the second quarter 2025, interest expense, net of amounts capitalized was $198 million compared to $185 million for the corresponding period in 2024. For year-to-date 2025, interest expense, net of amounts capitalized was $385

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million compared to $359 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were primarily associated with increases of approximately $13 million and $23 million, respectively, related to higher average outstanding borrowings and decreases of $3 million and $12 million, respectively, in net deferred financing costs related to Plant Vogtle Unit 3, partially offset by decreases of approximately $2 million and $4 million, respectively, related to lower interest rates.

See Note 2 to the financial statements under "Georgia Power – Nuclear Construction – Regulatory Matters" in Item 8 of the Form 10-K and FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information.

Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$44	22.9	$63	23.2

In the second quarter 2025, income taxes were $236 million compared to $192 million for the corresponding period in 2024. The increase was primarily due to a $64 million increase in charges to a valuation allowance on certain state tax credit carryforwards and $33 million from the recognition of certain state tax positions from amended returns in the second quarter 2024, partially offset by lower pre-tax earnings and an increase of $19 million in the flowback of excess state deferred income taxes.

For year-to-date 2025, income taxes were $334 million compared to $271 million for the corresponding period in 2024. The increase was primarily due to a $71 million increase in charges to a valuation allowance on certain state tax credit carryforwards, $33 million from the recognition of certain state tax positions from amended returns in the second quarter 2024, and higher pre-tax earnings, partially offset by increases of $34 million in the flowback of excess state deferred income taxes and $21 million in the generation of advanced nuclear PTCs.

See Note (G) to the Condensed Financial Statements herein for additional information.

Mississippi Power

Net Income


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(2)	(3.3)	$3	2.7

Mississippi Power's net income for year-to-date 2025 was $114 million compared to $111 million for the corresponding period in 2024. The increase was primarily due to higher retail revenues primarily resulting from changes in rates and pricing, largely offset by an increase in depreciation and amortization.

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Retail Revenues

In the second quarter 2025, retail revenues were $274 million compared to $242 million for the corresponding period in 2024. For year-to-date 2025, retail revenues were $522 million compared to $462 million for the corresponding period in 2024. Details of the changes in retail revenues were as follows:


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Rates and pricing	$	8	3.3	%	$	9	1.9	%
Sales growth	4		1.7		6		1.3
Weather	(2)		(0.8)		2		0.4
Fuel and other cost recovery	22		9.1		43		9.3
Retail revenues	$	32	13.3	%	$	60	12.9	%

Changes in rates and pricing resulted in increases in revenues in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024 primarily due to new PEP rates that became effective for the first billing cycle of April 2025. See Note (B) to the Condensed Financial Statements "Mississippi Power – Performance Evaluation Plan" for additional information.

Changes in sales resulted in increases in revenues in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024. Weather-adjusted residential KWH sales increased 2.4% in the second quarter 2025 primarily due to increased customer usage and were flat for year-to-date 2025. Weather-adjusted commercial KWH sales decreased 0.9% and 0.2% in the second quarter and year-to-date 2025, respectively, primarily due to decreased customer usage. Industrial KWH sales increased 3.7% and 4.3% in the second quarter and year-to-date 2025, respectively, primarily due to increases in the chemical and petroleum sectors.

Fuel and other cost recovery revenues increased in the second quarter and year-to-date 2025 when compared to the corresponding periods in 2024 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 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$8	14.8	$20	17.7

In the second quarter 2025, wholesale revenues from sales to non-affiliates were $62 million compared to $54 million for the corresponding period in 2024. The increase was primarily due to an increase associated with MRA customers largely due to higher recoverable fuel costs.

For year-to-date 2025, wholesale revenues from sales to non-affiliates were $133 million compared to $113 million for the corresponding period in 2024. The increase was primarily due to a $14 million increase associated with MRA customers largely due to higher recoverable fuel costs and a $5 million increase associated with changes in power supply agreements.

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

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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.

Wholesale Revenues – Affiliates


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(3)	(5.2)	$27	24.8

In the second quarter 2025, wholesale revenues from sales to affiliates were $55 million compared to $58 million for the corresponding period in 2024. The decrease was primarily due to a $12 million decrease related to the volume of KWH sales, partially offset by a $9 million increase related to the price of energy driven by natural gas prices.

For year-to-date 2025, wholesale revenues from sales to affiliates were $136 million compared to $109 million for the corresponding period in 2024. The increase was primarily due to an 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 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(1)	(10.0)	$8	36.4

For year-to-date 2025, other revenues were $30 million compared to $22 million for the corresponding period in 2024. The increase was primarily due to customer charges related to contributions in aid of construction included in rates.

Fuel and Purchased Power Expenses


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Fuel	$	21	19.8	%	$	71	33.6	%
Purchased power	5		45.5		9		50.0
Total fuel and purchased power expenses	$	26			$	80

In the second quarter 2025, total fuel and purchased power expenses were $143 million compared to $117 million for the corresponding period in 2024. The increase was primarily due to a net increase related to the average cost of fuel and purchased power.

For year-to-date 2025, total fuel and purchased power expenses were $309 million compared to $229 million for the corresponding period in 2024. The increase was due to a $65 million increase related to the average cost of fuel and purchased power and a $15 million increase related to the volume of KWHs generated and purchased.

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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 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 2025	Second Quarter 2024	Year-to-Date 2025	Year-to-Date 2024
Total generation (in millions of KWHs)	3,945	4,456	8,484	8,408
Total purchased power (in millions of KWHs)	403	231	591	401
Sources of generation (percent) –
Gas	89	93	90	92
Coal	11	7	10	8
Cost of fuel, generated (in cents per net KWH) –
Gas	3.26	2.24	3.39	2.44
Coal	5.03	5.83	4.98	5.25
Average cost of fuel, generated (in cents per net KWH)	3.47	2.52	3.57	2.68
Average cost of purchased power (in cents per net KWH)	3.88	4.89	4.48	4.36

Other Operations and Maintenance Expenses


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(1)	(1.2)	$(5)	(2.9)

In the second quarter 2025, other operations and maintenance expenses were $82 million compared to $83 million for the corresponding period in 2024. For year-to-date 2025, other operations and maintenance expenses were $166 million compared to $171 million for the corresponding period in 2024. The second quarter and year-to-date 2025 included $10.9 million of reliability-related expenses that were offset by utilization of the reliability reserve. See Note (B) to the Condensed Financial Statements "Mississippi Power – Reliability Reserve Accounting Order" for additional information.

Depreciation and Amortization


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$5	10.6	$12	12.9

In the second quarter 2025, depreciation and amortization was $52 million compared to $47 million for the corresponding period in 2024. For year-to-date 2025, depreciation and amortization was $105 million compared to $93 million for the corresponding period in 2024. The increases were primarily due to an increase in depreciation rates and additional plant in service. See Note (A) to the Condensed Financial Statements under "Depreciation and Amortization" herein for additional information.

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Taxes Other Than Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$4	12.5	$6	9.5

In the second quarter 2025, taxes other than income taxes were $36 million compared to $32 million for the corresponding period in 2024. For year-to-date 2025, taxes other than income taxes were $69 million compared to $63 million for the corresponding period in 2024. The increases were primarily due to increases in property taxes primarily resulting from an increase in the assessed value of property.

Other Income (Expense), Net


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(2)	(18.2)	$(9)	(36.0)

For year-to-date 2025, other income (expense), net was $16 million compared to $25 million for the corresponding period in 2024. The decrease was primarily due to lower customer charges related to contributions in aid of construction.

Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$2	13.3	$9	36.0

For year-to-date 2025, income taxes were $34 million compared to $25 million for the corresponding period in 2024. The increase was primarily due to a decrease of $6 million in the flowback of certain excess deferred income taxes and higher pre-tax earnings. See Note (G) to the Condensed Financial Statements herein for additional information.

Southern Power

Net Income Attributable to Southern Power


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(35)	(40.7)	$(44)	(24.2)

Net income attributable to Southern Power in the second quarter 2025 was $51 million compared to $86 million for the corresponding period in 2024. The decrease was primarily due to accelerated depreciation related to wind repowering projects and an increase in other operations and maintenance expenses due to increases in scheduled outage expenses and generation maintenance, partially offset by higher HLBV income associated with tax equity partnerships.

Net income attributable to Southern Power for year-to-date 2025 was $138 million compared to $182 million for the corresponding period in 2024. The decrease was primarily due to accelerated depreciation related to wind repowering projects and an increase in other operations and maintenance expenses due to increases in scheduled outage expenses and generation maintenance, partially offset by higher revenues driven by higher market prices of energy and higher HLBV income associated with tax equity partnerships.

See Note (K) to the Condensed Financial Statements under "Southern Power – Wind Repowering Projects" herein and Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

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Operating Revenues


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$22	4.2	$116	11.6

Total operating revenues include PPA capacity revenues, which are 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.

Operating Revenues Details

Details of Southern Power's operating revenues were as follows:


	Second Quarter 2025		Second Quarter 2024		Year-to-Date 2025		Year-to-Date 2024
	(in millions)
PPA capacity revenues	$	124	$	122	$	246	$	244
PPA energy revenues	345		331		716		612
Total PPA revenues	469		453		962		856
Non-PPA revenues	69		60		137		120
Other revenues	8		11		14		21
Total operating revenues	$	546	$	524	$	1,113	$	997

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In the second quarter 2025, total operating revenues were $546 million, reflecting a $22 million, or 4.2%, increase from the corresponding period in 2024. The change in operating revenues was primarily due to the following:

•PPA energy revenues increased $14 million, or 4.2%, primarily due to an increase of $25 million related to the volume of KWHs sold under natural gas PPAs, partially offset by a decrease of $8 million driven by fuel and purchased power prices.

•Non-PPA revenues increased $9 million, or 15.0%, primarily due to an increase of $10 million driven by the market price of energy.

For year-to-date 2025, total operating revenues were $1.1 billion, reflecting a $116 million, or 11.6%, increase from the corresponding period in 2024. The change in operating revenues was primarily due to the following:

•PPA energy revenues increased $104 million, or 17.0%, due to an increase of $58 million primarily related to the volume of KWHs sold under natural gas PPAs and an increase of $46 million driven by fuel and purchased power prices.

•Non-PPA revenues increased $17 million, or 14.2%, due to an increase of $36 million driven by the market price of energy, partially offset by a decrease of $19 million related to the volume of KWHs sold through short-term sales.

•Other revenues decreased $7 million, or 33.3%, primarily due to a $15 million decrease associated with transmission revenues, partially offset by a $6 million increase in receipts associated with liquidated damages related to generation facility production guarantees and warranty settlements.

Fuel and Purchased Power Expenses

Details of Southern Power's generation and purchased power were as follows:


	Second Quarter 2025	Second Quarter 2024	Year-to-Date 2025	Year-to-Date 2024
	(in billions of KWHs)
Generation	11.6	11.0	22.5	21.3
Purchased power	0.8	0.8	1.3	1.2
Total generation and purchased power	12.4	11.8	23.8	22.5

Total generation and purchased power (excluding solar, wind, fuel cells, and tolling agreements)	7.5	6.6	14.5	13.2

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.

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Details of Southern Power's fuel and purchased power expenses were as follows:


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)
Fuel	$	15	11.4	%	$	67	23.3	%
Purchased power	9		40.9		19		47.5
Total fuel and purchased power expenses	$	24			$	86

In the second quarter 2025, total fuel and purchased power expenses increased $24 million, or 15.6%, compared to the corresponding period in 2024. Fuel expense increased $15 million due to a $22 million increase related to the volume of KWHs generated, partially offset by a $7 million decrease associated with the average cost of fuel. Purchased power expense increased $9 million due to an increase associated with the average cost of purchased power.

For year-to-date 2025, total fuel and purchased power expenses increased $86 million, or 26.2%, compared to the corresponding period in 2024. Fuel expense increased $67 million due to a $37 million increase associated with the average cost of fuel and a $30 million increase related to the volume of KWHs generated. Purchased power expense increased $19 million primarily due to a $17 million increase associated with the average cost of purchased power.

Other Operations and Maintenance Expenses


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$16	13.4	$16	6.6

In the second quarter 2025, other operations and maintenance expenses were $135 million compared to $119 million for the corresponding period in 2024. For year-to-date 2025, other operations and maintenance expenses were $257 million compared to $241 million for the corresponding period in 2024. The increases were primarily due to increases in scheduled outage and generation maintenance expenses.

Depreciation and Amortization


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$50	39.4	$84	34.3

In the second quarter 2025, depreciation and amortization was $177 million compared to $127 million for the corresponding period in 2024. For year-to-date 2025, depreciation and amortization was $329 million compared to $245 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were primarily due to accelerated depreciation of $42 million and $69 million, respectively, related to wind repowering projects. See Note (K) to the Condensed Financial Statements under "Southern Power – Wind Repowering Projects" herein and Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Income Taxes (Benefit)

Second Quarter 2025 vs. Second Quarter 2024

Year-to-Date 2025 vs. Year-to-Date 2024

(change in millions)

(% change)

(change in millions)

(% change)

$(15)

N/M

$(2)

N/M

In the second quarter 2025, income tax benefit was $2 million compared to income tax expense of $13 million for the corresponding period in 2024. For year-to-date 2025, income tax benefit was $3 million compared to $1 million for the corresponding period in 2024. The changes were primarily due to a change in pre-tax earnings attributable to

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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 for additional information.

Net Loss Attributable to Noncontrolling Interests


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(12)	(80.0)	$(18)	(24.7)

In the second quarter 2025, net loss attributable to noncontrolling interests was $27 million compared to $15 million for the corresponding period in 2024. The increase was primarily due to $9 million in lower income allocations to equity partners and $4 million in higher HLBV loss allocations to tax equity partners.

For year-to-date 2025, net loss attributable to noncontrolling interests was $91 million compared to $73 million for the corresponding period in 2024. The increase was primarily due to $12 million in higher HLBV loss allocations to tax equity partners and $7 million in lower income allocations to equity partners.

Southern Company Gas

Southern Company Gas measures weather and the effect on its business using Heating Degree Days. Generally, increased Heating Degree Days results in higher demand for natural gas on Southern Company Gas' distribution system. Southern Company Gas has various regulatory mechanisms, such as weather and revenue normalization and straight-fixed-variable rate design, which limit its 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 for gas distribution operations and 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 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(2)	(1.9)	$7	1.4

Southern Company Gas' net income in the second quarter 2025 was $106 million compared to $108 million for the corresponding period in 2024. The decrease was primarily due to a $7 million decrease in net income at gas pipeline investments and a $5 million increase in net loss at all other, largely offset by an $11 million increase in net income at gas distribution operations.

For year-to-date 2025, net income was $524 million compared to $517 million for the corresponding period in 2024. The increase was primarily due to a $24 million increase in net income at gas distribution operations, partially offset by an $11 million decrease in net income at gas pipeline investments and a $6 million decrease in net income at all other.

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Natural Gas Revenues


	Second Quarter 2025 vs. Second Quarter 2024				Year-to-Date 2025 vs. Year-to-Date 2024
	(change in millions)		(% change)		(change in millions)		(% change)

Rates	$	28	3.4	%	$	71	2.8	%
Gas costs and other cost recovery	104		12.5		166		6.5
Gas marketing services	17		2.0		35		1.4

Other	(1)		(0.1)		8		0.3
Natural gas revenues	$	148	17.8	%	$	280	11.0	%

Revenues from gas marketing services increased in the second quarter and year-to-date 2025 compared to the corresponding periods in 2024 primarily due to higher commodity prices.

Cost of Natural Gas


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$106	71.1	$175	23.2

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 85% and 82% of the total cost of natural gas in the second quarter and year-to-date 2025, 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 2025, cost of natural gas was $255 million compared to $149 million for the corresponding period in 2024. For year-to-date 2025, cost of natural gas was $929 million compared to $754 million for the corresponding period in 2024. The increases reflect higher gas cost recovery as a result of increases of 81.6% and 71.5% in natural gas prices in the second quarter and year-to-date 2025, respectively.

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The following table details the volumes of natural gas sold during all periods presented:


	Second Quarter				Year-to-Date
	2025	2024	2025 vs. 2024		2025	2024	2025 vs. 2024
Gas distribution operations (mmBtu in millions)
Firm	102	95	7.4	%	403	361	11.6	%
Interruptible	20	22	(9.1)		43	47	(8.5)
Total	122	117	4.3	%	446	408	9.3	%

Gas marketing services (mmBtu in millions)
Firm:
Georgia	4	5	(20.0)	%	22	22	—	%
Illinois	—	1	(100.0)		3	3	—

Other	4	2	100.0		12	9	33.3
Interruptible large commercial and industrial	3	4	(25.0)		7	8	(12.5)
Total	11	12	(8.3)	%	44	42	4.8	%

Other Operations and Maintenance Expenses


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$13	4.5	$36	6.2

In the second quarter 2025, other operations and maintenance expenses were $301 million compared to $288 million for the corresponding period in 2024. For year-to-date 2025, other operations and maintenance expenses were $617 million compared to $581 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were primarily due to increases of $15 million and $32 million, respectively, in employee compensation and benefit expenses and $8 million and $20 million, respectively, in expenses passed through to customers primarily related to bad debt and energy efficiency programs at gas distribution operations, partially offset by decreases of $5 million and $12 million, respectively, related to deferred expenses.

Depreciation and Amortization


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$14	8.9	$28	8.9

In the second quarter 2025, depreciation and amortization was $172 million compared to $158 million for the corresponding period in 2024. For year-to-date 2025, depreciation and amortization was $341 million compared to $313 million for the corresponding period in 2024. The increases were primarily due to additional plant in service related to continued investments at the natural gas distribution utilities.

Taxes Other Than Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$5	8.9	$15	10.5

In the second quarter 2025, taxes other than income taxes were $61 million compared to $56 million for the corresponding period in 2024. For year-to-date 2025, taxes other than income taxes were $158 million compared to $143 million for the corresponding period in 2024. The increases for the second quarter and year-to-date 2025 were

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primarily due to increases in revenue taxes of $4 million and $14 million, respectively, as a result of higher natural gas revenues at Nicor Gas. Revenue taxes imposed on Nicor Gas are recoverable from its customers.

Earnings from Equity Method Investments


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(9)	(28.1)	$(14)	(18.4)

In the second quarter 2025, earnings from equity method investments were $23 million compared to $32 million for the corresponding period in 2024. For year-to-date 2025, earnings from equity method investments were $62 million compared to $76 million for the corresponding period in 2024. The decreases were primarily due to lower rates 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 herein under "Southern Company Gas" for additional information.

Interest Expense, Net of Amounts Capitalized


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$9	10.8	$16	9.6

In the second quarter 2025, interest expense, net of amounts capitalized was $92 million compared to $83 million for the corresponding period in 2024. For year-to-date 2025, interest expense, net of amounts capitalized was $183 million compared to $167 million for the corresponding period in 2024. The increases were primarily associated with higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" herein for additional information on borrowings.

Income Taxes


Second Quarter 2025 vs. Second Quarter 2024		Year-to-Date 2025 vs. Year-to-Date 2024
(change in millions)	(% change)	(change in millions)	(% change)
$(3)	(8.3)	$(12)	(6.9)

For year-to-date 2025, income taxes were $162 million compared to $174 million for the corresponding period in 2024. The decreases were primarily due to the flowback of excess state deferred income taxes. See Note (G) to the Condensed Financial Statements herein for additional information.

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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.


	2025						2024
	Operating Revenues		Operating Expenses		Net Income (Loss)		Operating Revenues		Operating Expenses		Net Income (Loss)
	(in millions)
Second Quarter
Gas distribution operations	$	885	$	707	$	91	$	749	$	582	$	80
Gas pipeline investments	8		2		15		8		2		22
Gas marketing services	83		71		8		70		57		9
All other	5		7		(8)		7		9		(3)
Intercompany eliminations	(2)		2		—		(3)		1		—
Consolidated	$	979	$	789	$	106	$	831	$	651	$	108

Year-to-Date
Gas distribution operations	$	2,454	$	1,789	$	406	$	2,212	$	1,571	$	382
Gas pipeline investments	16		5		41		16		5		52
Gas marketing services	345		241		74		305		205		74
All other	9		9		3		13		11		9
Intercompany eliminations	(6)		1		—		(8)		(1)		—
Consolidated	$	2,818	$	2,045	$	524	$	2,538	$	1,791	$	517

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 consumption, the earnings of the natural gas distribution utilities can be affected by customer consumption patterns that are a function of weather conditions, price levels for natural gas, and general economic conditions that may impact customers' ability to pay for natural gas consumed. Southern Company Gas has various regulatory and other mechanisms, such as weather and revenue normalization mechanisms and weather derivative instruments, that limit its exposure to changes in customer consumption, including weather changes within typical ranges in its natural gas distribution 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 2025, net income increased $11 million, or 13.8%, when compared to the corresponding period in 2024, as described further below:

•Operating revenues increased $136 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.

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•Operating expenses increased $125 million primarily due to a $96 million increase in cost of natural gas as a result of higher gas prices and higher volumes sold compared to 2024, a $14 million increase in depreciation primarily due to additional plant in service related to continued investments at the natural gas distribution utilities, and an $8 million increase related to expenses passed through to customers primarily related to bad debt and energy efficiency programs.

•Interest expense, net of amounts capitalized increased $6 million primarily due to higher average outstanding borrowings.

For year-to-date 2025, net income increased $24 million, or 6.3%, when compared to the corresponding period in 2024, as described further below:

•Operating revenues increased $242 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 $218 million primarily due to a $145 million increase in cost of natural gas as a result of higher gas prices and higher volumes sold compared to 2024, a $28 million increase in depreciation primarily due to additional plant in service related to continued investments at the natural gas distribution utilities, and a $20 million increase related to expenses passed through to customers primarily related to bad debt and energy efficiency programs.

•Interest expense, net of amounts capitalized increased $10 million primarily due to higher average outstanding borrowings.

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 and year-to-date 2025, net income decreased $7 million and $11 million, respectively, when compared to the corresponding periods in 2024. The decreases were primarily due to lower rates at SNG.

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 2025, net loss increased $5 million when compared to the corresponding period in 2024. For year-to-date 2025, net income decreased $6 million when compared to the corresponding period in 2024. The changes were primarily due to higher interest expense as a result of higher average outstanding borrowings.

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 result from the presidential administration.

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 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

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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. These growth opportunities could be offset by energy efficiency trends in each market.

Economic uncertainty and policy uncertainty have increased the volatility of future economic outlooks above historical norms. Significant changes in fiscal, monetary, or trade policies could disrupt anticipated economic outlooks. This uncertainty in economic growth, interest rates, tariffs, and inflation could impact customer demand for energy, access to capital markets, and the cost of doing business. The shifting economic policy variables and weakening of historic relationships among economic activity, prices, and employment have increased the uncertainty of future levels of economic activity, which will directly impact future energy demand and operating costs. Weakening economic activity increases the risk of slowing or declining energy sales. See RESULTS OF OPERATIONS herein for information on energy sales in the Southern Company system's service territory during the first six months of 2025.

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 renewable 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 Inflation Reduction Act's expansion of the availability of federal ITCs and PTCs and "Income Tax Matters – Federal Tax Legislation" herein for information regarding the One Big Beautiful Bill Act's (OBBB) 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, 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.

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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 in data centers; 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, which may impact future earnings.

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, partnerships, 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

Air Quality

On April 14, 2025, the U.S. Court of Appeals for the D.C. Circuit granted the EPA's motion to hold in abeyance the litigation regarding the 2015 Ozone National Ambient Air Quality Standards (NAAQS) Good Neighbor federal implementation plan (FIP).

On March 25, 2025, the U.S. Court of Appeals for the Fifth Circuit vacated and remanded the EPA's disapproval of the Mississippi state implementation plan (SIP) addressing interstate transport provisions of the Clean Air Act for the 2015 NAAQS. The decision protects the State of Mississippi from the requirements of the federal Good Neighbor plan unless or until the EPA properly disapproves Mississippi's SIP.

On June 18, 2025, the U.S. Supreme Court issued an opinion holding that the proper venue for reviewing interstate transport SIP disapprovals are regional appellate courts instead of the U.S. Court of Appeals for the D.C. Circuit.

The ultimate impact of the FIP and associated legal matters cannot be determined at this time; however, implementation of the stayed FIP would likely result in increased compliance costs for the traditional electric operating companies.

Water Quality

On February 28, 2025, the U.S. Court of Appeals for the Eighth Circuit granted the EPA's motion to hold the 2024 ELG Rule litigation in abeyance for 60 days. On March 12, 2025, the EPA announced its intent to reconsider the

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standards finalized in the 2024 ELG Rule, including the new technology-based ELGs for leachate. On May 1, 2025, the U.S. Court of Appeals for the Eighth Circuit granted the EPA's motion requesting an additional 60-day abeyance of the 2024 ELG Rule litigation. On July 11, 2025, the U.S. Court of Appeals for the Eighth Circuit granted the EPA's request to continue to hold the 2024 ELG Rule litigation in abeyance for another 30 days. The ultimate impact of the 2024 ELG Rule and associated legal matters cannot be determined at this time; however, it may result in significant compliance costs.

Coal Combustion Residuals

On March 12, 2025, the EPA announced its intent to undertake several regulatory actions related to the CCR Rule, including reviewing the 2024 Legacy Rule and evaluating whether to grant short- and long-term relief, such as extending compliance deadlines. On June 13, 2025, the U.S. Court of Appeals for the D.C. Circuit granted the EPA's motion requesting an additional 60-day abeyance of the litigation over the 2024 Legacy Rule.

On January 16, 2025, the EPA simultaneously published a direct final rule and companion proposed rule that included identical revisions to certain definitions in the 2024 Legacy Rule. On March 20, 2025, the EPA published a notice withdrawing its direct final rule and stating the EPA's intent to respond to comments received on the companion proposed rule. On July 22, 2025, the EPA published a direct final rule and companion proposed rule extending certain deadlines for compliance for owners and operators of CCR management units. The ultimate impact of any final rule and associated legal matters cannot be determined at this time; however, it may result in significant compliance costs.

Based on compliance requirements for closure and monitoring of CCR units 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.

Greenhouse Gases

On February 19, 2025, the U.S. Court of Appeals for the D.C. Circuit granted the EPA's motion to hold the litigation over the 2024 GHG Rules in abeyance for 60 days. On April 25, 2025, the U.S. Court of Appeals for the D.C. Circuit granted the EPA's motion requesting a continuing abeyance of the litigation over the 2024 GHG Rules. The EPA states in its motion that the agency will issue a proposed reconsideration rule in spring 2025 and a final reconsideration rule by December 2025. On June 17, 2025, the EPA published a proposed rule that, if finalized, would repeal all or a portion of the 2024 GHG Rules. The proposed rule includes a primary proposal and an alternative proposal. Under the primary proposal, the EPA would repeal all emissions standards promulgated under Section 111 of the Clean Air Act based on a finding that fossil fuel-fired power plants do not contribute significantly to dangerous air pollution. Under the alternative proposal, the EPA would repeal all of the emissions guidelines for existing fossil fuel-fired steam generating units as well as the carbon capture and storage requirement for new base load stationary combustion turbines. The ultimate impact of the final rules and associated legal matters cannot be determined at this time; however, it may result in significant compliance costs.

In 2009, the EPA finalized its determination that concentration of certain GHGs in the atmosphere represent a danger to public health and welfare, and such endangerment finding is a prerequisite for regulation of GHG emissions from electric generating units. On March 21, 2025, the EPA announced its intent to ask for public comment on its reconsideration of this endangerment finding. On July 29, 2025, the EPA released a proposed rule to repeal the 2009 endangerment finding with regard to motor vehicles. In the proposal, the EPA acknowledged that

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other Clean Air Act rulemakings, including those for electric generating units, have partially relied on the 2009 endangerment finding, and the EPA said it would address any overlapping issues in separate rulemakings. The ultimate impact of this proposal cannot be determined at this time.

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.

Construction Programs

The Southern Company system strategy continues to include developing and constructing new electric generating 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 investment and a return. 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 – Integrated Resource Plans" and " – Other Construction" herein for information regarding Georgia Power's future and current construction projects.

Alabama Power executed an agreement to build a battery energy storage facility at the former Plant Gorgas site in Walker County, Alabama. The new Gorgas battery facility is designed to have the capacity to store up to 150 MWs of electricity generated by other Alabama Power resources. Construction is expected to begin in the third quarter 2025, with estimated completion by 2027.

Southern Power's construction program includes the Millers Branch solar project and the Kay Wind, Grant Plains, Grant Wind, and Wake Wind repowering projects. The repowering projects result in accelerated depreciation related to the equipment being replaced that will continue until the commercial operation dates of the projects, which are projected to occur between the third quarter 2026 and the second quarter 2027. At June 30, 2025, the remaining pre-tax accelerated depreciation, net of noncontrolling interest impacts, is projected to total approximately $215 million in 2025, $320 million in 2026, and $25 million in 2027. The ultimate outcome of this matter cannot be determined at this time. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for information relating to Southern Power's construction of renewable energy facilities.

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 investment and a return associated with these infrastructure programs through their regulated rates, as approved by their applicable state regulatory agency. See Note 2 to the financial statements 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.

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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 was signed into law on July 4, 2025. It extends many of the Tax Cuts and Jobs Act's provisions that were set to expire and makes some of them permanent. The OBBB includes major changes to tax incentives for renewable energy projects. The legislation restricts the ITCs and PTCs for solar and wind power projects, which were originally set to run through 2032. Such projects must now either begin construction by July 2026 or be fully operational by the end of 2027 in order to claim the applicable tax credits. Nuclear, hydropower, and geothermal energy projects maintain tax credits under the new law. Battery energy storage projects retain their full tax credit through 2033, with a gradual phase-out by 2036. The OBBB adds new restrictions for tax credits for renewable facilities that are owned or influenced by a prohibited foreign entity or receive material assistance from a prohibited foreign entity. Following enactment of the OBBB, the president issued an executive order directing the U.S. Treasury to issue new and revised wind and solar tax credit guidance within 45 days. Additionally, the IRS is expected to issue significant guidance on the tax provisions in the OBBB. Southern Company is still assessing and will continue to monitor the impacts of the OBBB. The ultimate outcome of this legislation cannot be determined at this time.

Georgia State Tax Legislation

On April 15, 2025, the State of Georgia enacted tax legislation that reduced the corporate income tax rate from 5.39% to 5.19% effective for the 2025 tax year. This legislation reduced the amount of Southern Company's and certain subsidiaries' income tax expense in the State of Georgia and existing state net accumulated deferred tax liabilities, increased regulatory liabilities at Georgia Power and Southern Company Gas, and reduces Georgia Power's ability to utilize certain state tax credits in the State of Georgia. The legislation did not have a material impact on the net income of the applicable Registrants in 2025.

Zero-Emission Nuclear Power Production Tax Credit

Alabama Power and Georgia Power have nuclear generating facilities that qualify for Internal Revenue Code §45U PTCs for the 2024 tax year that are expected to be claimed on Southern Company's consolidated tax return by October 15, 2025. The base credit amounts are $75 million, $36 million, and $39 million for Southern Company, Alabama Power, and Georgia Power, respectively, which have been recorded as a regulatory liability. Additionally, each company may qualify for the prevailing wage multiplier which would allow Southern Company, Alabama Power, and Georgia Power to claim §45U PTCs totaling $373 million, $180 million, and $193 million, respectively. The §45U PTC is available for tax years 2024 to 2032 and is subject to a phase-out. As such, Southern Company, Alabama Power, and Georgia Power will each evaluate annually whether it qualifies for the credit. The ultimate outcome of this matter cannot be determined at this time.

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.

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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, 2025. 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 2025, the market price of Southern Company's common stock was $91.83 per share (based on the closing price as reported on the NYSE) and the book value was $30.92 per share, representing a market-to-book ratio of 297%, compared to $82.32, $30.28, and 272%, respectively, at the end of 2024. Southern Company's common stock dividend for the second quarter 2025 was $0.74 per share compared to $0.72 per share in the second quarter 2024.

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, 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 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 June and July 2025, Georgia Power requested certification from the Georgia PSC for several Georgia Power-owned projects through various RFPs. Estimated capital expenditures associated with these projects and related transmission investments through 2029 total approximately $14.3 billion, excluding previously committed expenditures and AFUDC. See Note (B) to the Condensed Financial Statements under "Georgia Power – Integrated Resource Plans" for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

During the second quarter 2025, Southern Power committed to development projects to repower the Grant Plains, Grant Wind, and Wake Wind facilities. The remaining aggregate construction costs for these projects are expected to be between $715 million and $805 million. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

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, 2024.

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. Operating cash flows provide a substantial portion of the Registrants' cash needs.

The amount, type, and timing of any financings in 2025, 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, 2025, the amount of subsidiary retained earnings restricted to dividend totaled $1.8 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 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, 2025 for the applicable Registrants:


At June 30, 2025	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
Current liabilities in excess of current assets	$	3,769	$	921	$	1,321	$	1,171

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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Bank Credit Arrangements

At June 30, 2025, unused committed credit arrangements with banks were as follows:


At June 30, 2025	Southern Company parent		Alabama Power(a)		Georgia Power		Mississippi Power		Southern Power(b)		Southern Company Gas(c)		SEGCO		Southern Company
	(in millions)
Unused committed credit	$	2,999	$	1,364	$	2,026	$	275	$	600	$	1,598	$	30	$	8,892

(a)Includes $14 million at Alabama Property Company, a wholly-owned subsidiary of Alabama Power. Alabama Power is not party to this arrangement.

(b)At June 30, 2025, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $21 million was unused. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(c)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.

See Note 8 to the financial statements in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein under "Bank Credit Arrangements" 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-

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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, 2025				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	$	988	4.6	%	$	876	4.9	%	$	1,610
Alabama Power	—		—		1		4.4		40
Georgia Power	285		4.7		451		5.0		1,025
Mississippi Power	32		4.6		8		4.6		34
Southern Power	200		4.6		35		4.6		200
Southern Company Gas:
Southern Company Gas Capital	471		4.7		339		4.7		507

(*)Average and maximum amounts are based upon daily balances during the three-month period ended June 30, 2025.

Analysis of Cash Flows

Net cash flows provided from (used for) operating, investing, and financing activities for the six months ended June 30, 2025 and 2024 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, 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)

Six Months Ended June 30, 2024
Operating activities	$	3,999	$	877	$	1,680	$	85	$	230	$	1,270
Investing activities	(4,222)		(951)		(2,199)		(218)		(127)		(696)
Financing activities	513		(46)		551		114		(85)		(574)

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 decreased $568 million for the six months ended June 30, 2025 as compared to the corresponding period in 2024 primarily due to the timing of vendor payments, decreased retail fuel cost recovery, primarily at Alabama Power, and storm restoration costs at Georgia Power, partially offset by the timing of materials and supplies purchases. See Note 2 to the financial statements under "Georgia Power – Storm Damage Recovery" in Item 8 of the Form 10-K for additional information relating to storm restoration costs.

The net cash used for investing activities for the six months ended June 30, 2025 was primarily related to the Subsidiary Registrants' construction programs.

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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, 2025 was primarily related to net issuances of long-term debt, partially offset by common stock dividend payments.

Alabama Power

Net cash provided from operating activities decreased $199 million for the six months ended June 30, 2025 as compared to the corresponding period in 2024 primarily due to a decrease in fuel cost recovery and customer refunds associated with the nuclear fuel disposal cost award, partially offset by the timing of vendor payments. See Note 3 to the financial statements under "Nuclear Fuel Disposal Cost" 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, 2025 was primarily related to gross property additions.

The net cash provided from financing activities for the six months ended June 30, 2025 was primarily related to capital contributions from Southern Company and net issuances of senior notes, partially offset by common stock dividend payments.

Georgia Power

Net cash provided from operating activities decreased $345 million for the six months ended June 30, 2025 as compared to the corresponding period in 2024 primarily due to the timing of vendor payments and storm restoration costs, partially offset by the timing of customer receivable collections. See Note 2 to the financial statements under "Georgia Power – Storm Damage Recovery" in Item 8 of the Form 10-K for additional information relating to storm restoration costs.

The net cash used for investing activities for the six months ended June 30, 2025 was primarily related to gross property additions.

Mississippi Power

Net cash provided from operating activities decreased $7 million for the six months ended June 30, 2025 as compared to the corresponding period in 2024 primarily due to decreased fuel cost recovery, partially offset by the timing of fossil fuel stock purchases.

The net cash used for investing activities for the six months ended June 30, 2025 was primarily related to gross property additions, partially offset by contributions in aid of construction.

The net cash provided from financing activities for the six months ended June 30, 2025 was primarily related to issuances of senior notes and capital contributions from Southern Company, partially offset by common stock dividend payments.

Southern Power

Net cash provided from operating activities increased $2 million for the six months ended June 30, 2025 as compared to the corresponding period in 2024.

The net cash used for investing activities for the six months ended June 30, 2025 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, 2025 was primarily related to an increase in commercial paper borrowings and capital contributions from Southern Company, partially offset by common stock dividend payments and net distributions to noncontrolling interests.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Company Gas

Net cash provided from operating activities decreased $60 million for the six months ended June 30, 2025 as compared to the corresponding period in 2024 primarily due to the timing of customer receivable collections.

The net cash used for investing activities for the six months ended June 30, 2025 was primarily related to construction of transportation and distribution assets recovered through base rates.

The net cash used for financing activities for the six months ended June 30, 2025 was primarily related to common stock dividend payments.

Significant Balance Sheet Changes

Southern Company

Significant balance sheet changes for the six months ended June 30, 2025 included:

•an increase of $4.9 billion in long-term debt (including securities due within one year) primarily related to issuances of senior notes and junior subordinated notes, partially offset by repayment of senior notes;

•an increase of $3.5 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants' construction programs;

•a decrease of $753 million in accounts payable primarily related to the timing of vendor payments;

•an increase of $668 million in total stockholders' equity primarily related to net income, partially offset by common stock dividend payments;

•an increase of $564 million in accumulated deferred income taxes primarily related to property-related timing differences and monetization of tax credits in 2025;

•a decrease of $436 million in accrued compensation due to the timing of payments;

•decreases of $389 million and $307 million in AROs and regulatory assets associated with AROs, respectively, primarily related to cost estimate updates at Alabama Power; and

•a decrease of $350 million in notes payable primarily due to repayment of short-term bank debt and a reduction in commercial paper borrowings.

See "Financing Activities" and Note (A) to the Condensed Financial Statements under "Asset Retirement Obligations" herein for additional information.

Alabama Power

Significant balance sheet changes for the six months ended June 30, 2025 included:

•an increase of $712 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 $367 million in total property, plant, and equipment primarily related to the construction of transmission and distribution facilities;

•an increase of $351 million in long-term debt (including securities due within one year) primarily due to net issuances of senior notes;

•decreases of $305 million and $218 million in AROs and regulatory assets associated with AROs, respectively, primarily related to cost estimate updates;

•a decrease of $228 million in other accounts payable primarily due to the timing of vendor payments; and

•a decrease of $191 million in cash and cash equivalents, as reflected in the statements of cash flows and discussed further under "Analysis of Cash Flows – Alabama Power" herein.

See "Financing Activities – Alabama Power" and Note (A) to the Condensed Financial Statements under "Asset Retirement Obligations" herein for additional information.

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AND RESULTS OF OPERATIONS (Continued)

Georgia Power

Significant balance sheet changes for the six months ended June 30, 2025 included:

•an increase of $2.4 billion in total property, plant, and equipment primarily related to the construction of generation, transmission, and distribution facilities, including costs associated with Plant Yates Units 8, 9, and 10;

•an increase of $1.8 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;

•an increase of $1.3 billion in long-term debt (including securities due within one year) primarily due to net issuances of senior notes;

•a decrease of $522 million in accounts payable primarily related to timing of vendor payments;

•an increase of $286 million in accumulated deferred income taxes primarily related to increases in property-related timing differences and a valuation allowance on certain state tax credit carryforwards, partially offset by decreases for timing differences in fuel recovery and customer advances; and

•a decrease of $234 million in accrued taxes primarily due to payments for municipal franchise fees and property taxes.

See "Financing Activities – Georgia Power" and Notes (B) and (G) to the Condensed Financial Statements under "Georgia Power – Other Construction" and "Georgia Power," respectively, herein for additional information.

Mississippi Power

Significant balance sheet changes for the six months ended June 30, 2025 included:

•an increase of $99 million in long-term debt (including securities due within one year) primarily due to issuances of senior notes;

•an increase of $83 million in total property, plant, and equipment primarily related to the construction of transmission and distribution facilities;

•an increase of $75 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 $53 million in other deferred credits and liabilities primarily due to contributions in aid of construction; and

•a decrease of $49 million in accrued taxes is primarily due to the payment of ad valorem taxes.

See "Financing Activities – Mississippi Power" herein for additional information.

Southern Power

Significant balance sheet changes for the six months ended June 30, 2025 included:

•an increase of $200 million in notes payable due to an increase in commercial paper borrowings;

•an increase of $136 million in total property, plant, and equipment due to an increase in CWIP primarily related to the continued construction of the Millers Branch solar facility and wind repowering projects, partially offset by the continued depreciation of assets;

•an increase of $67 million in long-term debt (including securities due within one year) primarily due to the change in fair value related to the foreign currency hedge on euro-denominated senior notes; and

•an increase of $62 million in customer accounts receivable, net primarily related to the timing of customer receivables.

See Notes (I) and (J) to the Condensed Financial Statements and Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

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AND RESULTS OF OPERATIONS (Continued)

Southern Company Gas

Significant balance sheet changes for the six months ended June 30, 2025 included:

•an increase of $446 million in total property, plant, and equipment primarily related to the construction of transportation and distribution assets;

•a decrease of $208 million in total accounts receivable primarily related to seasonality;

•an increase of $202 million in common stockholder's equity primarily related to net income, partially offset by dividends paid to Southern Company;

•a decrease of $191 million in natural gas for sale due to higher volumes of natural gas sold; and

•an increase of $182 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.

Financing Activities

The following table outlines long-term debt financing activities for the first six months of 2025:


	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	$	1,650	$	2,365		$	1,110	$	—
Alabama Power	600		4			250		1
Georgia Power	1,600		—			700		57
Mississippi Power	100		—			—		1


Other(b)	—		—			—		11
Elimination(c)	—		—			—		(1)
Southern Company	$	3,950	$	2,369		$	2,060	$	69

(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)Includes repayment by SEGCO of $10 million of its $100 million principal amount long-term bank loan due November 15, 2025, which is guaranteed by Alabama Power. At June 30, 2025, $70 million of the long-term bank loan remains outstanding. See Note 3 to the financial statements under "Guarantees" in Item 8 of the Form 10-K for additional information.

(c)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 2025, Southern Company issued approximately 3.4 million shares of common stock primarily through employee equity compensation and savings plans. Also during the first six months of 2025, Southern Company entered into forward sale contracts for the issuance of shares of common stock that may be settled through December 2026. See Note (F) to the Condensed Financial Statements under "Equity Distribution Agreement" herein for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

In January 2025, Southern Company issued $565 million aggregate principal amount of Series 2025A 6.50% Junior Subordinated Notes due March 15, 2085.

In February 2025, Southern Company issued $1.8 billion aggregate principal amount of Series 2025B 6.375% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due March 15, 2055.

In May 2025, Southern Company issued $1.65 billion aggregate principal amount of Series 2025A 3.25% Convertible Senior Notes due June 15, 2028 in a private offering. Southern Company used a portion of the proceeds from this issuance to repurchase approximately $781.6 million of the $1.725 billion aggregate principal amount outstanding of its Series 2023A 3.875% Convertible Senior Notes due December 15, 2025 and approximately $328.1 million of the $1.5 billion aggregate principal amount outstanding of its Series 2024A 4.50% Convertible Senior Notes due June 15, 2027. See Note (F) to the Condensed Financial Statements under "Convertible Senior Notes" herein for additional information.

Alabama Power

In March 2025, Alabama Power issued $500 million aggregate principal amount of Series 2025A 5.10% Senior Notes due April 2, 2035.

In April 2025, Alabama Power repaid at maturity $250 million aggregate principal amount of its Series 2015B 2.80% Senior Notes.

In June 2025, Alabama Power issued $100 million aggregate principal amount of Series 2025B Floating Rate Senior Notes due August 15, 2075.

Georgia Power

In March 2025, Georgia Power issued $400 million aggregate principal amount of Series 2025A Floating Rate Senior Notes due September 15, 2026, $500 million aggregate principal amount of Series 2025B 4.85% Senior Notes due March 15, 2031, and $700 million aggregate principal amount of Series 2025C 5.20% Senior Notes due March 15, 2035.

In May 2025, Georgia Power repaid at maturity $700 million aggregate principal amount of its Series 2023C Floating Rate Senior Notes.

Also in May 2025, Georgia Power entered into a $200 million short-term floating rate bank loan bearing interest based on term SOFR.

In June 2025, Georgia Power extended both of its short-term floating rate bank loans totaling $400 million to long-term term loans, which mature in June 2026.

Subsequent to June 30, 2025, Georgia Power repaid at maturity its obligations with respect to $45 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), First Series 1995.

Mississippi Power

In March 2025, Mississippi Power issued $50 million aggregate principal amount of Series 2025A 5.01% Senior Notes due March 15, 2030 and $50 million aggregate principal amount of Series 2025B 6.03% Senior Notes due March 15, 2055.

Subsequent to June 30, 2025, Mississippi Power repaid at maturity its obligations with respect to approximately $11 million aggregate principal amount of Mississippi Business Finance Corporation Solid Waste Disposal Facilities Revenue Bonds, Series 1995 (Mississippi Power Company Project).

Credit Rating Risk

At June 30, 2025, 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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

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, 2025 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	$	34	$	1	$	—	$	—	$	33	$	—
At BBB- and/or Baa3	456		2		36		—		417		—
At BB+ and/or Ba1 or below	3,626		421		2,352		274		1,351		14

(*)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, 2025.

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.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

During the six months ended June 30, 2025, 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 2025 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.

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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, during the three months ended June 30, 2025 for Southern Company's directors and "officers," as defined in Rule 16a-1(f) under the Securities Exchange Act of 1934, as amended. There were no modifications or terminations of such trading arrangements during the three months ended June 30, 2025. Unless otherwise indicated, each trading arrangement listed below is a "Rule 10b5-1 trading arrangement," provides for the sale of shares of Southern Company's common stock, commences no earlier than the expiration of the cooling-off period required by Rule 10b5-1(c)(1)(ii)(B)(1) under the Securities Exchange Act of 1934, as amended, and terminates upon the earlier of the "Expiration Date" listed below or the completion of all sales. The Subsidiary Registrants had no reportable trading arrangements for the three months ended June 30, 2025.

Name

Title

Date of Adoption

Expiration Date

Aggregate Number of Shares Covered

Bryan D. Anderson

Executive Vice President

May 30, 2025

September 30, 2026

6,206

Item 6. Exhibits.

The exhibits below with an asterisk (*) preceding the exhibit number are filed herewith. The remaining exhibits have previously been filed with the SEC and are incorporated herein by reference. The exhibits marked with a pound sign (#) are management contracts or compensatory plans or arrangements.

(3) Articles of Incorporation and By-Laws

Southern Company

(a)

Certificate of Amendment to the Certificate of Incorporation of Southern Company, effective May 27, 2025. (Designated in Form 8-K dated May 21, 2025, File No. 1-3526, as Exhibit 3.1 .)

(4) Instruments Describing Rights of Security Holders, Including Indentures

Southern Company

(a)

Thirty-Fourth Supplemental Indenture to Senior Note Indenture dated as of May 23, 2025, providing for the issuance of the Series 2025A 3.25% Convertible Senior Notes due June 15, 2028. (Designated in Form 8-K dated May 20 , 2025, File No. 1-3526 as Exhibit 4.2 .)

Alabama Power

(b)

Sixty-Ninth Supplemental Indenture to Senior Note Indenture dated as of June 13, 2025, providing for the issuance of the Series 2025B Floating Rate Senior Notes due August 15, 2075. (Designated in Form 8-K dated June 11 , 2025, File No. 1-3164 as Exhibit 4.6 .)

(24) Power of Attorney and Resolutions

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Southern Company

(a)

Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2024, File No. 1-3526 as Exhibit 24(a)1.)

Alabama Power

(b)

Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2024, File No. 1-3164 as Exhibit 24(b)1.)

Georgia Power

(c)

Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2024, File No. 1-6468 as Exhibit 24(c)1.)

Mississippi Power

(d)

Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2024, File No. 001-11229 as Exhibit 24(d)1.)

Southern Power

(e)

Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2024, File No. 001-37803 as Exhibit 24(e)1.)

Southern Company Gas

(f)

Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2024, File No. 1-14174 as Exhibit 24(f)1.)

(31) Section 302 Certifications

Southern Company

(a)1

Certificate of Southern Company's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

(a)2

Certificate of Southern Company's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Alabama Power

(b)1

Certificate of Alabama Power's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

(b)2

Certificate of Alabama Power's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Georgia Power

Certificate of Georgia Power's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Certificate of Georgia Power's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Mississippi Power

(d)1

Certificate of Mississippi Power's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

(d)2

Certificate of Mississippi Power's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Southern Power

(e)1

Certificate of Southern Power Company's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

(e)2

Certificate of Southern Power Company's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

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Southern Company Gas

(f)1

Certificate of Southern Company Gas' Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

(f)2

Certificate of Southern Company Gas' Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

(32) Section 906 Certifications

Southern Company

(a)

Certificate of Southern Company's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Alabama Power

(b)

Certificate of Alabama Power's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Georgia Power

(c)

Certificate of Georgia Power's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Mississippi Power

(d)

Certificate of Mississippi Power's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Southern Power

(e)

Certificate of Southern Power Company's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Southern Company Gas

(f)

Certificate of Southern Company Gas' Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

(101) Interactive Data Files

INS

Inline XBRL Instance Document – The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.

SCH

Inline XBRL Taxonomy Extension Schema Document

CAL

Inline XBRL Taxonomy Calculation Linkbase Document

DEF

Inline XBRL Definition Linkbase Document

LAB

Inline XBRL Taxonomy Label Linkbase Document

PRE

Inline XBRL Taxonomy Presentation Linkbase Document

(104) Cover Page Interactive Data File

Formatted as inline XBRL with applicable taxonomy extension information contained in Exhibits 101.

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THE SOUTHERN COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.


						THE SOUTHERN COMPANY

By						Christopher C. Womack
						Chairman, President, and Chief Executive Officer
						(Principal Executive Officer)

By						Daniel S. Tucker
						Executive Vice President and Chief Financial Officer
						(Principal Financial Officer)

By						/s/ Melissa K. Caen
						(Melissa K. Caen, Attorney-in-fact)

Date: July 30, 2025

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ALABAMA POWER COMPANY

SIGNATURES


						ALABAMA POWER COMPANY

By						J. Jeffrey Peoples
						Chairman, President, and Chief Executive Officer
						(Principal Executive Officer)

By						Moses H. Feagin
						Executive Vice President, Chief Financial Officer, and Treasurer
						(Principal Financial Officer)

By						/s/ Melissa K. Caen
						(Melissa K. Caen, Attorney-in-fact)

Date: July 30, 2025

148

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GEORGIA POWER COMPANY

SIGNATURES


						GEORGIA POWER COMPANY

By						Kimberly S. Greene
						Chairman, President, and Chief Executive Officer
						(Principal Executive Officer)

By						Aaron P. Abramovitz
						Executive Vice President, Chief Financial Officer, and Treasurer
						(Principal Financial Officer)

By						/s/ Melissa K. Caen
						(Melissa K. Caen, Attorney-in-fact)

Date: July 30, 2025

149

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MISSISSIPPI POWER COMPANY

SIGNATURES


						MISSISSIPPI POWER COMPANY

By						Anthony L. Wilson
						Chairman and Chief Executive Officer
						(Principal Executive Officer)

By						Matthew P. Grice
						Vice President, Chief Financial Officer, and Treasurer
						(Principal Financial Officer)

By						/s/ Melissa K. Caen
						(Melissa K. Caen, Attorney-in-fact)

Date: July 30, 2025

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SOUTHERN POWER COMPANY

SIGNATURES


						SOUTHERN POWER COMPANY

By						Christopher Cummiskey
						Chairman and Chief Executive Officer
						(Principal Executive Officer)

By						Gary Kerr
						Senior Vice President, Chief Financial Officer, and Treasurer
						(Principal Financial Officer)

By						/s/ Melissa K. Caen
						(Melissa K. Caen, Attorney-in-fact)

Date: July 30, 2025

151

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SOUTHERN COMPANY GAS

SIGNATURES


						SOUTHERN COMPANY GAS

By						James Y. Kerr II
						Chairman, President, and Chief Executive Officer
						(Principal Executive Officer)

By						Grace A. Kolvereid
						Executive Vice President, Chief Financial Officer, and Treasurer
						(Principal Financial Officer)

By						/s/ Melissa K. Caen
						(Melissa K. Caen, Attorney-in-fact)

Date: July 30, 2025

152