10-Q

    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, 2022

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from           to            

Commission
File Number Registrant,
State of Incorporation,
Address and Telephone Number I.R.S. Employer
Identification No.

1-3526 The Southern Company 58-0690070

(A Delaware Corporation)

30 Ivan Allen Jr. Boulevard, N.W.

Atlanta, Georgia 30308

(404) 506-5000

1-3164 Alabama Power Company 63-0004250

(An Alabama Corporation)

600 North 18th Street

Birmingham, Alabama 35203

(205) 257-1000

1-6468 Georgia Power Company 58-0257110

(A Georgia Corporation)

241 Ralph McGill Boulevard, N.E.

Atlanta, Georgia 30308

(404) 506-6526

001-11229 Mississippi Power Company 64-0205820

(A Mississippi Corporation)

2992 West Beach Boulevard

Gulfport, Mississippi 39501

(228) 864-1211

001-37803 Southern Power Company 58-2598670

(A Delaware Corporation)

30 Ivan Allen Jr. Boulevard, N.W.

Atlanta, Georgia 30308

(404) 506-5000

1-14174 Southern Company Gas 58-2210952

(A Georgia Corporation)

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	2019 Series A Corporate Units	SOLN	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
Alabama Power Company	5.00% Series Class A Preferred Stock	ALP PR Q	NYSE
Georgia Power Company	Series 2017A 5.00% Junior Subordinated Notes due 2077	GPJA	NYSE
Southern Power Company	Series 2016A 1.000% Senior Notes due 2022	SO/22B	NYSE
Southern Power Company	Series 2016B 1.850% Senior Notes due 2026	SO/26A	NYSE

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes þ No ¨

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). Yes þ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Registrant	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer	Smaller Reporting Company	Emerging Growth Company
The Southern Company	X
Alabama Power Company			X
Georgia Power Company			X
Mississippi Power Company			X
Southern Power Company			X
Southern Company Gas			X

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No þ (Response applicable to all registrants.)

Registrant	Description of Common Stock	Shares Outstanding at June 30, 2022
The Southern Company	Par Value $5 Per Share	1,063,001,320
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	96
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	149
Item 4.	Controls and Procedures	149
	PART II—OTHER INFORMATION
Item 1.	Legal Proceedings	150
Item 1A.	Risk Factors	150
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	Inapplicable
Item 6.	Exhibits	150
	Signatures	153

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DEFINITIONS

Term	Meaning
2019 ARP	Alternate Rate Plan approved by the Georgia PSC in 2019 for Georgia Power for the years 2020 through 2022
AFUDC	Allowance for funds used during construction
Alabama Power	Alabama Power Company
Amended and Restated Loan Guarantee Agreement	Loan guarantee agreement entered into by Georgia Power with the DOE in 2014, as amended and restated in March 2019, under which the proceeds of borrowings may be used to reimburse Georgia Power for Eligible Project Costs incurred in connection with its construction of Plant Vogtle Units 3 and 4
ARO	Asset retirement obligation
Atlanta Gas Light	Atlanta Gas Light Company, a wholly-owned subsidiary of Southern Company Gas
Bechtel	Bechtel Power Corporation, the primary contractor for the remaining construction activities for Plant Vogtle Units 3 and 4
Bechtel Agreement	The 2017 construction completion agreement between the Vogtle Owners and Bechtel
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
COD	Commercial operation date
Contractor Settlement Agreement	The December 31, 2015 agreement between Westinghouse and the Vogtle Owners resolving disputes between the Vogtle Owners and the EPC Contractor under the Vogtle 3 and 4 Agreement
COVID-19	The novel coronavirus disease declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention in March 2020
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
Eligible Project Costs	Certain costs of construction relating to Plant Vogtle Units 3 and 4 that are eligible for financing under the loan guarantee program established under Title XVII of the Energy Policy Act of 2005
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
FERC	Federal Energy Regulatory Commission
FFB	Federal Financing Bank
Fitch	Fitch Ratings, Inc.
Form 10-K	Annual Report on Form 10-K of Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas for the year ended December 31, 2021, as applicable
GAAP	U.S. generally accepted accounting principles
Georgia Power	Georgia Power Company
GRAM	Atlanta Gas Light's Georgia Rate Adjustment Mechanism
Guarantee Settlement Agreement	The June 9, 2017 settlement agreement between the Vogtle Owners and Toshiba related to certain payment obligations of the EPC Contractor guaranteed by Toshiba
Gulf Power	Gulf Power Company, until January 1, 2019 a wholly-owned subsidiary of Southern Company; effective January 1, 2021, Gulf Power Company merged with and into Florida Power and Light Company, with Florida Power and Light Company remaining as the surviving company

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DEFINITIONS

(continued)

Term	Meaning
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
IRP	Integrated resource plan
ITAAC	Inspections, Tests, Analyses, and Acceptance Criteria, standards established by the NRC
ITC	Investment tax credit
JEA	Jacksonville Electric Authority
KWH	Kilowatt-hour
LIBOR	London Interbank Offered Rate
LIFO	Last-in, first-out
LOCOM	Lower of weighted average cost or current market price
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
NYMEX	New York Mercantile Exchange, Inc.
OCI	Other comprehensive income
OPC	Oglethorpe Power Corporation (an electric membership corporation)
PennEast Pipeline	PennEast Pipeline Company, LLC, a joint venture in which Southern Company Gas has a 20% ownership interest
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, and Rate CNP PPA
Rate ECR	Alabama Power's Rate Energy Cost Recovery
Rate NDR	Alabama Power's Rate Natural Disaster Reserve
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

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DEFINITIONS

(continued)

Term	Meaning
ROE	Return on equity
S&P	S&P Global Ratings, a division of S&P Global Inc.
SCS	Southern Company Services, Inc., the Southern Company system service company and a wholly-owned subsidiary of Southern Company
SEC	U.S. Securities and Exchange Commission
SEGCO	Southern Electric Generating Company, 50% owned by each of Alabama Power and Georgia Power
Sequent	Sequent Energy Management, L.P. and Sequent Energy Canada Corp., wholly-owned subsidiaries of Southern Company Gas through June 30, 2021
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 100%-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 Communications Services, Inc., PowerSecure, and other subsidiaries
Southern Holdings	Southern Company Holdings, Inc., a wholly-owned subsidiary of Southern Company
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
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
VCM	Vogtle Construction Monitoring
VIE	Variable interest entity
Virginia Natural Gas	Virginia Natural Gas, Inc., a wholly-owned subsidiary of Southern Company Gas
Vogtle 3 and 4 Agreement	Agreement entered into with the EPC Contractor in 2008 by Georgia Power, acting for itself and as agent for the Vogtle Owners, and rejected in bankruptcy in July 2017, pursuant to which the EPC Contractor agreed to design, engineer, procure, construct, and test Plant Vogtle Units 3 and 4
Vogtle Owners	Georgia Power, OPC, MEAG Power, and Dalton
Vogtle Services Agreement	The June 2017 services agreement between the Vogtle Owners and the EPC Contractor, as amended and restated in July 2017, for the EPC Contractor to transition construction management of Plant Vogtle Units 3 and 4 to Southern Nuclear and to provide ongoing design, engineering, and procurement services to Southern Nuclear
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 the potential and expected effects of the continued COVID-19 pandemic, regulated rates, the strategic goals for the business, customer and sales growth, economic conditions, cost recovery and other rate actions, projected equity ratios, 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 and regulations;

•the potential effects of the continued COVID-19 pandemic, including, but not limited to, those described in Item 1A "Risk Factors" of the Form 10-K;

•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, and operational interruptions to natural gas distribution and transmission activities;

•transmission constraints;

•effects of inflation;

•the ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of facilities or other projects, including Plant Vogtle Units 3 and 4 (which includes components based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale) and Plant Barry Unit 8, due to current and/or future challenges which include, but are not limited to, changes in labor costs, availability, and productivity; challenges with 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; 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, including, for nuclear units, inspections and the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related investigations, reviews, and approvals by the NRC necessary to support NRC authorization to load fuel; challenges with start-up activities, including major equipment failure, or system integration; and/or operational performance; and challenges related to the COVID-19 pandemic;

•the ability to overcome or mitigate the current challenges at Plant Vogtle Units 3 and 4, as described in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" in Item 1 herein, that could further impact the cost and schedule for the project;

•legal proceedings and regulatory approvals and actions related to construction projects, such as Plant Vogtle Units 3 and 4 and Plant Barry Unit 8, including PSC approvals and FERC and NRC actions;

•under certain specified circumstances, a decision by holders of more than 10% of the ownership interests of Plant Vogtle Units 3 and 4 not to proceed with construction;

•the ability of other Vogtle Owners to tender a portion of their ownership interests to Georgia Power following certain construction cost increases, including the purported exercises by OPC and Dalton of their tender options and related litigation initiated by OPC and MEAG Power;

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

(continued)

•in the event Georgia Power becomes obligated to provide funding to MEAG Power with respect to the portion of MEAG Power's ownership interest in Plant Vogtle Units 3 and 4 involving JEA, any inability of Georgia Power to receive repayment of such funding;

•the ability to construct facilities in accordance with the requirements of permits and licenses (including satisfaction of NRC requirements), 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 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 fuel and other cost recovery mechanisms;

•the ability to successfully operate the traditional electric operating companies' and SEGCO's generation, transmission, and distribution facilities, Southern Power's generation facilities, and Southern Company Gas' natural gas distribution and storage facilities and the successful performance of necessary corporate functions;

•the inherent risks involved in operating and constructing nuclear generating facilities;

•the inherent risks involved in transporting and storing natural gas;

•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, 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 physical attacks;

•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 replacement of LIBOR with an alternative reference rate;

•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	17
Condensed Statements of Comprehensive Income	17
Condensed Statements of Cash Flows	18
Condensed Balance Sheets	19
Condensed Statements of Common Stockholder's Equity	21
Georgia Power Company:
Condensed Statements of Income	22
Condensed Statements of Comprehensive Income	22
Condensed Statements of Cash Flows	23
Condensed Balance Sheets	24
Condensed Statements of Common Stockholder's Equity	26
Mississippi Power Company:
Condensed Statements of Income	27
Condensed Statements of Comprehensive Income	27
Condensed Statements of Cash Flows	28
Condensed Balance Sheets	29
Condensed Statements of Common Stockholder's Equity	31
Southern Power Company and Subsidiary Companies:
Condensed Consolidated Statements of Income	32
Condensed Consolidated Statements of Comprehensive Income	32
Condensed Consolidated Statements of Cash Flows	33
Condensed Consolidated Balance Sheets	34
Condensed Consolidated Statements of Stockholders' Equity	36
Southern Company Gas and Subsidiary Companies:
Condensed Consolidated Statements of Income	37
Condensed Consolidated Statements of Comprehensive Income	37
Condensed Consolidated Statements of Cash Flows	38
Condensed Consolidated Balance Sheets	39
Condensed Consolidated Statements of Stockholder's Equity	41
Combined Notes to the Condensed Financial Statements	42

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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,
	2022		2021		2022		2021
	(in millions)				(in millions)
Operating Revenues:
Retail electric revenues	$	4,789	$	3,599	$	8,402	$	6,941
Wholesale electric revenues	937		546		1,601		1,091
Other electric revenues	192		175		370		346
Natural gas revenues (includes alternative revenue programs of     $2, $2, $1, and $4, respectively)	1,083		677		3,140		2,371
Other revenues	205		201		341		359
Total operating revenues	7,206		5,198		13,854		11,108
Operating Expenses:
Fuel	1,715		848		2,826		1,696
Purchased power	408		217		640		424
Cost of natural gas	452		231		1,546		814
Cost of other sales	114		103		183		185
Other operations and maintenance	1,558		1,438		3,075		2,810
Depreciation and amortization	913		891		1,805		1,762
Taxes other than income taxes	349		313		721		657
Estimated loss on Plant Vogtle Units 3 and 4	52		460		52		508
Gain on dispositions, net	(10)		(11)		(33)		(54)
Total operating expenses	5,551		4,490		10,815		8,802
Operating Income	1,655		708		3,039		2,306
Other Income and (Expense):
Allowance for equity funds used during construction	53		45		104		90
Earnings (loss) from equity method investments	34		(40)		80		5
Interest expense, net of amounts capitalized	(488)		(450)		(950)		(901)
Other income (expense), net	139		101		283		160
Total other income and (expense)	(262)		(344)		(483)		(646)
Earnings Before Income Taxes	1,393		364		2,556		1,660
Income taxes (benefit)	304		(12)		477		178
Consolidated Net Income	1,089		376		2,079		1,482
Dividends on preferred stock of subsidiaries	4		4		7		7
Net loss attributable to noncontrolling interests	(22)		—		(67)		(33)
Consolidated Net Income Attributable to    Southern Company	$	1,107	$	372	$	2,139	$	1,508
Common Stock Data:
Earnings per share -
Basic	$	1.04	$	0.35	$	2.01	$	1.42
Diluted	$	1.03	$	0.35	$	2.00	$	1.41
Average number of shares of common stock outstanding (in millions)
Basic	1,065		1,061		1,064		1,060
Diluted	1,072		1,067		1,070		1,066

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,
	2022		2021		2022		2021
	(in millions)				(in millions)
Consolidated Net Income	$	1,089	$	376	$	2,079	$	1,482
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of     $(15), $5, $(7), and $(5), respectively	(45)		14		(26)		(16)
Reclassification adjustment for amounts included in net income,    net of tax of $17, $(1), $24, and $17, respectively	54		(5)		74		50
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income,    net of tax of $1, $2, $2, and $3, respectively	2		3		5		6
Total other comprehensive income	11		12		53		40
Comprehensive Income	1,100		388		2,132		1,522
Dividends on preferred stock of subsidiaries	4		4		7		7
Comprehensive loss attributable to noncontrolling interests	(22)		—		(67)		(33)
Consolidated Comprehensive Income Attributable to    Southern Company	$	1,118	$	384	$	2,192	$	1,548

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,
	2022		2021
	(in millions)
Operating Activities:
Consolidated net income	$	2,079	$	1,482
Adjustments to reconcile consolidated net income to net cash provided from operating activities —
Depreciation and amortization, total	1,995		1,949
Deferred income taxes	240		(101)
Utilization of federal investment tax credits	281		224
Allowance for equity funds used during construction	(104)		(90)
Mark-to-market adjustments	14		136
Pension, postretirement, and other employee benefits	(211)		(115)
Settlement of asset retirement obligations	(198)		(228)
Stock based compensation expense	100		105
Estimated loss on Plant Vogtle Units 3 and 4	52		508
Storm damage accruals	107		112
Natural gas cost under recovery – long-term	192		(119)
Retail fuel cost under recovery – long-term	(729)		—
Other, net	21		117
Changes in certain current assets and liabilities —
-Receivables	(637)		29
-Prepayments	(90)		(79)
-Materials and supplies	(109)		(57)
-Natural gas for sale, net of temporary LIFO liquidation	335		375
-Natural gas cost under recovery	(94)		(485)
-Other current assets	12		94
-Accounts payable	703		(177)
-Accrued taxes	(150)		(157)
-Accrued compensation	(260)		(238)
-Retail fuel cost over recovery	—		(146)
-Other current liabilities	30		(235)
Net cash provided from operating activities	3,579		2,904
Investing Activities:
Business acquisitions, net of cash acquired	—		(345)
Property additions	(3,213)		(3,384)
Nuclear decommissioning trust fund purchases	(628)		(930)
Nuclear decommissioning trust fund sales	624		926
Proceeds from dispositions	119		25
Cost of removal, net of salvage	(377)		(184)
Payments pursuant to LTSAs	(81)		(114)
Other investing activities	96		(20)
Net cash used for investing activities	(3,460)		(4,026)
Financing Activities:
Increase in notes payable, net	263		492
Proceeds —
Long-term debt	2,200		4,646
Short-term borrowings	1,200		325
Common stock	61		24
Redemptions and repurchases —
Long-term debt	(1,851)		(2,477)
Short-term borrowings	(400)		(25)
Capital contributions from noncontrolling interests	73		343
Distributions to noncontrolling interests	(115)		(113)
Payment of common stock dividends	(1,425)		(1,377)
Other financing activities	(219)		(167)
Net cash provided from (used for) financing activities	(213)		1,671
Net Change in Cash, Cash Equivalents, and Restricted Cash	(94)		549
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829		1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	1,735	$	1,617
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $46 and $43 capitalized for 2022 and 2021, respectively)	$	836	$	884
Income taxes, net	157		88
Noncash transactions —
Accrued property additions at end of period	837		943
Contributions from noncontrolling interests	—		89
Contributions of wind turbine equipment	—		82
Right-of-use assets obtained under leases	15		90
Reassessment of right-of-use assets under operating leases	40		—

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

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    Table of Contents                                Index to Financial Statements

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At June 30, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	1,724	$	1,798
Receivables —
Customer accounts	2,277		1,806
Unbilled revenues	807		711
Other accounts and notes	534		523
Accumulated provision for uncollectible accounts	(94)		(78)
Materials and supplies	1,641		1,543
Fossil fuel for generation	431		450
Natural gas for sale	209		362
Prepaid expenses	528		330
Assets from risk management activities, net of collateral	247		151
Regulatory assets – asset retirement obligations	263		219
Natural gas cost under recovery	361		266
Other regulatory assets	641		653
Other current assets	212		231
Total current assets	9,781		8,965
Property, Plant, and Equipment:
In service	117,418		115,592
Less: Accumulated depreciation	35,203		34,079
Plant in service, net of depreciation	82,215		81,513
Nuclear fuel, at amortized cost	837		824
Construction work in progress	9,770		8,771
Total property, plant, and equipment	92,822		91,108
Other Property and Investments:
Goodwill	5,280		5,280
Nuclear decommissioning trusts, at fair value	2,150		2,542
Equity investments in unconsolidated subsidiaries	1,305		1,282
Other intangible assets, net of amortization of $326 and $307, respectively	425		445
Miscellaneous property and investments	576		653
Total other property and investments	9,736		10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,623		1,701
Deferred charges related to income taxes	843		824
Prepaid pension costs	1,893		1,657
Unamortized loss on reacquired debt	248		258
Regulatory assets – asset retirement obligations, deferred	5,982		5,466
Other regulatory assets, deferred	5,448		5,577
Other deferred charges and assets	2,393		1,776
Total deferred charges and other assets	18,430		17,259
Total Assets	$	130,769	$	127,534

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)

Liabilities and Stockholders' Equity	At June 30, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	1,052	$	2,157
Notes payable	2,510		1,440
Accounts payable	2,908		2,169
Customer deposits	461		479
Accrued taxes —
Accrued income taxes	17		50
Other accrued taxes	635		641
Accrued interest	553		533
Accrued compensation	807		1,070
Asset retirement obligations	693		697
Operating lease obligations	232		250
Other regulatory liabilities	557		563
Other current liabilities	1,062		872
Total current liabilities	11,487		10,921
Long-term Debt	51,204		50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,620		8,862
Deferred credits related to income taxes	5,318		5,401
Accumulated deferred ITCs	2,175		2,216
Employee benefit obligations	1,509		1,550
Operating lease obligations, deferred	1,464		1,503
Asset retirement obligations, deferred	11,010		10,990
Other cost of removal obligations	1,993		2,103
Other regulatory liabilities, deferred	536		485
Other deferred credits and liabilities	1,198		816
Total deferred credits and other liabilities	34,823		33,926
Total Liabilities	97,514		94,967
Redeemable Preferred Stock of Subsidiaries	242		291
Total Stockholders' Equity (See accompanying statements)	33,013		32,276
Total Liabilities and Stockholders' Equity	$	130,769	$	127,534

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

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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, 2020	1,058	(1)	$	5,268	$	11,834	$	(46)	$	11,311	$	(395)	$	4,262	$	32,234
Consolidated net income (loss)	—	—	—		—		—		1,135		—		(32)		1,103
Other comprehensive income	—	—	—		—		—		—		28		—		28
Stock issued	2	—	5		9		—		—		—		—		14
Stock-based compensation	—	—	—		9		—		—		—		—		9
Cash dividends of $0.64 per share	—	—	—		—		—		(678)		—		—		(678)
Capital contributions from    noncontrolling interests	—	—	—		—		—		—		—		403		403
Distributions to noncontrolling interests	—	—	—		—		—		—		—		(46)		(46)
Other	—	—	—		2		—		—		—		(1)		1
Balance at March 31, 2021	1,060	(1)	5,273		11,854		(46)		11,768		(367)		4,586		33,068
Consolidated net income	—	—	—		—		—		372		—		—		372
Other comprehensive income	—	—	—		—		—		—		12		—		12
Stock issued	—	—	1		9		—		—		—		—		10
Stock-based compensation	—	—	—		22		—		—		—		—		22
Cash dividends of $0.66 per share	—	—	—		—		—		(699)		—		—		(699)
Capital contributions from    noncontrolling interests	—	—	—		—		—		—		—		29		29
Distributions to noncontrolling interests	—	—	—		—		—		—		—		(68)		(68)
Other	—	—	—		1		(2)		1		—		—		—
Balance at June 30, 2021	1,060	(1)	$	5,274	$	11,886	$	(48)	$	11,442	$	(355)	$	4,547	$	32,746

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    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, 2021	1,061	(1)	$	5,279	$	11,950	$	(47)	$	10,929	$	(237)	$	4,402	$	32,276
Consolidated net income (loss)	—	—	—		—		—		1,032		—		(45)		987
Other comprehensive income	—	—	—		—		—		—		42		—		42
Stock issued	3	—	7		31		—		—		—		—		38
Stock-based compensation	—	—	—		6		—		—		—		—		6
Cash dividends of $0.66 per share	—	—	—		—		—		(702)		—		—		(702)
Capital contributions from    noncontrolling interests	—	—	—		—		—		—		—		73		73
Distributions to noncontrolling interests	—	—	—		—		—		—		—		(98)		(98)
Other	—	—	—		7		(2)		2		—		—		7
Balance at March 31, 2022	1,064	(1)	5,286		11,994		(49)		11,261		(195)		4,332		32,629
Consolidated net income (loss)	—	—	—		—		—		1,107		—		(22)		1,085
Other comprehensive income	—	—	—		—		—		—		11		—		11
Stock issued	—	—	2		21		—		—		—		—		23
Stock-based compensation	—	—	—		14		—		—		—		—		14
Cash dividends of $0.68 per share	—	—	—		—		—		(723)		—		—		(723)
Distributions to noncontrolling interests	—	—	—		—		—		—		—		(28)		(28)
Other	—	—	—		4		(2)		—		—		—		2
Balance at June 30, 2022	1,064	(1)	$	5,288	$	12,033	$	(51)	$	11,645	$	(184)	$	4,282	$	33,013

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

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ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Operating Revenues:
Retail revenues	$	1,629	$	1,354	$	3,008	$	2,706
Wholesale revenues, non-affiliates	159		85		272		178
Wholesale revenues, affiliates	34		24		100		55
Other revenues	109		93		200		176
Total operating revenues	1,931		1,556		3,580		3,115
Operating Expenses:
Fuel	401		263		733		554
Purchased power, non-affiliates	95		48		162		97
Purchased power, affiliates	121		39		147		69
Other operations and maintenance	441		413		852		775
Depreciation and amortization	218		214		432		425
Taxes other than income taxes	100		101		204		203
Total operating expenses	1,376		1,078		2,530		2,123
Operating Income	555		478		1,050		992
Other Income and (Expense):
Allowance for equity funds used during construction	17		12		33		24
Interest expense, net of amounts capitalized	(91)		(84)		(180)		(168)
Other income (expense), net	27		33		61		62
Total other income and (expense)	(47)		(39)		(86)		(82)
Earnings Before Income Taxes	508		439		964		910
Income taxes	121		104		227		213
Net Income	387		335		737		697
Dividends on Preferred Stock	4		4		7		7
Net Income After Dividends on Preferred Stock	$	383	$	331	$	730	$	690

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Net Income	$	387	$	335	$	737	$	697
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of     $—, $—, $(1), and $—, respectively	—		—		(1)		—
Reclassification adjustment for amounts included in net income,    net of tax of $—, $—, $1, and $1, respectively	1		1		2		2
Total other comprehensive income	1		1		1		2
Comprehensive Income	$	388	$	336	$	738	$	699

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

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ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Six Months Ended June 30,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	737	$	697
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	494		496
Deferred income taxes	117		87
Pension, postretirement, and other employee benefits	(59)		(39)
Settlement of asset retirement obligations	(91)		(104)
Retail fuel cost under recovery – long-term	(191)		—
Other, net	(67)		(35)
Changes in certain current assets and liabilities —
-Receivables	(296)		(85)
-Prepayments	(69)		(53)
-Other current assets	(33)		(23)
-Accounts payable	14		(236)
-Accrued compensation	(55)		(60)
-Other current liabilities	9		(61)
Net cash provided from operating activities	510		584
Investing Activities:
Property additions	(759)		(844)
Nuclear decommissioning trust fund purchases	(180)		(473)
Nuclear decommissioning trust fund sales	180		473
Cost of removal, net of salvage	(104)		(56)
Change in construction payables	(8)		25
Other investing activities	(18)		(18)
Net cash used for investing activities	(889)		(893)
Financing Activities:
Proceeds — Senior notes	700		600
Redemptions — Senior notes	(550)		(200)
Capital contributions from parent company	656		624
Payment of common stock dividends	(508)		(492)
Other financing activities	(71)		(26)
Net cash provided from financing activities	227		506
Net Change in Cash, Cash Equivalents, and Restricted Cash	(152)		197
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,060		530
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	908	$	727
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $9 and $7 capitalized for 2022 and 2021, respectively)	$	166	$	154
Income taxes, net	192		171
Noncash transactions —
Accrued property additions at end of period	141		191
Right-of-use assets obtained under leases	6		2

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

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    Table of Contents                                Index to Financial Statements

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At June 30, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	908	$	1,060
Receivables —
Customer accounts	501		410
Unbilled revenues	189		138
Affiliated	85		37
Other accounts and notes	101		55
Accumulated provision for uncollectible accounts	(14)		(14)
Fossil fuel stock	161		159
Materials and supplies	568		548
Prepaid expenses	147		41
Other regulatory assets	263		208
Other current assets	113		67
Total current assets	3,022		2,709
Property, Plant, and Equipment:
In service	33,596		33,135
Less: Accumulated provision for depreciation	10,589		10,313
Plant in service, net of depreciation	23,007		22,822
Nuclear fuel, at amortized cost	251		247
Construction work in progress	1,319		1,147
Total property, plant, and equipment	24,577		24,216
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,124		1,325
Equity investments in unconsolidated subsidiaries	56		57
Miscellaneous property and investments	128		126
Total other property and investments	1,308		1,508
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	89		108
Deferred charges related to income taxes	246		240
Prepaid pension and other postretirement benefit costs	568		513
Regulatory assets – asset retirement obligations	1,845		1,547
Other regulatory assets, deferred	1,860		1,807
Other deferred charges and assets	395		334
Total deferred charges and other assets	5,003		4,549
Total Assets	$	33,910	$	32,982

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

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    Table of Contents                                Index to Financial Statements

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At June 30, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	201	$	751
Accounts payable —
Affiliated	414		309
Other	351		459
Customer deposits	107		106
Accrued taxes	128		98
Accrued interest	109		100
Accrued compensation	174		219
Asset retirement obligations	325		320
Other regulatory liabilities	133		215
Other current liabilities	121		125
Total current liabilities	2,063		2,702
Long-term Debt	9,633		8,936
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,719		3,573
Deferred credits related to income taxes	1,944		1,968
Accumulated deferred ITCs	84		88
Employee benefit obligations	176		171
Operating lease obligations	66		66
Asset retirement obligations, deferred	3,998		4,014
Other cost of removal obligations	106		192
Other regulatory liabilities, deferred	227		210
Other deferred credits and liabilities	58		58
Total deferred credits and other liabilities	10,378		10,340
Total Liabilities	22,074		21,978
Redeemable Preferred Stock	242		291
Common Stockholder's Equity (See accompanying statements)	11,594		10,713
Total Liabilities and Stockholder's Equity	$	33,910	$	32,982

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

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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, 2020	31	$	1,222	$	5,413	$	3,194	$	(19)	$	9,810
Net income after dividends on    preferred stock	—	—		—		359		—		359
Capital contributions from parent company	—	—		602		—		—		602
Other comprehensive income	—	—		—		—		1		1
Cash dividends on common stock	—	—		—		(246)		—		(246)
Balance at March 31, 2021	31	1,222		6,015		3,307		(18)		10,526
Net income after dividends on    preferred stock	—	—		—		331		—		331
Capital contributions from parent company	—	—		26		—		—		26
Other comprehensive income	—	—		—		—		1		1
Cash dividends on common stock	—	—		—		(246)		—		(246)
Other	—	—		—		(1)		—		(1)
Balance at June 30, 2021	31	$	1,222	$	6,041	$	3,391	$	(17)	$	10,637
Balance at December 31, 2021	31	$	1,222	$	6,056	$	3,448	$	(13)	$	10,713
Net income after dividends on    preferred stock	—	—		—		347		—		347
Capital contributions from parent company	—	—		626		—		—		626
Cash dividends on common stock	—	—		—		(254)		—		(254)
Balance at March 31, 2022	31	1,222		6,682		3,541		(13)		11,432
Net income after dividends on    preferred stock	—	—		—		383		—		383
Capital contributions from parent company	—	—		32		—		—		32
Other comprehensive income	—	—		—		—		1		1
Cash dividends on common stock	—	—		—		(254)		—		(254)
Balance at June 30, 2022	31	$	1,222	$	6,714	$	3,670	$	(12)	$	11,594

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

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GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Operating Revenues:
Retail revenues	$	2,908	$	2,026	$	4,926	$	3,813
Wholesale revenues	64		36		130		80
Other revenues	149		163		272		302
Total operating revenues	3,121		2,225		5,328		4,195
Operating Expenses:
Fuel	628		343		1,046		656
Purchased power, non-affiliates	246		144		396		288
Purchased power, affiliates	323		149		529		285
Other operations and maintenance	573		542		1,091		1,015
Depreciation and amortization	356		342		706		680
Taxes other than income taxes	141		118		265		235
Estimated loss on Plant Vogtle Units 3 and 4	52		460		52		508
Total operating expenses	2,319		2,098		4,085		3,667
Operating Income	802		127		1,243		528
Other Income and (Expense):
Allowance for equity funds used during construction	33		30		65		61
Interest expense, net of amounts capitalized	(117)		(106)		(224)		(210)
Other income (expense), net	54		42		103		83
Total other income and (expense)	(30)		(34)		(56)		(66)
Earnings Before Income Taxes	772		93		1,187		462
Income taxes (benefit)	164		(50)		194		(32)
Net Income	$	608	$	143	$	993	$	494

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Net Income	$	608	$	143	$	993	$	494
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of     $4, $—, $8, and $—, respectively	15		—		23		—
Reclassification adjustment for amounts included in net income,    net of tax of $—, $1, $1, and $1, respectively	1		1		3		3
Total other comprehensive income	16		1		26		3
Comprehensive Income	$	624	$	144	$	1,019	$	497

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

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GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Six Months Ended June 30,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	993	$	494
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	803		772
Deferred income taxes	72		(309)
Allowance for equity funds used during construction	(65)		(61)
Pension, postretirement, and other employee benefits	(114)		(59)
Settlement of asset retirement obligations	(91)		(100)
Storm damage accruals	107		107
Retail fuel cost under recovery – long-term	(538)		—
Estimated loss on Plant Vogtle Units 3 and 4	52		508
Other, net	7		90
Changes in certain current assets and liabilities —
-Receivables	(424)		(73)
-Fossil fuel stock	31		55
-Materials and supplies	(46)		(46)
-Other current assets	(25)		15
-Accounts payable	235		83
-Accrued compensation	(50)		(39)
-Retail fuel cost over recovery	—		(113)
-Other current liabilities	(21)		(11)
Net cash provided from operating activities	926		1,313
Investing Activities:
Property additions	(1,654)		(1,575)
Nuclear decommissioning trust fund purchases	(448)		(458)
Nuclear decommissioning trust fund sales	444		453
Cost of removal, net of salvage	(207)		(73)
Change in construction payables, net of joint owner portion	51		(72)
Contributions in aid of construction	109		45
Proceeds from dispositions	56		3
Other investing activities	(19)		(53)
Net cash used for investing activities	(1,668)		(1,730)
Financing Activities:
Increase in notes payable, net	—		250
Proceeds —
Senior notes	1,500		750
FFB loan	—		371
Short-term borrowings	650		—
Redemptions and repurchases —
Senior notes	(400)		(325)
Pollution control revenue bonds	—		(69)
FFB loan	(45)		(45)
Short-term borrowings	(250)		—
Other long-term debt	(125)		—
Capital contributions from parent company	491		368
Payment of common stock dividends	(845)		(824)
Other financing activities	(37)		(19)
Net cash provided from financing activities	939		457
Net Change in Cash, Cash Equivalents, and Restricted Cash	197		40
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	33		9
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	230	$	49
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $33 and $30 capitalized for 2022 and 2021, respectively)	$	188	$	182
Income taxes, net	106		139
Noncash transactions —
Accrued property additions at end of period	500		476
Right-of-use assets obtained under operating leases	1		3

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

23

    Table of Contents                                Index to Financial Statements

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At June 30, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	230	$	33
Receivables —
Customer accounts, net	830		547
Unbilled revenues	450		231
Joint owner accounts	44		116
Affiliated	54		25
Other accounts and notes	33		44
Fossil fuel stock	218		248
Materials and supplies	712		670
Regulatory assets – asset retirement obligations	222		178
Assets from risk management activities	94		48
Other regulatory assets	244		289
Other current assets	124		130
Total current assets	3,255		2,559
Property, Plant, and Equipment:
In service	42,067		41,332
Less: Accumulated provision for depreciation	13,233		12,854
Plant in service, net of depreciation	28,834		28,478
Nuclear fuel, at amortized cost	586		577
Construction work in progress	7,420		6,688
Total property, plant, and equipment	36,840		35,743
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,025		1,217
Equity investments in unconsolidated subsidiaries	51		50
Miscellaneous property and investments	75		69
Total other property and investments	1,151		1,336
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,083		1,157
Deferred charges related to income taxes	564		550
Prepaid pension costs	652		563
Deferred under recovered fuel clause revenues	948		410
Regulatory assets – asset retirement obligations, deferred	3,896		3,688
Other regulatory assets, deferred	2,073		1,964
Other deferred charges and assets	512		491
Total deferred charges and other assets	9,728		8,823
Total Assets	$	50,974	$	48,461

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

24

    Table of Contents                                Index to Financial Statements

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At June 30, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	248	$	675
Notes payable	400		—
Accounts payable —
Affiliated	863		757
Other	892		702
Customer deposits	255		259
Accrued taxes	322		335
Accrued interest	150		136
Accrued compensation	174		232
Operating lease obligations	157		156
Asset retirement obligations	312		317
Other regulatory liabilities	260		280
Other current liabilities	258		254
Total current liabilities	4,291		4,103
Long-term Debt	14,450		13,109
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,318		3,019
Deferred credits related to income taxes	2,283		2,321
Accumulated deferred ITCs	323		328
Employee benefit obligations	384		402
Operating lease obligations, deferred	950		999
Asset retirement obligations, deferred	6,537		6,507
Other deferred credits and liabilities	541		439
Total deferred credits and other liabilities	14,336		14,015
Total Liabilities	33,077		31,227
Common Stockholder's Equity (See accompanying statements)	17,897		17,234
Total Liabilities and Stockholder's Equity	$	50,974	$	48,461

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

25

    Table of Contents                                Index to Financial Statements

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, 2020	9	$	398	$	12,361	$	3,789	$	(47)	$	16,501
Net income	—	—		—		351		—		351
Capital contributions from parent company	—	—		332		—		—		332
Other comprehensive income	—	—		—		—		2		2
Cash dividends on common stock	—	—		—		(412)		—		(412)
Balance at March 31, 2021	9	398		12,693		3,728		(45)		16,774
Net income	—	—		—		143		—		143
Capital contributions from parent company	—	—		40		—		—		40
Other comprehensive income	—	—		—		—		1		1
Cash dividends on common stock	—	—		—		(412)		—		(412)
Balance at June 30, 2021	9	$	398	$	12,733	$	3,459	$	(44)	$	16,546
Balance at December 31, 2021	9	$	398	$	14,153	$	2,724	$	(41)	$	17,234
Net income	—	—		—		385		—		385
Capital contributions from parent company	—	—		443		—		—		443
Other comprehensive income	—	—		—		—		10		10
Cash dividends on common stock	—	—		—		(423)		—		(423)
Balance at March 31, 2022	9	398		14,596		2,686		(31)		17,649
Net income	—	—		—		608		—		608
Capital contributions from parent company	—	—		46		—		—		46
Other comprehensive income	—	—		—		—		16		16
Cash dividends on common stock	—	—		—		(422)		—		(422)
Balance at June 30, 2022	9	$	398	$	14,642	$	2,872	$	(15)	$	17,897

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

26

    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,
	2022		2021		2022		2021
	(in millions)				(in millions)
Operating Revenues:
Retail revenues	$	252	$	219	$	469	$	422
Wholesale revenues, non-affiliates	63		54		131		117
Wholesale revenues, affiliates	107		25		149		57
Other revenues	12		5		20		14
Total operating revenues	434		303		769		610
Operating Expenses:
Fuel and purchased power	207		102		339		208
Other operations and maintenance	91		76		167		144
Depreciation and amortization	45		44		90		91
Taxes other than income taxes	32		32		61		63
Total operating expenses	375		254		657		506
Operating Income	59		49		112		104
Other Income and (Expense):
Interest expense, net of amounts capitalized	(14)		(14)		(27)		(29)
Other income (expense), net	12		11		22		20
Total other income and (expense)	(2)		(3)		(5)		(9)
Earnings Before Income Taxes	57		46		107		95
Income taxes	12		8		20		12
Net Income	$	45	$	38	$	87	$	83

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Net Income	$	45	$	38	$	87	$	83
Other comprehensive income:
Qualifying hedges:
Reclassification adjustment for amounts included in net income,    net of tax of $—, $—, $—, and $—, respectively	—		—		—		1
Total other comprehensive income	—		—		—		1
Comprehensive Income	$	45	$	38	$	87	$	84

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

27

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Six Months Ended June 30,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	87	$	83
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	110		106
Other, net	13		(28)
Changes in certain current assets and liabilities —
-Receivables	(92)		1
-Retail fuel cost under recovery	(25)		—
-Other current assets	(23)		(4)
-Accounts payable	79		(33)
-Accrued taxes	(36)		(51)
-Retail fuel cost over recovery	—		(15)
-Other current liabilities	(1)		(18)
Net cash provided from operating activities	112		41
Investing Activities:
Property additions	(87)		(90)
Construction payables	(16)		(3)
Payments pursuant to LTSAs	(15)		(14)
Other investing activities	(15)		(10)
Net cash used for investing activities	(133)		(117)
Financing Activities:
Increase (decrease) in notes payable, net	16		(25)
Proceeds — Senior notes	—		525
Capital contributions from parent company	51		101
Payment of common stock dividends	(85)		(79)
Other financing activities	—		(7)
Net cash provided from (used for) financing activities	(18)		515
Net Change in Cash, Cash Equivalents, and Restricted Cash	(39)		439
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	61		39
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	22	$	478
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest	$	26	$	31
Income taxes, net	5		7
Noncash transactions — Accrued property additions at end of period	9		31

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

28

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At June 30, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	22	$	61
Receivables —
Customer accounts, net	89		37
Unbilled revenues	44		34
Affiliated	76		29
Other accounts and notes	37		28
Fossil fuel stock	33		28
Materials and supplies	76		70
Assets from risk management activities	62		28
Other regulatory assets	62		54
Other current assets	15		13
Total current assets	516		382
Property, Plant, and Equipment:
In service	5,197		5,106
Less: Accumulated provision for depreciation	1,648		1,591
Plant in service, net of depreciation	3,549		3,515
Construction work in progress	127		127
Total property, plant, and equipment	3,676		3,642
Other Property and Investments	175		179
Deferred Charges and Other Assets:
Deferred charges related to income taxes	30		31
Prepaid pension costs	91		79
Regulatory assets – asset retirement obligations	236		232
Other regulatory assets, deferred	286		317
Accumulated deferred income taxes	112		118
Other deferred charges and assets	129		100
Total deferred charges and other assets	884		877
Total Assets	$	5,251	$	5,080

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

29

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At June 30, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	1	$	1
Notes payable	16		—
Accounts payable —
Affiliated	129		81
Other	62		47
Accrued taxes	83		120
Accrued compensation	28		36
Asset retirement obligations	24		30
Other regulatory liabilities	92		59
Other current liabilities	96		65
Total current liabilities	531		439
Long-term Debt	1,510		1,510
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	466		464
Deferred credits related to income taxes	265		269
Employee benefit obligations	88		88
Asset retirement obligations, deferred	162		160
Other cost of removal obligations	193		195
Other regulatory liabilities, deferred	91		64
Other deferred credits and liabilities	24		24
Total deferred credits and other liabilities	1,289		1,264
Total Liabilities	3,330		3,213
Common Stockholder's Equity (See accompanying statements)	1,921		1,867
Total Liabilities and Stockholder's Equity	$	5,251	$	5,080

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

30

    Table of Contents                                Index to Financial Statements

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, 2020	1	$	38	$	4,460	$	(2,754)	$	(2)	$	1,742
Net income	—	—		—		45		—		45
Capital contributions from parent company	—	—		100		—		—		100
Cash dividends on common stock	—	—		—		(39)		—		(39)
Balance at March 31, 2021	1	38		4,560		(2,748)		(2)		1,848
Net income	—	—		—		38		—		38
Capital contributions from parent company	—	—		2		—		—		2
Cash dividends on common stock	—	—		—		(39)		—		(39)
Other	—	—		—		(1)		1		—
Balance at June 30, 2021	1	$	38	$	4,562	$	(2,750)	$	(1)	$	1,849
Balance at December 31, 2021	1	$	38	$	4,582	$	(2,753)	$	—	$	1,867
Net income	—	—		—		42		—		42
Capital contributions from parent company	—	—		51		—		—		51
Cash dividends on common stock	—	—		—		(43)		—		(43)
Balance at March 31, 2022	1	38		4,633		(2,754)		—		1,917
Net income	—	—		—		45		—		45
Capital contributions from parent company	—	—		1		—		—		1
Cash dividends on common stock	—	—		—		(42)		—		(42)
Balance at June 30, 2022	1	$	38	$	4,634	$	(2,751)	$	—	$	1,921

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

31

    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,
	2022		2021		2022		2021
	(in millions)				(in millions)
Operating Revenues:
Wholesale revenues, non-affiliates	$	658	$	373	$	1,084	$	728
Wholesale revenues, affiliates	232		112		337		193
Other revenues	9		5		17		9
Total operating revenues	899		490		1,438		930
Operating Expenses:
Fuel	437		140		669		281
Purchased power	68		25		89		46
Other operations and maintenance	115		111		220		211
Depreciation and amortization	131		132		251		251
Taxes other than income taxes	12		12		25		24
Gain on dispositions, net	—		—		(2)		(39)
Total operating expenses	763		420		1,252		774
Operating Income	136		70		186		156
Other Income and (Expense):
Interest expense, net of amounts capitalized	(36)		(37)		(73)		(75)
Other income (expense), net	1		1		3		8
Total other income and (expense)	(35)		(36)		(70)		(67)
Earnings Before Income Taxes	101		34		116		89
Income taxes (benefit)	25		(2)		13		(11)
Net Income	76		36		103		100
Net loss attributable to noncontrolling interests	(22)		—		(67)		(33)
Net Income Attributable to Southern Power	$	98	$	36	$	170	$	133

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Net Income	$	76	$	36	$	103	$	100
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of     $(18), $2, $(23), and $(8), respectively	(54)		6		(72)		(26)
Reclassification adjustment for amounts included in net income,    net of tax of $19, $(3), $26, and $13, respectively	57		(9)		79		38
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income,    net of tax of $—, $1, $—, and $1, respectively	—		—		1		1
Total other comprehensive income (loss)	3		(3)		8		13
Comprehensive Income	79		33		111		113
Comprehensive loss attributable to noncontrolling interests	(22)		—		(67)		(33)
Comprehensive Income Attributable to Southern Power	$	101	$	33	$	178	$	146

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

32

    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Six Months Ended June 30,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	103	$	100
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	264		264
Deferred income taxes	14		(20)
Utilization of federal investment tax credits	239		205
Amortization of investment tax credits	(29)		(29)
Gain on dispositions, net	(2)		(39)
Other, net	(25)		(18)
Changes in certain current assets and liabilities —
-Receivables	(161)		(91)
-Prepaid income taxes	22		28
-Other current assets	(6)		2
-Accounts payable	114		14
-Accrued taxes	42		8
-Other current liabilities	(23)		(13)
Net cash provided from operating activities	552		411
Investing Activities:
Business acquisitions, net of cash acquired	—		(345)
Property additions	(34)		(224)
Proceeds from dispositions	48		17
Change in construction payables	(54)		(14)
Payments pursuant to LTSAs	(33)		(47)
Other investing activities	—		12
Net cash used for investing activities	(73)		(601)
Financing Activities:
Increase (decrease) in notes payable, net	94		(56)
Proceeds —
Senior notes	—		400
Capital contributions from parent company	326		4
Redemptions — Senior notes	(677)		—
Return of capital to parent company	—		(271)
Capital contributions from noncontrolling interests	73		343
Distributions to noncontrolling interests	(115)		(113)
Payment of common stock dividends	(99)		(102)
Other financing activities	(5)		(9)
Net cash provided from (used for) financing activities	(403)		196
Net Change in Cash, Cash Equivalents, and Restricted Cash	76		6
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	135		183
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	211	$	189
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $— and $2 capitalized for 2022 and 2021, respectively)	$	91	$	91
Income taxes, net	(263)		(189)
Noncash transactions —
Contributions from noncontrolling interests	—		89
Contributions of wind turbine equipment	—		82
Accrued property additions at end of period	28		59
Right-of-use assets obtained under operating leases	—		65
Reassessment of right-of-use assets under operating leases	40		—

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

33

    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At June 30, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	202	$	107
Receivables —
Customer accounts, net	278		139
Affiliated	83		51
Other	19		29
Materials and supplies	108		106
Prepaid income taxes	5		27
Other current assets	48		46
Total current assets	743		505
Property, Plant, and Equipment:
In service	14,637		14,585
Less: Accumulated provision for depreciation	3,462		3,241
Plant in service, net of depreciation	11,175		11,344
Construction work in progress	34		45
Total property, plant, and equipment	11,209		11,389
Other Property and Investments:
Intangible assets, net of amortization of $119 and $109, respectively	274		282
Equity investments in unconsolidated subsidiaries	49		86
Net investment in sales-type leases	156		161
Total other property and investments	479		529
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	493		479
Prepaid LTSAs	192		210
Other deferred charges and assets	286		278
Total deferred charges and other assets	971		967
Total Assets	$	13,402	$	13,390

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

34

    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholders' Equity	At June 30, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	—	$	679
Notes payable	306		211
Accounts payable —
Affiliated	192		92
Other	77		85
Accrued taxes	56		14
Accrued interest	24		32
Other current liabilities	89		140
Total current liabilities	744		1,253
Long-term Debt	2,964		3,009
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	471		215
Accumulated deferred ITCs	1,585		1,614
Operating lease obligations	514		497
Other deferred credits and liabilities	245		204
Total deferred credits and other liabilities	2,815		2,530
Total Liabilities	6,523		6,792
Total Stockholders' Equity (See accompanying statements)	6,879		6,598
Total Liabilities and Stockholders' Equity	$	13,402	$	13,390

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

35

    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (UNAUDITED)

	Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Income (Loss)		Total Common Stockholders' Equity		Noncontrolling Interests		Total
	(in millions)
Balance at December 31, 2020	$	914	$	1,522	$	(67)	$	2,369	$	4,262	$	6,631
Net income (loss)	—		97		—		97		(32)		65
Return of capital to parent company	(271)		—		—		(271)		—		(271)
Other comprehensive income	—		—		16		16		—		16
Cash dividends on common stock	—		(51)		—		(51)		—		(51)
Capital contributions from    noncontrolling interests	—		—		—		—		403		403
Distributions to noncontrolling interests	—		—		—		—		(46)		(46)
Other	(2)		1		(1)		(2)		(1)		(3)
Balance at March 31, 2021	641		1,569		(52)		2,158		4,586		6,744
Net income	—		36		—		36		—		36
Other comprehensive income (loss)	—		—		(3)		(3)		—		(3)
Cash dividends on common stock	—		(51)		—		(51)		—		(51)
Capital contributions from    noncontrolling interests	—		—		—		—		29		29
Distributions to noncontrolling interests	—		—		—		—		(68)		(68)
Other	2		—		1		3		—		3
Balance at June 30, 2021	$	643	$	1,554	$	(54)	$	2,143	$	4,547	$	6,690

Balance at December 31, 2021	$	638	$	1,585	$	(27)	$	2,196	$	4,402	$	6,598
Net income (loss)	—		72		—		72		(45)		27
Other comprehensive income	—		—		5		5		—		5
Cash dividends on common stock	—		(49)		—		(49)		—		(49)
Capital contributions from    noncontrolling interests	—		—		—		—		73		73
Distributions to noncontrolling interests	—		—		—		—		(98)		(98)
Balance at March 31, 2022	638		1,608		(22)		2,224		4,332		6,556
Net income (loss)	—		98		—		98		(22)		76
Capital contributions from parent company	322		—		—		322		—		322
Other comprehensive income	—		—		3		3		—		3
Cash dividends on common stock	—		(50)		—		(50)		—		(50)
Distributions to noncontrolling interests	—		—		—		—		(28)		(28)
Balance at June 30, 2022	$	960	$	1,656	$	(19)	$	2,597	$	4,282	$	6,879

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

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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,
	2022		2021		2022		2021
	(in millions)				(in millions)
Operating Revenues:
Natural gas revenues (includes revenue taxes of     $33, $23, $104, and $77, respectively)	$	1,081	$	675	$	3,139	$	2,367
Alternative revenue programs	2		2		1		4
Total operating revenues	1,083		677		3,140		2,371
Operating Expenses:
Cost of natural gas	452		231		1,546		814
Other operations and maintenance	266		233		570		532
Depreciation and amortization	138		133		275		263
Taxes other than income taxes	62		49		163		130
Total operating expenses	918		646		2,554		1,739
Operating Income	165		31		586		632
Other Income and (Expense):
Earnings (loss) from equity method investments	31		(52)		71		(11)
Interest expense, net of amounts capitalized	(61)		(59)		(122)		(118)
Other income (expense), net	16		(14)		32		(78)
Total other income and (expense)	(14)		(125)		(19)		(207)
Earnings (Loss) Before Income Taxes	151		(94)		567		425
Income taxes (benefit)	36		(29)		134		92
Net Income (Loss)	$	115	$	(65)	$	433	$	333

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Net Income (Loss)	$	115	$	(65)	$	433	$	333
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of     $(2), $3, $8, and $3, respectively	(5)		8		22		9
Reclassification adjustment for amounts included in net income,     net of tax of $(3), $—, $(5), and $1, respectively	(7)		—		(13)		3
Total other comprehensive income (loss)	(12)		8		9		12
Comprehensive Income	$	103	$	(57)	$	442	$	345

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,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	433	$	333
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	275		263
Deferred income taxes	35		110
Mark-to-market adjustments	13		137
Impairment of PennEast Pipeline investment	—		82
Natural gas cost under recovery – long-term	192		(119)
Other, net	42		15
Changes in certain current assets and liabilities —
-Receivables	244		262
-Natural gas for sale, net of temporary LIFO liquidation	335		375
-Prepaid income taxes	(70)		(129)
-Natural gas cost under recovery	(94)		(485)
-Other current assets	19		7
-Accounts payable	101		(42)
-Accrued taxes	(41)		1
-Other current liabilities	(6)		(88)
Net cash provided from operating activities	1,478		722
Investing Activities:
Property additions	(637)		(635)
Cost of removal, net of salvage	(53)		(44)
Other investing activities	32		11
Net cash used for investing activities	(658)		(668)
Financing Activities:
Increase (decrease) in notes payable, net	(593)		210
Proceeds — Short-term borrowings	50		300
Redemptions —
Short-term borrowings	(150)		—
Senior notes	—		(300)
Medium-term notes	(46)		(30)
Capital contributions from parent company	349		60
Payment of common stock dividends	(260)		(265)
Net cash used for financing activities	(650)		(25)
Net Change in Cash, Cash Equivalents, and Restricted Cash	170		29
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	48		19
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	218	$	48
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $4 and $3 capitalized for 2022 and 2021, respectively)	$	129	$	127
Income taxes, net	210		100
Noncash transactions — Accrued property additions at end of period	126		137

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, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	217	$	45
Receivables —
Customer accounts	379		462
Unbilled revenues	109		278
Other accounts and notes	53		49
Accumulated provision for uncollectible accounts	(55)		(39)
Natural gas for sale	209		362
Prepaid expenses	185		114
Assets from risk management activities, net of collateral	22		33
Natural gas cost under recovery	361		266
Other regulatory assets	105		136
Other current assets	53		49
Total current assets	1,638		1,755
Property, Plant, and Equipment:
In service	19,362		18,880
Less: Accumulated depreciation	5,201		5,067
Plant in service, net of depreciation	14,161		13,813
Construction work in progress	776		684
Total property, plant, and equipment	14,937		14,497
Other Property and Investments:
Goodwill	5,015		5,015
Equity investments in unconsolidated subsidiaries	1,134		1,173
Other intangible assets, net of amortization of $151 and $145, respectively	31		37
Miscellaneous property and investments	19		19
Total other property and investments	6,199		6,244
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	63		70
Prepaid pension costs	192		175
Other regulatory assets, deferred	459		689
Other deferred charges and assets	130		130
Total deferred charges and other assets	844		1,064
Total Assets	$	23,618	$	23,560

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, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	—	$	47
Notes payable	516		1,209
Accounts payable —
Affiliated	54		58
Other	494		361
Customer deposits	81		95
Accrued taxes	74		124
Accrued interest	58		59
Accrued compensation	91		110
Temporary LIFO liquidation	177		—
Other regulatory liabilities	37		8
Other current liabilities	161		155
Total current liabilities	1,743		2,226
Long-term Debt	6,785		6,855
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,595		1,555
Deferred credits related to income taxes	800		816
Employee benefit obligations	168		176
Operating lease obligations	55		59
Other cost of removal obligations	1,694		1,683
Accrued environmental remediation	181		197
Other deferred credits and liabilities	137		77
Total deferred credits and other liabilities	4,630		4,563
Total Liabilities	13,158		13,644
Common Stockholder's Equity (See accompanying statements)	10,460		9,916
Total Liabilities and Stockholder's Equity	$	23,618	$	23,560

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, 2020	$	9,930	$	(141)	$	(22)	$	9,767
Net income	—		398		—		398
Capital contributions from parent company	57		—		—		57
Other comprehensive income	—		—		4		4
Cash dividends on common stock	—		(132)		—		(132)
Balance at March 31, 2021	9,987		125		(18)		10,094
Net loss	—		(65)		—		(65)
Capital contributions from parent company	25		—		—		25
Other comprehensive income	—		—		8		8
Cash dividends on common stock	—		(133)		—		(133)
Balance at June 30, 2021	$	10,012	$	(73)	$	(10)	$	9,929
Balance at December 31, 2021	$	10,024	$	(132)	$	24	$	9,916
Net income	—		319		—		319
Capital contributions from parent company	50		—		—		50
Other comprehensive income	—		—		20		20
Cash dividends on common stock	—		(130)		—		(130)
Balance at March 31, 2022	10,074		57		44		10,175
Net income	—		115		—		115
Capital contributions from parent company	312		—		—		312
Other comprehensive income (loss)	—		—		(12)		(12)
Cash dividends on common stock	—		(130)		—		(130)
Balance at June 30, 2022	$	10,386	$	42	$	32	$	10,460

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

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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	43
B	Regulatory Matters	46
C	Contingencies	57
D	Revenue from Contracts with Customers and Lease Income	60
E	Consolidated Entities and Equity Method Investments	66
F	Financing and Leases	68
G	Income Taxes	70
H	Retirement Benefits	71
I	Fair Value Measurements	74
J	Derivatives	78
K	Acquisitions and Dispositions	91
L	Segment and Related Information	92

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 list below indicates the Registrants to which each footnote applies.

Registrant	Applicable Notes
Southern Company	A, B, C, D, E, F, G, H, I, J, K, L
Alabama Power	A, B, C, D, F, G, H, I, J
Georgia Power	A, B, C, D, F, G, H, I, J
Mississippi Power	A, B, C, D, F, G, H, I, J
Southern Power	A, C, D, E, F, G, H, I, J, K
Southern Company Gas	A, B, C, D, E, F, G, H, I, J, K, L

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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, 2021 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, 2022 and 2021. Certain information and footnote 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.

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 June 30, 2022 and December 31, 2021 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,280
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 impairment indicators arise.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Other intangible assets were as follows:

	At June 30, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(157)	$	55	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(119)		271		390		(109)		281
Other	10		(9)		1		11		(10)		1
Total other intangible assets subject to amortization	$	676	$	(326)	$	350	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	751	$	(326)	$	425	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(119)	$	271	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(135)	$	21	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(151)	$	31	$	182	$	(145)	$	37

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Amortization associated with other intangible assets was as follows:

	Three Months Ended		Six Months Ended
	June 30, 2022
	(in millions)
Southern Company(a)	$	9	$	19
Southern Power(b)	5		10
Southern Company Gas	2		5

(a)Includes $5 million and $10 million for the three and six months ended June 30, 2022, respectively, recorded as a reduction to operating revenues.

(b)Recorded as a reduction to operating revenues.

Cash, Cash Equivalents, and Restricted Cash

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,724	$	1,798	$	202	$	107	$	217	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,735	$	1,829	$	211	$	135	$	218	$	48

(a)For Southern Power, reflects $9 million and $10 million at June 30, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

Natural Gas for Sale

With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG considered to be other than 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, 2022 is expected to be restored prior to year end.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Depreciation and Amortization

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

Effective January 1, 2022, Southern Power revised the depreciable lives of its wind generating facilities from up to 30 years to up to 35 years. This revision resulted in an immaterial decrease in depreciation for the three and six months ended June 30, 2022 and is expected to result in an immaterial decrease in annual depreciation for 2022.

(B) REGULATORY MATTERS

See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information relating to regulatory matters.

The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at June 30, 2022 and December 31, 2021 were as follows:

Regulatory Clause	Balance Sheet Line Item	June 30, 2022		December 31, 2021
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, deferred	$	29	$	16
Rate CNP PPA	Other regulatory assets, deferred	93		84
Retail Energy Cost Recovery(*)	Other regulatory assets, current	60		—
	Other regulatory assets, deferred	191		126
Georgia Power
Fuel Cost Recovery	Deferred under recovered fuel clause revenues	$	948	$	410
Mississippi Power
Fuel Cost Recovery	Other customer accounts receivable	$	29	$	4
Ad Valorem Tax	Other regulatory assets, current	12		12
	Other regulatory assets, deferred	29		37
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	361	$	266
	Other regulatory assets, deferred	15		207

(*)In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.

Alabama Power

Certificate of Convenience and Necessity

On July 12, 2022, the Alabama PSC approved and, on July 15, 2022, issued its order regarding Alabama Power's petition for a certificate of convenience and necessity (CCN) which authorizes Alabama Power to complete the acquisition of the Calhoun Generating Station, which was approved by the FERC on March 25, 2022, and is expected to close by September 30, 2022. Alabama Power expects to recover all approved costs associated with the acquisition through existing rate mechanisms as outlined in Note 2 to the financial statements in Item 8 of the Form 10-K. The Alabama PSC's order is subject to any rehearing request or judicial appeal filed on or before August 15, 2022. The ultimate outcome of this matter cannot be determined at this time.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Rate ECR

On July 12, 2022, the Alabama PSC approved an adjustment to Rate ECR from 1.960 cents per KWH to 2.557 cents per KWH, or approximately $310 million annually, effective with August 2022 billings. The approved increase in the Rate ECR factor will have no significant effect on Alabama Power's net income, but will increase operating cash flows related to fuel cost recovery. The rate will adjust to 5.910 cents per KWH in January 2025 absent a further order from the Alabama PSC.

Rate NDR

On July 12, 2022, the Alabama PSC approved modifications to Rate NDR, which include an adjustment to the charges to establish and maintain the reserve and an adjustment to the recovery period for any existing deferred storm-related operations and maintenance costs and future reserve deficits from 24 months to 48 months. As modified, the maximum total Rate NDR charge to recover a deficit is limited to $5.00 per month per non-residential customer account and $2.50 per month per residential customer account.

At June 30, 2022, Alabama Power's NDR balance was $103 million. Beginning with August 2022 billings, the reserve establishment charge will be suspended and the reserve maintenance charge will be activated as a result of the NDR balance exceeding $75 million. Alabama Power expects to collect $6 million in the second half of 2022 and approximately $12 million annually beginning in 2023 under Rate NDR unless the NDR balance falls below $50 million. Alabama Power continues to have the authority to accrue additional amounts to the NDR as circumstances warrant.

Reliability Reserve Accounting Order

On July 12, 2022, the Alabama PSC approved an accounting order authorizing Alabama Power to create a reliability reserve separate from the NDR and transition the previous Rate NDR authority related to reliability expenditures to the reliability reserve. Alabama Power may make accruals to the reliability reserve if the NDR balance exceeds $35 million.

Renewable Generation Certificate

Through the issuance of a Renewable Generation Certificate (RGC), Alabama Power is authorized by the Alabama PSC to procure up to 500 MWs of renewable capacity and energy by September 16, 2027 and to market the related energy and environmental attributes to customers and other third parties. In April 2022, one of the existing solar projects which was expected to be served through a PPA commencing in first quarter 2024 was terminated, resulting in the restoration of 80 MWs of capacity under the RGC. The ultimate outcome of this matter cannot be determined at this time.

Georgia Power

Rate Plans

2022 Base Rate Case

On June 24, 2022, Georgia Power filed a base rate case (Georgia Power 2022 Base Rate Case) with the Georgia PSC. The filing proposes continuation of a three-year alternate rate plan with requested rate increases totaling $852 million, $107 million, and $45 million effective January 1, 2023, January 1, 2024, and January 1, 2025, respectively. These increases are based on a proposed retail ROE of 11.00% using the currently approved equity ratio of 56% and reflect levelized revenue requirements during the three-year period, with the exception of incremental compliance costs related to CCR AROs, Demand-Side Management (DSM) programs, and related adjustments to the Municipal Franchise Fee tariff.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Georgia Power has requested recovery of the proposed increases through its existing base rate tariffs as follows:

Tariff	2023		2024		2025
	(in millions)
Traditional base	$	739	$	—	$	—
ECCR
Traditional	(1)		—		—
CCR ARO(a)	64		78		47
DSM(a)	30		27		(2)
Municipal Franchise Fee	20		2		1
Total(b)	$	852	$	107	$	45

(a)As determined by the Georgia PSC through annual compliance filings.

(b)Totals may not add due to rounding.

Georgia Power's filing primarily reflects requests to (i) recover the costs of recent and future capital investments in the electric grid including the transmission and distribution systems and the continuation of its grid investment plan, all designed to support customer long-term reliability and resiliency needs, (ii) recover the cost of coal-fired generation units proposed for retirement, or made unavailable, as requested in the 2022 IRP, as Georgia Power continues the transition of the generation fleet to more economical and cleaner resources, (iii) make the necessary investments and recover costs to comply with federal and state environmental regulations, including costs associated with the CCR AROs related to ash pond and landfill closures and post-closure care, and (iv) reduce operating costs despite significant inflationary pressures. In addition, the filing includes the following provisions:

•Continuation of an allowed retail ROE range of 9.50% to 12.00%.

•Continuation of the process whereby 80% of any earnings above the top of the allowed ROE range are shared with Georgia Power's customers and the remaining 20% are retained by Georgia Power.

•Continuation of the option to file an Interim Cost Recovery tariff in the event earnings are projected to fall below the bottom of the allowed ROE range during the three-year term of the plan.

Georgia Power expects the Georgia PSC to render a final decision in this matter on December 20, 2022. The ultimate outcome of this matter cannot be determined at this time.

2019 ARP

In 2020, the Georgia PSC denied a motion for reconsideration filed by Sierra Club regarding the Georgia PSC's decision in the 2019 ARP allowing Georgia Power to recover compliance costs for CCR AROs. The Superior Court of Fulton County subsequently affirmed the Georgia PSC's decision and, in October 2021, the Georgia Court of Appeals affirmed the Superior Court of Fulton County's order. In December 2021, Sierra Club filed a petition for writ of certiorari to the Georgia Supreme Court, which was denied on July 14, 2022. This matter is now concluded. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information regarding Georgia Power's AROs.

Integrated Resource Plans

In response to supply chain challenges in the solar industry, the Georgia PSC approved Georgia Power's request to amend 970 MWs of utility-scale solar PPAs that were authorized by the Georgia PSC in Georgia Power's 2019 IRP. The amendments extended the required commercial operation dates for the PPAs from 2023 to 2024.

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On July 21, 2022, the Georgia PSC approved the 2022 IRP, as modified by a stipulated agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors and as further modified by the Georgia PSC. In the 2022 IRP decision, the Georgia PSC approved the following requests:

•Decertification and retirement of Plant Wansley Units 1 and 2 (926 MWs based on 53.5% ownership) by August 31, 2022 and reclassification to regulatory asset accounts of the remaining net book values ($302 million and $279 million for Unit 1 and Unit 2, respectively, at June 30, 2022) and any remaining unusable materials and supplies inventories upon retirement. The regulatory asset accounts for the net book values of the units will be amortized at a rate equal to the unit depreciation rates authorized in the 2019 ARP through December 31, 2022. In the Georgia Power 2022 Base Rate Case, Georgia Power requested recovery of the remaining regulatory asset balances for the net book values of the units through 2030 and requested that the timing of recovery of the regulatory asset account for the unusable materials and supplies inventories be determined in a future base rate case.

•Decertification and retirement of Plant Scherer Unit 3 (614 MWs based on 75% ownership) by December 31, 2028 and reclassification to regulatory asset accounts of the remaining net book value (approximately $614 million at June 30, 2022) and any remaining unusable materials and supplies inventory to regulatory asset accounts upon retirement. The timing of recovery for these regulatory assets is expected to be determined in a future base rate case.

•Decertification and retirement of Plant Gaston Units 1 through 4 (500 MWs based on 50% ownership through SEGCO) by December 31, 2028. See Note 7 to the financial statements under "SEGCO" in Item 8 of the Form 10-K for additional information.

•Georgia Power's environmental compliance strategy, including approval of Georgia Power's plans to address CCR at its ash ponds and landfills. Recovery of the related costs is expected to be determined in future base rate cases. The Georgia PSC's approval included a change in the method of closure for one ash pond. Georgia Power is currently evaluating the related impact on its cost estimates and AROs; however, it is not expected to be material.

•Installation of environmental controls at Plants Bowen and Scherer for compliance with rules related to effluent limitations guidelines.

•Initiation of a license renewal application with the NRC for Plant Hatch.

•Investments related to the continued hydro operations of Plants Sinclair and Burton.

•Provisional authorization for development of a 265-MW battery energy storage facility with expected commercial operation in 2026.

•Issuance of requests for proposals (RFP) for 2,300 MWs of renewable resources, an additional 500 MWs of energy storage, and up to 140 MWs of biomass generation.

•Related transmission projects necessary to support the generation facilities plan.

•Certification of six PPAs (including five affiliate PPAs with Southern Power that are subject to approval by the FERC) with capacities of 1,567 MWs beginning in 2024, 380 MWs beginning in 2025, and 228 MWs beginning in 2028, procured through RFPs authorized in the 2019 IRP. See Note (F) under "Georgia Power Lease Modification" for additional information.

The Georgia PSC deferred a decision on the requested decertification and retirement of Plant Bowen Units 1 and 2 (1,400 MWs) to the 2025 IRP and rejected Georgia Power's request to certify approximately 88 MWs of wholesale capacity to be placed in retail rate base between January 1, 2024 and January 1, 2025. Georgia Power may offer such capacity in the wholesale market or to the retail jurisdiction in a future regulatory proceeding.

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

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Nuclear Construction

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a 45.7% ownership interest. In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction of the two AP1000 nuclear units (with electric generating capacity of approximately 1,100 MWs each) and related facilities to begin. Until March 2017, construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement.

In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units. The Vogtle Services Agreement is terminable by the Vogtle Owners upon 30 days' written notice.

In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, under which Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, subject to adjustment based on Bechtel's performance against cost and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its proportionate share, based on its ownership interest, of all amounts owed to Bechtel under the Bechtel Agreement. The Vogtle Owners may terminate the Bechtel Agreement at any time for their convenience, provided that the Vogtle Owners will be required to pay amounts related to work performed prior to the termination (including the applicable portion of the base fee), certain termination-related costs, and, at certain stages of the work, the applicable portion of the at-risk fee. Bechtel may terminate the Bechtel Agreement under certain circumstances, including certain Vogtle Owner suspensions of work, certain breaches of the Bechtel Agreement by the Vogtle Owners, Vogtle Owner insolvency, and certain other events.

See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for information on the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, and mandatory prepayment events.

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,393
Construction contingency estimate	60
Total project capital cost forecast(a)(b)	10,453
Net investment at June 30, 2022(b)	(8,966)
Remaining estimate to complete	$	1,487

(a)Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $455 million of incremental costs under the cost-sharing and tender provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through AFUDC of approximately $385 million, of which $247 million had been accrued through June 30, 2022.

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

Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.4 billion, of which $3.0 billion had been incurred through June 30, 2022.

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As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts on a regular basis to incorporate current information available, particularly in the areas of engineering support, commodity installation, system turnovers and related test results, and workforce statistics. Southern Nuclear establishes aggressive target values for monthly construction production and system turnover activities, which are reflected in the site work plans.

Since March 2020, the number of active COVID-19 cases at the site has fluctuated consistent with the surrounding area and impacted productivity levels and pace of activity completion, with the site experiencing peaks in the number of active cases in January 2021, August 2021, and January 2022. Georgia Power estimates the productivity impacts of the COVID-19 pandemic have consumed approximately three to four months of schedule margin previously embedded in the site work plan for Unit 3 and Unit 4. As of June 30, 2022, Georgia Power's proportionate share of the estimated incremental cost associated with COVID-19 mitigation actions and impacts on construction productivity is estimated to be between $160 million and $200 million and is included in the total project capital cost forecast. The continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing activities at Plant Vogtle Units 3 and 4.

Fuel load for Unit 3 is projected during the fourth quarter 2022 with an in-service date projected during the first quarter 2023. Unit 3's projected schedule primarily depends on the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on Unit 3 progress through fuel load, startup, and testing; overall construction productivity and production levels improving, particularly in electrical installation, including terminations; and appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates and cost increases.

During the first half of 2022, established construction contingency totaling $126 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, additional craft and support resources, and procurement for Units 3 and 4. Georgia Power also increased its total project capital cost forecast as of June 30, 2022 by adding $36 million to replenish construction contingency. After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future regulatory proceedings, Georgia Power recorded a pre-tax charge to income in the second quarter 2022 of $36 million ($27 million after tax) for the increase in the total project capital cost forecast. Georgia Power may request the Georgia PSC to evaluate those expenditures for rate recovery during the prudence review following the Unit 4 fuel load pursuant to the twenty-fourth VCM stipulation described below.

As Unit 3 completes system turnover from construction and moves to testing and transition to operations, ongoing and potential future challenges include construction productivity, completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, and final component and pre-operational tests. As Unit 4 progresses through construction and continues to transition into testing, ongoing and potential future challenges include the pace and quality of electrical installation; availability of craft and supervisory resources, including the temporary diversion of such resources to support Unit 3 construction efforts; the pace of work package closures and system turnovers; and the timeframe and duration of hot functional and other testing. As construction, including subcontract work, continues on both Units 3 and 4, ongoing or future challenges include management of contractors and vendors; subcontractor performance; supervision of craft labor and related productivity, particularly in the installation of electrical, mechanical, and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and procurement and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up, which may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale). The ongoing and potential future challenges described above may change the projected schedule and estimated cost.

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There have been technical and procedural challenges to the construction and licensing of Plant Vogtle Units 3 and 4 at the federal and state level and additional challenges may arise. Additional license amendment requests also may be filed with the NRC. Processes are in place that are designed to ensure compliance with the requirements specified in the Westinghouse Design Control Document and the combined construction and operating licenses, including inspections by Southern Nuclear and the NRC that occur throughout construction. In connection with the additional construction remediation work described above, Southern Nuclear reviewed the project's construction quality programs and, where needed, is implementing improvement plans consistent with these processes. On March 25, 2022, the NRC completed its follow-up inspection related to the November 2021 final significance report on its special inspection to review the root cause of this additional construction remediation work and the corresponding corrective action plans. The NRC closed the two white findings identified in November 2021 and returned Vogtle Unit 3 to the NRC's baseline inspection program.

Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel, have arisen or may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues, including inspections and ITAACs, are not resolved in a timely manner, there may be delays in the project schedule that could result in increased costs.

The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described below, is estimated to result in additional base capital costs for Georgia Power of up to $35 million per month for Unit 3 and $45 million per month for Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. While Georgia Power is not precluded from seeking retail recovery of any future capital cost forecast increase other than the amounts related to the cost-sharing and tender provisions of the joint ownership agreements described below, management will ultimately determine whether or not to seek recovery. Any further changes to the capital cost forecast that are not expected to be recoverable through regulated rates will be required to be charged to income and such charges could be material.

Joint Owner Contracts

In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 to continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements). The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners' sole recourse against Georgia Power or Southern Nuclear for any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power and/or Southern Nuclear as agent, except in cases of willful misconduct.

Amendments to the Vogtle Joint Ownership Agreements

In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power's wholly-owned subsidiaries MEAG Power SPVJ, LLC (MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet) with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power's wholly-owned subsidiaries

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MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership Agreements to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments).

Pursuant to the Global Amendments: (i) each Vogtle Owner must pay its proportionate share of qualifying construction costs for Plant Vogtle Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4 which formed the basis of Georgia Power's forecast of $8.4 billion in the nineteenth VCM plus $800 million; (ii) Georgia Power will be responsible for 55.7% of actual qualifying construction costs between $800 million and $1.6 billion over the EAC in the nineteenth VCM (resulting in $80 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata in accordance with their respective ownership interests; and (iii) Georgia Power will be responsible for 65.7% of qualifying construction costs between $1.6 billion and $2.1 billion over the EAC in the nineteenth VCM (resulting in a further $100 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective ownership interests. If the EAC is revised and exceeds the EAC in the nineteenth VCM by more than $2.1 billion, each of the other Vogtle Owners will have a one-time option at the time the project budget cost forecast is so revised to tender a portion of its ownership interest to Georgia Power in exchange for Georgia Power's agreement to pay 100% of such Vogtle Owner's remaining share of total construction costs in excess of the EAC in the nineteenth VCM plus $2.1 billion.

For purposes of the foregoing provisions, qualifying construction costs will not include costs (i) resulting from force majeure events, including epidemics and quarantines, governmental actions or inactions (or significant delays associated with issuance of such actions) that affect the licensing, completion, start-up, operations, or financing of Plant Vogtle Units 3 and 4, administrative proceedings or litigation regarding ITAAC or other regulatory challenges to commencement of operation of Plant Vogtle Units 3 and 4, and changes in laws or regulations governing Plant Vogtle Units 3 and 4, (ii) legal fees and legal expenses incurred due to litigation with contractors or subcontractors that are not subsidiaries or affiliates of Southern Company, and (iii) additional costs caused by requests from the Vogtle Owners other than Georgia Power, except for the exercise of a right to vote granted under the Vogtle Joint Ownership Agreements, that increase costs by $100,000 or more.

In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 must vote to continue construction if certain adverse events occur, including, among other events: (i) the bankruptcy of Toshiba; (ii) the termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel Agreement, or the agency agreement with Southern Nuclear; (iii) Georgia Power's public announcement of its intention not to submit for rate recovery any portion of its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power's costs relating to the construction of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts paid by Georgia Power on behalf of the other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of costs during any six-month VCM reporting period that are disallowed by the Georgia PSC for recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates; and (iv) an incremental extension of one year or more from the seventeenth VCM report estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in February 2022 triggered the requirement for a vote to continue construction. Effective February 25, 2022, all of the Vogtle Owners had voted to continue construction.

Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments or the extent to which COVID-19-related costs impact those provisions. Based on the definition in the Global Amendments, Georgia Power believes the starting dollar amount is $18.38 billion and the current project capital cost forecast exceeds the cost-sharing provision threshold, but not the tender provision threshold. The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. Georgia Power recorded pre-tax charges to income in the fourth quarter 2021 and the second quarter 2022 of approximately $440 million ($328 million after tax) and $16 million ($12 million after tax), respectively, associated with these cost-sharing and tender provisions, which are

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(UNAUDITED)

included in the total project capital cost forecast. Georgia Power may be required to record further pre-tax charges to income of up to approximately $480 million associated with these provisions based on the current project capital cost forecast. Georgia Power's incremental charges associated with these provisions, which relate to the other Vogtle Owners' share of costs, will not be recovered from retail customers. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement, which was modified on June 3, 2022, to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 194 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022, and would require the other Vogtle Owners to notify Georgia Power of their intent to exercise their tender options by August 27, 2022. On June 17, 2022 and July 26, 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. On June 18, 2022, OPC and MEAG Power each filed a separate lawsuit against Georgia Power in the Superior Court of Fulton County, Georgia seeking a declaratory judgment that the starting dollar amount is $17.1 billion and that the cost-sharing and tender provisions have been triggered. The lawsuits also assert other claims, including breach of contract allegations, and seek, among other remedies, damages and injunctive relief requiring Georgia Power to track and allocate construction costs consistent with MEAG Power's and OPC's interpretations of the Global Amendments. On July 25, 2022, Georgia Power filed its answer in the lawsuit filed by MEAG Power and included counterclaims seeking a declaratory judgment that the starting dollar amount is $18.38 billion and that costs related to force majeure events are excluded prior to calculating the cost-sharing and tender provisions and when calculating Georgia Power's related financial obligations.

Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%; however, it could increase if one or more of the other Vogtle Owners effectively exercise the option to tender a portion of their ownership interest to Georgia Power and require Georgia Power to pay 100% of the remaining share of the costs necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest would be calculated and conveyed to Georgia Power after Plant Vogtle Units 3 and 4 are placed in service.

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

Regulatory Matters

In 2009, the Georgia PSC voted to certify construction of Plant Vogtle Units 3 and 4 with a certified capital cost of $4.418 billion. In addition, in 2009 the Georgia PSC approved inclusion of the Plant Vogtle Units 3 and 4 related CWIP accounts in rate base, and the State of Georgia enacted the Georgia Nuclear Energy Financing Act, which allows Georgia Power to recover financing costs for Plant Vogtle Units 3 and 4. Financing costs are recovered on all applicable certified costs through annual adjustments to the NCCR tariff up to the certified capital cost of $4.418 billion. At June 30, 2022, Georgia Power had recovered approximately $2.8 billion of financing costs. Financing costs related to capital costs above $4.418 billion are being recognized through AFUDC and are expected to be recovered through retail rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to any capital costs in excess of the total deemed reasonable by the Georgia PSC (currently $7.3 billion) and not requested for rate recovery. In November 2021, the Georgia PSC approved Georgia Power's request to decrease the NCCR tariff by $78 million annually, effective January 1, 2022.

Georgia Power is required to file semi-annual VCM reports with the Georgia PSC by February 28 and August 31 of each year. In 2013, in connection with the eighth VCM report, the Georgia PSC approved a stipulation between Georgia Power and the staff of the Georgia PSC to waive the requirement to amend the Plant Vogtle Units 3 and 4 certificate in accordance with the 2009 certification order until the completion of Plant Vogtle Unit 3, or earlier if deemed appropriate by the Georgia PSC and Georgia Power.

In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in connection with the fifteenth VCM report. In December 2017, the Georgia PSC voted to approve (and issued its related order on January 11, 2018) Georgia Power's seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 11, 2018 order, resolved the following regulatory matters related to Plant Vogtle Units 3 and 4: (i) none of the $3.3 billion of costs incurred through December 31, 2015 and reflected in the fourteenth VCM report should be disallowed from rate base on the basis of imprudence; (ii) the Contractor Settlement Agreement was reasonable and

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(UNAUDITED)

prudent and none of the $0.3 billion paid pursuant to the Contractor Settlement Agreement should be disallowed from rate base on the basis of imprudence; (iii) (a) capital costs incurred up to $5.68 billion would be presumed to be reasonable and prudent with the burden of proof on any party challenging such costs, (b) Georgia Power would have the burden to show that any capital costs above $5.68 billion were prudent, and (c) a revised capital cost forecast of $7.3 billion (after reflecting the impact of payments received under the Guarantee Settlement Agreement and related customer refunds) was found reasonable; (iv) construction of Plant Vogtle Units 3 and 4 should be completed, with Southern Nuclear serving as project manager and Bechtel as primary contractor; (v) approved and deemed reasonable Georgia Power's revised schedule placing Plant Vogtle Units 3 and 4 in service in November 2021 and November 2022, respectively; (vi) confirmed that the revised cost forecast does not represent a cost cap and that a prudence proceeding on cost recovery will occur following Unit 4 fuel load, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 alternate rate plan) to 10.00% effective January 1, 2016, (b) from 10.00% to 8.30%, effective January 1, 2020, and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case will be less than Georgia Power's average cost of long-term debt); (viii) reduced the ROE used for AFUDC equity for Plant Vogtle Units 3 and 4 from 10.00% to Georgia Power's average cost of long-term debt, effective January 1, 2018; and (ix) agreed that effective the first month after Unit 3 reaches commercial operation, retail base rates would be adjusted to include the costs related to Unit 3 and common facilities deemed prudent in the Vogtle Cost Settlement Agreement (see Note 2 to the financial statements under "Georgia Power – Plant Vogtle Unit 3 and Common Facilities Rate Proceeding" in Item 8 of the Form 10-K for additional information). The January 11, 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by 10 basis points each month (but not lower than Georgia Power's average cost of long-term debt) until the respective Unit is commercially operational. The ROE reductions negatively impacted earnings by approximately $270 million in 2021 and are estimated to have negative earnings impacts of approximately $300 million and $250 million in 2022 and 2023, respectively. In its January 11, 2018 order, the Georgia PSC also stated if other conditions change and assumptions upon which Georgia Power's seventeenth VCM report are based do not materialize, the Georgia PSC reserved the right to reconsider the decision to continue construction.

In the August 2021 order approving the twenty-fourth VCM report, the Georgia PSC approved a stipulation addressing the following matters: (i) beginning with its twenty-fifth VCM report, Georgia Power will continue to report to the Georgia PSC all costs incurred during the period for review and will request for approval costs up to the $7.3 billion determined to be reasonable in the Georgia PSC's seventeenth VCM order and (ii) Georgia Power will not seek rate recovery of the $0.7 billion increase to the base capital cost forecast included in the nineteenth VCM report and charged to income by Georgia Power in the second quarter 2018. In addition, the stipulation confirms Georgia Power may request verification and approval of costs above $7.3 billion for inclusion in rate base at a later time, but no earlier than the prudence review contemplated by the seventeenth VCM order described previously.

The Georgia PSC has approved 25 VCM reports covering periods through June 30, 2021. These reports reflect total construction capital costs incurred of $7.9 billion (net of $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds), of which the Georgia PSC has verified and approved $7.3 billion as described above. The Georgia PSC has reviewed the twenty-sixth VCM report, which reflects $584 million of additional construction capital costs incurred through December 31, 2021. Georgia Power expects to file its twenty-seventh VCM report with the Georgia PSC by August 31, 2022, which will reflect the revised capital cost forecast discussed above and $522 million of construction capital costs incurred from January 1, 2022 through June 30, 2022.

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

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Mississippi Power

Performance Evaluation Plan

On June 7, 2022, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2022, resulting in an annual increase in revenues of approximately $18 million, or 1.9%, primarily due to increases in rate base, operations and maintenance expenses, and depreciation and amortization. The rate increase became effective with the first billing cycle of April 2022 in accordance with the PEP rate schedule.

Ad Valorem Tax Adjustment

On June 7, 2022, the Mississippi PSC approved Mississippi Power's annual ad valorem tax adjustment filing for 2022, resulting in an annual increase in revenues of $5 million, effective with the first billing cycle of July 2022.

Municipal and Rural Associations Tariff

On May 26, 2022, Mississippi Power and Cooperative Energy executed an amended shared service agreement (SSA) under which Cooperative Energy will continue to decrease its use of Mississippi Power's generation services under the MRA tariff up to 2.5% annually through 2035. At June 30, 2022, Mississippi Power is serving approximately 400 MWs of Cooperative Energy's annual demand. Beginning in 2036, Cooperative Energy will provide 100% of its electricity requirements at the MRA delivery points under the tariff. Neither party has the option to cancel the amended SSA. On June 30, 2022, Mississippi Power filed a request with the FERC for approval of the amended SSA.

On July 15, 2022, Mississippi Power filed a request with the FERC for a $23 million increase in annual wholesale base revenues under the MRA tariff and requested an effective date of July 15, 2022.

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

Southern Company Gas

Infrastructure Replacement Programs and Capital Projects

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first six months of 2022 were as follows:

Utility	Program	Six Months Ended June 30, 2022
		(in millions)
Nicor Gas	Investing in Illinois	$	177
Virginia Natural Gas	Steps to Advance Virginia's Energy	33
Atlanta Gas Light	System Reinforcement Rider	28
Chattanooga Gas	Pipeline Replacement Program	2
Total		$	240

Rate Proceedings

Atlanta Gas Light

On July 1, 2022, Atlanta Gas Light filed its annual GRAM update with the Georgia PSC. The filing requests an annual base rate increase of $53 million based on the projected 12-month period beginning January 1, 2023. Resolution of the GRAM filing is expected by December 28, 2022, with the new rates effective January 1, 2023. The ultimate outcome of this matter cannot be determined at this time.

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(UNAUDITED)

Virginia Natural Gas

On May 31, 2022, Virginia Natural Gas filed a notice of intent with the Virginia State Corporation Commission to file a base rate case later in the third quarter 2022. The ultimate outcome of this matter cannot be determined at this time.

(C) CONTINGENCIES

See Note 3 to the financial statements in Item 8 of the Form 10-K for information relating to various lawsuits and other contingencies.

General Litigation Matters

The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential litigation or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on such Registrant's financial statements.

The Registrants believe the pending legal challenges discussed below have no merit; however, the ultimate outcome of these matters cannot be determined at this time.

Southern Company

In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits named as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of Georgia. The complaints alleged that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints alleged that the defendants were unjustly enriched and caused the waste of corporate assets and also alleged that the individual defendants violated their fiduciary duties.

In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that named as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. The complaint alleged that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleged that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. In August 2019, the court granted a motion filed by the plaintiff in July 2019 to substitute a new named plaintiff, Martin J. Kobuck, in place of Helen E. Piper Survivor's Trust.

The plaintiffs in each of these cases sought to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiffs also sought certain changes to Southern Company's corporate governance and internal processes. On January 21, 2022, the plaintiffs in the federal court action filed a motion for preliminary approval of settlement, together with an executed stipulation of settlement, which applied to both actions. On June 9, 2022, the U.S. District Court for the Northern District of Georgia granted final approval of the settlement and, on June 16, 2022, the Superior Court of Gwinnett County, Georgia entered an order awarding attorneys' fees and expenses related to the Martin J. Kobuck lawsuit. The settlement consists of an aggregate payment by Southern Company's insurers of approximately $4.5 million for attorneys' fees and expenses, as well as adoption of various corporate governance reforms by Southern Company. These matters are now concluded.

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Georgia Power

In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state law claims. This case has been ruled upon and appealed numerous times over the last several years. In 2019, the Georgia PSC issued an order that found Georgia Power has appropriately implemented the municipal franchise fee schedule. In March 2021, the Superior Court of Fulton County granted class certification and Georgia Power's motion for summary judgment and the plaintiffs filed a notice of appeal. In April 2021, Georgia Power filed a notice of cross appeal on the issue of class certification. In December 2021, the Georgia Court of Appeals affirmed the Superior Court's ruling that granted summary judgment to Georgia Power and dismissed Georgia Power's cross appeal on the issue of class certification as moot. Also in December 2021, the plaintiffs filed a petition for writ of certiorari to the Georgia Supreme Court. The amount of any possible losses cannot be estimated at this time because, among other factors, it is unknown whether any losses would be subject to recovery from any municipalities.

In July 2020, a group of individual plaintiffs filed a complaint in the Superior Court of Fulton County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater, surface water, and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages, a medical monitoring fund, and injunctive relief. Georgia Power has filed multiple motions to dismiss the complaint. In October 2021, three additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages. In November 2021, Georgia Power filed a notice to remove the three cases pending in the Superior Court of Monroe County, Georgia to the U.S. District Court for the Middle District of Georgia. On February 7, 2022, four additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power seeking damages for alleged personal injuries or property damage. On March 9, 2022, Georgia Power filed a notice to remove the four cases pending in the Superior Court of Monroe County, Georgia to the U.S. District Court for the Middle District of Georgia. The amount of any possible losses from these matters cannot be estimated at this time.

Mississippi Power

In 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March 2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service. The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds. In November 2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power. In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. On March 21, 2022, the

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U.S. Court of Appeals for the Fifth Circuit issued an opinion affirming the dismissal of the claims against the Mississippi PSC defendants but reversing the dismissal of the claims against Mississippi Power. The appellate court remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. On May 31, 2022, the U.S. Court of Appeals for the Fifth Circuit denied a petition by Mississippi Power for a rehearing en banc and the case was remanded back to the trial court for further proceedings. On June 17, 2022, Mississippi Power filed with the trial court a motion to dismiss the complaint. An adverse outcome in this proceeding could have a material impact on Mississippi Power's financial statements.

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 $16 million and $17 million at June 30, 2022 and December 31, 2021, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected.

Southern Company Gas' environmental remediation liability was $241 million and $249 million at June 30, 2022 and December 31, 2021, respectively, based on the estimated cost of environmental investigation and remediation associated with 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

In conjunction with Southern Company's 2019 sale of Gulf Power, NextEra Energy, Inc. held back $75 million of the purchase price pending Mississippi Power and Gulf Power negotiating a mutually acceptable revised operating agreement for Plant Daniel. On July 12, 2022, the co-owners executed a revised operating agreement and Southern Company subsequently received the remaining $75 million of the purchase price. The revised operating agreement contains dispatch procedures for the two jointly-owned coal units at Plant Daniel such that Mississippi Power will designate one of the two units as primary and the other as secondary in lieu of each company separately owning 100% of a single generating unit. Mississippi Power has the option to purchase its co-owner's ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior to that date. The revised operating agreement is not expected to have a material impact on Mississippi Power's financial statements. See Note 15 to the financial statements under "Southern Company" in Item 8 of the Form 10-K for additional information regarding the sale of Gulf Power.

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(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. See Note 1 to the financial statements under "Revenues" in Item 8 of the Form 10-K for additional information on the revenue policies of the Registrants. See "Lease Income" herein and Note (J) for additional information on revenue accounted for under lease and derivative accounting guidance, respectively.

The following table disaggregates revenue from contracts with customers for the three and six months ended June 30, 2022 and 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2022
Operating revenues
Retail electric revenues
Residential	$	1,655	$	617	$	962	$	76	$	—	$	—
Commercial	1,387		410		900		77		—		—
Industrial	1,005		368		553		84		—		—
Other	25		3		20		2		—		—
Total retail electric revenues	4,072		1,398		2,435		239		—		—
Natural gas distribution revenues
Residential	474		—		—		—		—		474
Commercial	130		—		—		—		—		130
Transportation	276		—		—		—		—		276
Industrial	16		—		—		—		—		16
Other	67		—		—		—		—		67
Total natural gas distribution revenues	963		—		—		—		—		963
Wholesale electric revenues
PPA energy revenues	585		108		40		5		441		—
PPA capacity revenues	136		40		12		—		85		—
Non-PPA revenues	62		35		6		169		196		—
Total wholesale electric revenues	783		183		58		174		722		—
Other natural gas revenues
Gas marketing services	90		—		—		—		—		90
Other natural gas revenues	10		—		—		—		—		10
Total natural gas revenues	100		—		—		—		—		100
Other revenues	308		63		121		9		9		—
Total revenue from contracts with customers	6,226		1,644		2,614		422		731		1,063
Other revenue sources(a)	980		287		507		12		168		20
Total operating revenues	$	7,206	$	1,931	$	3,121	$	434	$	899	$	1,083

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Six Months Ended June 30, 2022
Operating revenues
Retail electric revenues
Residential	$	3,179	$	1,250	$	1,783	$	146	$	—	$	—
Commercial	2,567		786		1,638		143		—		—
Industrial	1,732		691		887		154		—		—
Other	51		7		40		4		—		—
Total retail electric revenues	7,529		2,734		4,348		447		—		—
Natural gas distribution revenues
Residential	1,490		—		—		—		—		1,490
Commercial	400		—		—		—		—		400
Transportation	613		—		—		—		—		613
Industrial	48		—		—		—		—		48
Other	195		—		—		—		—		195
Total natural gas distribution revenues	2,746		—		—		—		—		2,746
Wholesale electric revenues
PPA energy revenues	930		168		72		8		694		—
PPA capacity revenues	268		78		23		3		166		—
Non-PPA revenues	124		99		15		271		269		—
Total wholesale electric revenues	1,322		345		110		282		1,129		—
Other natural gas revenues
Gas marketing services	333		—		—		—		—		333
Other natural gas revenues	26		—		—		—		—		26
Total natural gas revenues	359		—		—		—		—		359
Other revenues	530		109		216		17		17		—
Total revenue from contracts with customers	12,486		3,188		4,674		746		1,146		3,105
Other revenue sources(a)	1,368		392		654		23		292		35
Total operating revenues	$	13,854	$	3,580	$	5,328	$	769	$	1,438	$	3,140

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2021
Operating revenues
Retail electric revenues
Residential	$	1,469	$	553	$	852	$	64	$	—	$	—
Commercial	1,176		386		724		66		—		—
Industrial	728		334		321		73		—		—
Other	23		4		17		2		—		—
Total retail electric revenues	3,396		1,277		1,914		205		—		—
Natural gas distribution revenues
Residential	311		—		—		—		—		311
Commercial	73		—		—		—		—		73
Transportation	247		—		—		—		—		247
Industrial	8		—		—		—		—		8
Other	59		—		—		—		—		59
Total natural gas distribution revenues	698		—		—		—		—		698
Wholesale electric revenues
PPA energy revenues	209		38		16		2		158		—
PPA capacity revenues	118		29		14		1		75		—
Non-PPA revenues	55		25		3		75		78		—
Total wholesale electric revenues	382		92		33		78		311		—
Other natural gas revenues
Wholesale gas services	578		—		—		—		—		578
Gas marketing services	63		—		—		—		—		63
Other natural gas revenues	10		—		—		—		—		10
Total natural gas revenues	651		—		—		—		—		651
Other revenues	295		52		137		7		5		—
Total revenue from contracts with customers	5,422		1,421		2,084		290		316		1,349
Other revenue sources(a)	1,179		135		141		13		174		731
Other adjustments(b)	(1,403)		—		—		—		—		(1,403)
Total operating revenues	$	5,198	$	1,556	$	2,225	$	303	$	490	$	677

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Six Months Ended June 30, 2021
Operating revenues
Retail electric revenues
Residential	$	2,936	$	1,181	$	1,627	$	128	$	—	$	—
Commercial	2,294		758		1,410		126		—		—
Industrial	1,397		654		606		137		—		—
Other	47		9		34		4		—		—
Total retail electric revenues	6,674		2,602		3,677		395		—		—
Natural gas distribution revenues
Residential	925		—		—		—		—		925
Commercial	243		—		—		—		—		243
Transportation	536		—		—		—		—		536
Industrial	24		—		—		—		—		24
Other	155		—		—		—		—		155
Total natural gas distribution revenues	1,883		—		—		—		—		1,883
Wholesale electric revenues
PPA energy revenues	422		81		30		7		313		—
PPA capacity revenues	237		58		27		4		150		—
Non-PPA revenues	119		57		12		162		139		—
Total wholesale electric revenues	778		196		69		173		602		—
Other natural gas revenues
Wholesale gas services	2,168		—		—		—		—		2,168
Gas marketing services	257		—		—		—		—		257
Other natural gas revenues	17		—		—		—		—		17
Total natural gas revenues	2,442		—		—		—		—		2,442
Other revenues	542		97		249		14		9		—
Total revenue from contracts with customers	12,319		2,895		3,995		582		611		4,325
Other revenue sources(a)	2,488		220		200		28		319		1,745
Other adjustments(b)	(3,699)		—		—		—		—		(3,699)
Total operating revenues	$	11,108	$	3,115	$	4,195	$	610	$	930	$	2,371

(a)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 that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies.

(b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (L) under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively.

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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, 2022 and December 31, 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At June 30, 2022	$	3,021	$	773	$	1,217	$	95	$	278	$	504
At December 31, 2021	2,504		589		736		73		149		753
Contract Assets
At June 30, 2022	$	102	$	—	$	38	$	—	$	—	$	—
At December 31, 2021	117		2		63		—		1		—
Contract Liabilities
At June 30, 2022	$	70	$	3	$	25	$	4	$	1	$	—
At December 31, 2021	57		4		14		—		1		—

At June 30, 2022 and December 31, 2021, Georgia Power had contract assets primarily related to 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, and unregulated service agreements, where payment is contingent on project completion. Contract liabilities for Georgia Power relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern Company's unregulated distributed generation business had $63 million and $50 million of contract assets and $38 million and $39 million of contract liabilities at June 30, 2022 and December 31, 2021, respectively, for outstanding performance obligations.

Revenues recognized in the three and six months ended June 30, 2022, which were included in contract liabilities at December 31, 2021, were $10 million and $19 million, respectively, for Southern Company and immaterial for the other Registrants.

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Remaining Performance Obligations

The Subsidiary Registrants have 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. For Southern Company Gas, these contracts involve energy infrastructure enhancement and upgrade projects for certain governmental customers. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at June 30, 2022 are expected to be recognized as follows:

	2022 (remaining)		2023		2024		2025		2026		Thereafter
	(in millions)
Southern Company	$	347	$	617	$	414	$	322	$	307	$	2,340
Alabama Power	15		24		7		5		—		—
Georgia Power	39		63		30		22		11		21
Southern Power	184		347		344		294		299		2,334
Southern Company Gas	16		29		29		—		—		—

Revenue expected to be recognized for performance obligations remaining at June 30, 2022 was immaterial for Mississippi Power.

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Lease Income

Lease income for the three and six months ended June 30, 2022 and 2021 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended June 30, 2022
Lease income - interest income on sales-type leases	$	7	$	—	$	—	$	4	$	3	$	—
Lease income - operating leases	52		19		8		—		21		9
Variable lease income	129		—		—		—		138		—
Total lease income	$	188	$	19	$	8	$	4	$	162	$	9
For the Six Months Ended June 30, 2022
Lease income - interest income on sales-type leases	$	13	$	—	$	—	$	8	$	5	$	—
Lease income - operating leases	105		39		16		1		42		18
Variable lease income	211		—		—		—		227		—
Total lease income	$	329	$	39	$	16	$	9	$	274	$	18
For the Three Months Ended June 30, 2021
Lease income - interest income on sales-type leases	$	4	$	—	$	—	$	4	$	—	$	—
Lease income - operating leases	56		21		10		—		21		9
Variable lease income	128		(1)		—		—		138		—
Total lease income	$	188	$	20	$	10	$	4	$	159	$	9
For the Six Months Ended June 30, 2021
Lease income - interest income on sales-type leases	$	7	$	—	$	—	$	7	$	—	$	—
Lease income - operating leases	112		41		21		1		42		17
Variable lease income	212		—		—		—		228		—
Total lease income	$	331	$	41	$	21	$	8	$	270	$	17

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 for Alabama Power and Southern Power is included in wholesale revenues.

(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 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, 2022 and December 31, 2021, SP Solar had total assets of $6.0 billion and $6.1 billion, respectively, total liabilities of $386 million and $408 million, respectively, and noncontrolling interests of $1.1 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic in accordance with

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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, 2022 and December 31, 2021, SP Wind had total assets of $2.3 billion, total liabilities of $212 million and $130 million, respectively, and noncontrolling interests of $40 million and $41 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.

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, 2022 and December 31, 2021, the other VIEs had total assets of $1.8 billion and $1.9 billion, respectively, total liabilities of $253 million and $263 million, respectively, and noncontrolling interests of $858 million and $886 million, respectively. Under the terms of the partnership agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent.

Equity Method Investments

At June 30, 2022 and December 31, 2021, Southern Power had equity method investments in wind and battery energy storage projects totaling $49 million and $86 million, respectively. Earnings (loss) from these investments were immaterial for both periods presented. During the six months ended June 30, 2022, Southern Power sold equity method investments in wind projects and received proceeds totaling $38 million. The gains associated with the sales were immaterial.

Southern Company Gas

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at June 30, 2022 and December 31, 2021 and related earnings (loss) from those investments for the three and six months ended June 30, 2022 and 2021 were as follows:

Investment Balance	June 30, 2022		December 31, 2021
	(in millions)
SNG	$	1,099	$	1,129
Other(*)	35		44
Total	$	1,134	$	1,173

(*)Balance at June 30, 2022 reflects a $9 million distribution from PennEast Pipeline.

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	Three Months Ended June 30,				Six Months Ended June 30,
Earnings (Loss) from Equity Method Investments	2022		2021		2022		2021
	(in millions)
SNG	$	31	$	28	$	70	$	66
PennEast Pipeline(*)	—		(81)		—		(79)
Other	—		1		1		2
Total	$	31	$	(52)	$	71	$	(11)

(*)Includes a pre-tax impairment charge of $82 million ($58 million after tax) for the three and six months ended June 30, 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

(F) FINANCING AND LEASES

Bank Credit Arrangements

See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K for additional information.

At June 30, 2022, committed credit arrangements with banks were as follows:

	Expires
Company	2023		2024		2025		2026		Total		Unused		Expires within One Year
	(in millions)
Southern Company parent	$	—	$	—	$	—	$	2,000	$	2,000	$	1,998	$	—
Alabama Power	—		550		—		700		1,250		1,250		—
Georgia Power	—		—		—		1,750		1,750		1,726		—
Mississippi Power	—		150		125		—		275		275		—
Southern Power(a)	—		—		—		600		600		568		—
Southern Company Gas(b)	250		—		—		1,500		1,750		1,748		250
SEGCO	30		—		—		—		30		30		30
Southern Company	$	280	$	700	$	125	$	6,550	$	7,655	$	7,595	$	280

(a)Does not include Southern Power Company's two $75 million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $11 million and $5 million, respectively, was unused at June 30, 2022. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)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 2026. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $700 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 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. Nicor Gas is also the borrower of a new $250 million credit arrangement expiring in 2023.

As reflected in the table above, in March 2022, Mississippi Power amended and restated its $125 million revolving credit arrangement, which among other things, extended the maturity date from 2023 to 2025 and allows for borrowing based on term SOFR.

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 or, in the case of Southern Power, cross-default provisions to other indebtedness (including guarantee obligations) that are restricted only to the indebtedness

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of the individual company. Such cross-default provisions to other indebtedness would trigger an event of default if Southern Power defaulted on indebtedness or guarantee obligations over a specified threshold. Such 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, 2022, 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 the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at June 30, 2022 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi Power). In addition, at June 30, 2022, Georgia Power had approximately $445 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

Equity Units

In May 2022, Southern Company remarketed $862.5 million aggregate principal amount of its Series 2019A Remarketable Junior Subordinated Notes due August 1, 2024 (2019A RSNs) and $862.5 million aggregate principal amount of its Series 2019B Remarketable Junior Subordinated Notes due August 1, 2027 (2019B RSNs), pursuant to the terms of its 2019 Series A Equity Units (Equity Units). In connection with the remarketing, the interest rates on the 2019A RSNs and the 2019B RSNs were reset to 4.475% and 5.113%, respectively, payable on a semi-annual basis, and Southern Company ceased to have the ability to redeem these securities prior to maturity or to defer interest payments. Southern Company did not receive any proceeds from the remarketing, which were used to purchase a portfolio of treasury securities maturing on July 28, 2022. On August 1, 2022, the proceeds from this maturing portfolio will be used to settle the purchase contracts entered into as a part of the Equity Units and Southern Company expects to issue approximately 25.2 million shares of common stock. At June 30, 2022 and December 31, 2021, the 2019A RSNs and the 2019B RSNs are included in long-term debt on Southern Company's consolidated balance sheets.

Earnings per Share

For Southern Company, the only differences in computing basic and diluted earnings per share are attributable to awards outstanding under stock-based compensation plans and the Equity Units issued in 2019. Earnings per share dilution resulting from stock-based compensation plans and the Equity Units issuance is determined using the treasury stock method. See Note 8 to the financial statements under "Equity Units" in Item 8 of the Form 10-K and "Equity Units" herein for information on the equity units and Note 12 to the financial statements in Item 8 of the Form 10-K for information on stock-based compensation plans. Shares used to compute diluted earnings per share were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2022	2021	2022	2021
	(in millions)
As reported shares	1,065	1,061	1,064	1,060
Effect of stock-based compensation	5	6	5	6
Effect of equity units	2	—	1	—
Diluted shares	1,072	1,067	1,070	1,066

For all periods presented, an immaterial number of stock-based compensation awards was not included in the diluted earnings per share calculation because the awards were anti-dilutive.

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Southern Company Leveraged Lease

See Note 9 to the financial statements in Item 8 of the Form 10-K for information on a leveraged lease agreement related to energy generation. On June 30, 2022, the Southern Holdings subsidiary operating the generating plant for the lessee provided notice to the lessee to terminate the related operating and maintenance agreement effective June 30, 2023. The parties to the lease agreement are currently negotiating a potential restructuring, which could result in rescission of the termination notice. The ultimate outcome of this matter cannot be determined at this time but is not expected to have a material impact on Southern Company's financial statements.

Georgia Power Lease Modification

See Note 9 to the financial statements in Item 8 of the Form 10-K for information on Georgia Power's leases. Subsequent to June 30, 2022, Georgia Power recognized a lease modification related to an existing non-affiliate PPA which converted from an operating lease to a finance lease upon its approval in the 2022 IRP. As a result, Georgia Power will remove operating lease right-of-use assets, net of amortization of $17 million and lease obligations of $18 million maturing through 2024 and will record finance lease right-of-use assets of $110 million and lease obligations of $111 million maturing through 2039.

(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

Tax Credit and Net Operating Loss Carryforwards

Southern Company had federal ITC and PTC carryforwards (primarily related to Southern Power) totaling $0.9 billion at June 30, 2022 compared to $1.2 billion at December 31, 2021.

The federal PTC and ITC carryforwards begin expiring in 2032, but are expected to be fully utilized by 2025. The utilization of each Registrant's estimated tax credit and state net operating loss carryforwards and related valuation allowances could be impacted by numerous factors, including the acquisition of additional renewable projects, the purchase of rights to additional PTCs of Plant Vogtle Units 3 and 4 pursuant to certain joint ownership agreements, an increase in Georgia Power's ownership interest percentage in Plant Vogtle Units 3 and 4, changes in taxable income projections, and potential income tax rate changes. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4.

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 primarily at Southern Power.

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 18.7% for the six months ended June 30, 2022 compared to 10.7% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings and an adjustment related to a prior year state tax credit carryforward at Georgia Power in 2022.

Georgia Power

Georgia Power's effective tax rate was 16.4% for the six months ended June 30, 2022 compared to a tax benefit rate of (6.9)% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings and an adjustment related to a prior year state tax credit carryforward in 2022.

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Mississippi Power

Mississippi Power's effective tax rate was 18.8% for the six months ended June 30, 2022 compared to 12.6% for the corresponding period in 2021. The effective tax rate increase was primarily due to a decrease in the flowback of excess deferred income taxes in 2022.

Southern Power

Southern Power's effective tax rate was 11.2% for the six months ended June 30, 2022 compared to a tax benefit rate of (12.8)% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings in 2022 and a change in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in the first quarter 2021, partially offset by higher wind PTCs in 2022.

(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 (ERISA). No mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2022. The Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas has a separate unfunded supplemental retirement health care plan that provides medical care and life insurance benefits to employees of discontinued businesses.

During the first quarter 2022, the qualified pension plan achieved the predetermined funding threshold whereby the asset allocation was adjusted to invest a larger portion of the portfolio in fixed rate debt securities.

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, 2022 and 2021 are presented in the following tables.

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2022
Pension Plans
Service cost	$	103	$	24	$	26	$	4	$	3	$	8
Interest cost	102		24		30		4		1		7
Expected return on plan assets	(317)		(75)		(100)		(14)		(4)		(24)
Amortization:
Prior service costs	—		—		1		—		—		—
Regulatory asset	—		—		—		—		—		4
Net loss	60		15		19		4		—		1
Net periodic pension cost (income)	$	(52)	$	(12)	$	(24)	$	(2)	$	—	$	(4)
Postretirement Benefits
Service cost	$	5	$	2	$	1	$	—	$	—	$	—
Interest cost	11		2		3		1		—		1
Expected return on plan assets	(20)		(8)		(6)		(1)		—		(1)
Amortization:
Regulatory asset	—		—		—		—		—		1
Net loss	—		—		1		—		—		—
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1
Six Months Ended June 30, 2022
Pension Plans
Service cost	$	206	$	49	$	52	$	8	$	5	$	17
Interest cost	204		48		61		9		3		14
Expected return on plan assets	(633)		(152)		(199)		(29)		(8)		(46)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		8
Net loss	120		31		37		7		1		3
Net periodic pension cost (income)	$	(103)	$	(24)	$	(48)	$	(5)	$	1	$	(5)
Postretirement Benefits
Service cost	$	11	$	3	$	3	$	—	$	—	$	1
Interest cost	21		5		7		1		—		2
Expected return on plan assets	(40)		(16)		(13)		(1)		—		(3)
Amortization:
Regulatory asset	—		—		—		—		—		3
Net (gain)/loss	—		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(8)	$	(8)	$	(2)	$	—	$	—	$	2

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2021
Pension Plans
Service cost	$	108	$	25	$	28	$	5	$	3	$	9
Interest cost	86		21		26		4		1		6
Expected return on plan assets	(297)		(71)		(94)		(13)		(4)		(22)
Amortization:
Prior service costs	—		—		1		—		—		—
Regulatory asset	—		—		—		—		—		4
Net loss	79		20		25		3		1		3
Net periodic pension cost (income)	$	(24)	$	(5)	$	(14)	$	(1)	$	1	$	—
Postretirement Benefits
Service cost	$	6	$	2	$	1	$	—	$	—	$	1
Interest cost	9		2		3		1		—		1
Expected return on plan assets	(19)		(7)		(6)		(1)		—		(2)
Amortization:
Prior service costs	(1)		—		—		—		—		—
Regulatory asset	—		—		—		—		—		1
Net loss	1		—		—		—		—		—
Net periodic postretirement benefit cost (income)	$	(4)	$	(3)	$	(2)	$	—	$	—	$	1
Six Months Ended June 30, 2021
Pension Plans
Service cost	$	217	$	51	$	56	$	9	$	5	$	18
Interest cost	173		41		52		8		2		12
Expected return on plan assets	(595)		(143)		(188)		(27)		(7)		(43)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		8
Net loss	157		41		50		7		2		6
Net periodic pension cost (income)	$	(48)	$	(10)	$	(29)	$	(3)	$	2	$	—
Postretirement Benefits
Service cost	$	12	$	3	$	3	$	—	$	—	$	1
Interest cost	17		4		6		1		—		2
Expected return on plan assets	(38)		(14)		(13)		(1)		—		(4)
Amortization:
Prior service costs	(1)		—		—		—		—		—
Regulatory asset	—		—		—		—		—		3
Net (gain)/loss	2		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(8)	$	(7)	$	(3)	$	—	$	—	$	1

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(I) FAIR VALUE MEASUREMENTS

At June 30, 2022, 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, 2022	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)	$	43	$	408	$	—	$	—	$	451
Investments in trusts:(b)(c)
Domestic equity	643		168		—		—		811
Foreign equity	122		144		—		—		266
U.S. Treasury and government agency securities	—		273		—		—		273
Municipal bonds	—		56		—		—		56
Pooled funds – fixed income	—		9		—		—		9
Corporate bonds	1		445		—		—		446
Mortgage and asset backed securities	—		89		—		—		89
Private equity	—		—		—		164		164
Cash and cash equivalents	3		—		—		—		3
Other	36		17		—		—		53
Cash equivalents	1,058		10		—		—		1,068
Other investments	9		27		—		—		36
Total	$	1,915	$	1,646	$	—	$	164	$	3,725
Liabilities:
Energy-related derivatives(a)	$	16	$	88	$	—	$	—	$	104
Interest rate derivatives	—		214		—		—		214
Foreign currency derivatives	—		228		—		—		228
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	16	$	543	$	14	$	—	$	573

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	Fair Value Measurements Using:
At June 30, 2022	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	$	—	$	131	$	—	$	—	$	131
Nuclear decommissioning trusts:(b)
Domestic equity	391		159		—		—		550
Foreign equity	122		—		—		—		122
U.S. Treasury and government agency securities	—		17		—		—		17
Municipal bonds	—		2		—		—		2
Corporate bonds	1		227		—		—		228
Mortgage and asset backed securities	—		20		—		—		20
Private equity	—		—		—		164		164
Other	20		—		—		—		20
Cash equivalents	677		10		—		—		687
Other investments	—		27		—		—		27
Total	$	1,211	$	593	$	—	$	164	$	1,968
Liabilities:
Energy-related derivatives	$	—	$	23	$	—	$	—	$	23
Georgia Power
Assets:
Energy-related derivatives	$	—	$	137	$	—	$	—	$	137
Nuclear decommissioning trusts:(b)(c)
Domestic equity	252		1		—		—		253
Foreign equity	—		142		—		—		142
U.S. Treasury and government agency securities	—		256		—		—		256
Municipal bonds	—		54		—		—		54
Corporate bonds	—		218		—		—		218
Mortgage and asset backed securities	—		69		—		—		69
Other	16		17		—		—		33
Cash equivalents	98		—		—		—		98
Total	$	366	$	894	$	—	$	—	$	1,260
Liabilities:
Energy-related derivatives	$	—	$	29	$	—	$	—	$	29

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	Fair Value Measurements Using:
At June 30, 2022	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	$	—	$	121	$	—	$	—	$	121
Liabilities:
Energy-related derivatives	$	—	$	14	$	—	$	—	$	14
Southern Power
Assets:
Energy-related derivatives	$	—	$	6	$	—	$	—	$	6
Liabilities:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1
Foreign currency derivatives	—		45		—		—		45
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	—	$	59	$	14	$	—	$	73
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	43	$	13	$	—	$	—	$	56
Non-qualified deferred compensation trusts:
Domestic equity	—		8		—		—		8
Foreign equity	—		2		—		—		2
Pooled funds – fixed income	—		9		—		—		9
Cash equivalents	3		—		—		—		3
Cash equivalents and restricted cash	192		—		—		—		192
Total	$	238	$	32	$	—	$	—	$	270
Liabilities:
Energy-related derivatives(a)	$	16	$	20	$	—	$	—	$	36
Interest rate derivatives	—		62		—		—		62
Total	$	16	$	82	$	—	$	—	$	98

(a)Excludes cash collateral of $13 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 in Item 8 of the Form 10-K for additional information.

(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. At June 30, 2022, approximately $65 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

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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 the three and six months ended June 30, 2022 and 2021. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

Fair value increases (decreases)	Three Months Ended June 30, 2022		Three Months Ended June 30, 2021		Six Months Ended June 30, 2022		Six Months Ended June 30, 2021
	(in millions)
Southern Company	$	(230)	$	125	$	(380)	$	164
Alabama Power	(125)		77		(192)		118
Georgia Power	(105)		48		(188)		46

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 Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility 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

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contingent consideration 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" include 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, 2022, the fair value measurements of private equity 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 $164 million and unfunded commitments related to the private equity investments totaled $91 million. Private equity investments include high-quality private equity funds across several market sectors and funds that invest in real estate assets. Private equity 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, 2022, 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	$	52.0	$	9.8	$	14.6	$	1.5	$	3.0	$	6.8
Fair value	48.0		9.0		13.7		1.3		2.9		6.2

(*)The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at 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. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' wholesale gas operations used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, 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

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the Form 10-K for additional information. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information regarding the sale of Sequent.

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 operating 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 operating 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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At June 30, 2022, 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(*)	273	2030	2025
Alabama Power	65	2026	—
Georgia Power	75	2025	—
Mississippi Power	71	2026	—
Southern Power	4	2030	—
Southern Company Gas(*)	58	2024	2025

(*)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 long natural gas positions of 64.4 million mmBtu and short natural gas positions of 6.4 million mmBtu at June 30, 2022, which is also included in Southern Company's total volume.

In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is 15 million mmBtu for Southern Company, which includes 4 million mmBtu for Alabama Power, 5 million mmBtu for Georgia Power, 2 million mmBtu for Mississippi Power, and 4 million mmBtu for Southern Power.

For cash flow hedges of energy-related derivatives, the estimated pre-tax gains expected to be reclassified from accumulated OCI to earnings for the 12-month period ending June 30, 2023 total $12 million for both Southern Company and Southern Company Gas and are immaterial for the other Registrants.

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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.

At June 30, 2022, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at June 30, 2022
	(in millions)					(in millions)
Cash Flow Hedges of Existing Debt
Alabama Power	$	50	—	3.18%	August 2027	$	—
Southern Company Gas	250		—	3.26%	August 2032	(5)
Fair Value Hedges of Existing Debt
Southern Company parent	400		1.75%	1-month LIBOR + 0.68%	March 2028	(39)
Southern Company parent	1,000		3.70%	1-month LIBOR + 2.36%	April 2030	(113)
Southern Company Gas	500		1.75%	1-month LIBOR + 0.38%	January 2031	(57)
Southern Company	$	2,200				$	(214)

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, 2023 total $(16) million for Southern Company and are immaterial for the other Registrants. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2052 for Southern Company, Alabama Power, and Georgia Power, 2028 for Mississippi Power, and 2046 for Southern Company Gas.

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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.

At June 30, 2022, 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, 2022
	(in millions)			(in millions)				(in millions)
Fair Value Hedges of Existing Debt
Southern Company parent	$	1,476	3.39%	€	1,250	1.88%	September 2027	$	(183)
Cash Flow Hedges of Existing Debt
Southern Power	564		3.78%	500		1.85%	June 2026	(45)
Southern Company	$	2,040		€	1,750			$	(228)

For cash flow hedges of foreign currency derivatives, the estimated pre-tax losses expected to be reclassified from accumulated OCI to earnings for the 12-month period ending June 30, 2023 are $11 million for Southern Company and 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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The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	267	$	49	$	129	$	30
Other deferred charges and assets/Other deferred credits and liabilities	144		37		72		6
Total derivatives designated as hedging instruments for regulatory purposes	$	411	$	86	$	201	$	36
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	17	$	5	$	7	$	5
Other deferred charges and assets/Other deferred credits and liabilities	6		—		1		—
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	—		19		19		—
Other deferred charges and assets/Other deferred credits and liabilities	—		195		—		29
Foreign currency derivatives:
Assets from risk management activities/Other current liabilities	—		36		—		39
Other deferred charges and assets/Other deferred credits and liabilities	—		192		—		40
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	23	$	447	$	27	$	113
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	15	$	12	$	9	$	4
Other deferred charges and assets/Other deferred credits and liabilities	2		1		1		—
Total derivatives not designated as hedging instruments	$	17	$	13	$	10	$	4
Gross amounts recognized	$	451	$	546	$	238	$	153
Gross amounts offset(a)	(87)		(74)		(25)		(28)
Net amounts recognized in the Balance Sheets(b)	$	364	$	472	$	213	$	125

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	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	76	$	6	$	30	$	9
Other deferred charges and assets/Other deferred credits and liabilities	55		17		25		2
Total derivatives designated as hedging instruments for regulatory purposes	$	131	$	23	$	55	$	11
Gross amounts offset	(20)		(20)		(5)		(5)
Net amounts recognized in the Balance Sheets	$	111	$	3	$	50	$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	102	$	15	$	54	$	6
Other deferred charges and assets/Other deferred credits and liabilities	35		14		21		2
Total derivatives designated as hedging instruments for regulatory purposes	$	137	$	29	$	75	$	8
Gross amounts offset	(21)		(21)		(8)		(8)
Net amounts recognized in the Balance Sheets	$	116	$	8	$	67	$	—
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	67	$	8	$	30	$	3
Other deferred charges and assets/Other deferred credits and liabilities	54		6		26		2
Total derivatives designated as hedging instruments for regulatory purposes	$	121	$	14	$	56	$	5
Gross amounts offset	(11)		(11)		(4)		(4)
Net amounts recognized in the Balance Sheets	$	110	$	3	$	52	$	1

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	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	—	$	—	$	2	$	—
Other deferred charges and assets/Other deferred credits and liabilities	4		—		1		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		11		—		16
Other deferred charges and assets/Other deferred credits and liabilities	—		34		—		—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	4	$	45	$	3	$	16
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	1	$	1	$	1	$	—
Other deferred charges and assets/Other deferred credits and liabilities	1		—		—		—
Total derivatives not designated as hedging instruments	$	2	$	1	$	1	$	—
Gross amounts recognized	$	6	$	46	$	4	$	16
Gross amounts offset	(1)		(1)		—		—
Net amounts recognized in the Balance Sheets	$	5	$	45	$	4	$	16

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	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	23	$	19	$	15	$	12
Total derivatives designated as hedging instruments for regulatory purposes	$	23	$	19	$	15	$	12
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	17	$	5	$	5	$	5
Other deferred charges and assets/Other deferred credits and liabilities	2		—		—		—
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	—		—		6		—
Other deferred charges and assets/Other deferred credits and liabilities	—		62		—		6
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	19	$	67	$	11	$	11
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	13	$	11	$	8	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		1		1		—
Total derivatives not designated as hedging instruments	$	14	$	12	$	9	$	4
Gross amounts recognized	$	56	$	98	$	35	$	27
Gross amounts offset(a)	(34)		(21)		(8)		(11)
Net amounts recognized in the Balance Sheets(b)	$	22	$	77	$	27	$	16

(a)Gross amounts offset include cash collateral held on deposit in broker margin accounts of $13 million and $3 million at June 30, 2022 and December 31, 2021, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives at December 31, 2021. There were no such amounts at June 30, 2022.

Energy-related derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies at June 30, 2022. There were no such instruments for the traditional electric operating companies at December 31, 2021.

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At June 30, 2022 and December 31, 2021, 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, 2022:
Energy-related derivatives:
Other regulatory assets, current	$	(26)	$	(2)	$	(6)	$	(3)	$	(15)
Other regulatory assets, deferred	(3)		(1)		(1)		(1)		—
Other regulatory liabilities, current	234		72		93		62		7
Other regulatory liabilities, deferred	110		39		22		49		—
Total energy-related derivative gains (losses)	$	315	$	108	$	108	$	107	$	(8)
At December 31, 2021:
Energy-related derivatives:
Other regulatory assets, current	$	(17)	$	(6)	$	—	$	—	$	(11)
Other regulatory liabilities, current	107		28		48		27		4
Other regulatory liabilities, deferred	65		22		19		24		—
Total energy-related derivative gains (losses)	$	155	$	44	$	67	$	51	$	(7)

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For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	(1)	$	16	$	41	$	20
Interest rate derivatives	21		(1)		30		2
Foreign currency derivatives	(74)		4		(102)		(43)
Fair value hedges(*):
Foreign currency derivatives	(7)		—		(3)		—
Total	$	(61)	$	19	$	(34)	$	(21)
Georgia Power
Interest rate derivatives	$	19	$	—	$	31	$	—
Southern Power
Cash flow hedges:
Energy-related derivatives	$	2	$	5	$	7	$	8
Foreign currency derivatives	(74)		4		(102)		(43)
Total	$	(72)	$	9	$	(95)	$	(35)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	(2)	$	11	$	35	$	12
Interest rate derivatives	(5)		—		(5)		—
Total	$	(7)	$	11	$	30	$	12

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

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other Registrants.

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For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows:

Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Southern Company
Total cost of natural gas	$	452	$	231	$	1,546	$	814
Gain (loss) on energy-related cash flow hedges(a)	10		1		18		(2)
Total depreciation and amortization	913		891		1,805		1,762
Gain (loss) on energy-related cash flow hedges(a)	4		1		6		4
Total interest expense, net of amounts capitalized	(488)		(450)		(950)		(901)
Gain (loss) on interest rate cash flow hedges(a)	(6)		(7)		(13)		(14)
Gain (loss) on foreign currency cash flow hedges(a)	(7)		(6)		(13)		(12)
Gain (loss) on interest rate fair value hedges(b)	(76)		(3)		(198)		(12)
Total other income (expense), net	139		101		283		160
Gain (loss) on foreign currency cash flow hedges(a)(c)	(73)		17		(97)		(43)
Gain (loss) on foreign currency fair value hedges	(96)		—		(121)		—
Amount excluded from effectiveness testing recognized in earnings	7		—		3		—
Southern Power
Total depreciation and amortization	$	131	$	132	$	251	$	251
Gain (loss) on energy-related cash flow hedges(a)	4		1		6		4
Total interest expense, net of amounts capitalized	(36)		(37)		(73)		(75)
Gain (loss) on foreign currency cash flow hedges(a)	(7)		(6)		(13)		(12)
Total other income (expense), net	1		1		3		8
Gain (loss) on foreign currency cash flow hedges(a)(c)	(73)		17		(97)		(43)
Southern Company Gas
Total cost of natural gas	$	452	$	231	$	1,546	$	814
Gain (loss) on energy-related cash flow hedges(a)	10		—		18		(2)
Total interest expense, net of amounts capitalized	(61)		(59)		(122)		(118)
Gain (loss) on interest rate cash flow hedges(a)	(1)		(1)		(1)		(1)
Gain (loss) on interest rate fair value hedges(b)	(22)		4		(57)		4

(a)Reclassified from accumulated OCI into earnings.

(b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income.

(c)The reclassification from accumulated OCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes.

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income for energy-related derivatives and interest rate derivatives were immaterial for the traditional electric operating companies.

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At June 30, 2022 and December 31, 2021, 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, 2022		At December 31, 2021		At June 30, 2022		At December 31, 2021
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(2,981)	$	(3,280)	$	192	$	9
Southern Company Gas
Long-term debt	$	(437)	$	(493)	$	59	$	2

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas were as follows:

		Gain (Loss)
		Three Months Ended June 30,				Six Months Ended June 30,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location	2022		2021		2022		2021
		(in millions)				(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	(15)	$	(103)	$	(13)	$	(120)
	Cost of natural gas	(25)		9		(5)		16
Total derivatives in non-designated hedging relationships		$	(40)	$	(94)	$	(18)	$	(104)

(*)Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for the other Registrants.

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. At June 30, 2022, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For the applicable Registrants, the fair value of interest rate and 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, 2022. 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. Following the sale of Gulf Power to NextEra Energy, Inc., Gulf Power continued participating in the Southern Company power pool through July 13, 2022.

Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. If collateral is required, fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against fair value amounts recognized for derivatives executed with the same counterparty.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

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, 2022, cash collateral posted in these accounts was immaterial. 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. At June 30, 2022, cash collateral held on deposit in broker margin accounts was $13 million.

The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants only enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's and S&P 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.

(K) ACQUISITIONS AND DISPOSITIONS

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

Southern Power

Construction Projects

During the six months ended June 30, 2022, Southern Power completed construction of and placed in service the remaining 40 MWs of the Tranquillity battery energy storage facility and the remaining 15 MWs of the Garland battery energy storage facility.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	COD	PPA Contract Period
Projects Completed During the Six Months Ended June 30, 2022
Garland Solar Storage(a)	Battery energy storage system	88	Kern County, CA	September 2021 through February 2022(b)	20 years
Tranquillity Solar Storage(a)	Battery energy storage system	72	Fresno County, CA	November 2021 through March 2022(c)	20 years

(a)Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest.

(b)The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in February 2022.

(c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in March 2022.

Southern Company Gas

On May 20, 2022, Southern Company Gas received the final $5 million contingent payment from Dominion Modular LNG Holdings, Inc. in connection with its 2020 sale of Pivotal LNG, Inc.

(L) SEGMENT AND RELATED 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, 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. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' other businesses also included wholesale gas 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. Revenues from sales by Southern Power to the traditional electric operating companies were $232 million and $337 million for the three and six months ended June 30, 2022, respectively, and $112 million and $193 million for the three and six months ended June 30, 2021, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for all periods presented. Revenues from sales of natural gas from Southern Company Gas (prior to its sale of Sequent) to Southern Power were $6 million and $18 million for the three and six months ended June 30, 2021, respectively. 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 and, for the three and six months ended June 30, 2021, leveraged lease projects. All other inter-segment revenues are not material.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Financial data for business segments and products and services for the three and six months ended June 30, 2022 and 2021 was as follows:

	Electric Utilities
	Traditional Electric Operating Companies		Southern Power		Eliminations		Total		Southern Company Gas		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended June 30, 2022
Operating revenues	$	5,563	$	899	$	(456)	$	6,006	$	1,083	$	159	$	(42)	$	7,206
Segment net income (loss)(a)(b)	1,036		98		—		1,134		115		(137)		(5)		1,107
Six Months Ended June 30, 2022
Operating revenues	$	9,778	$	1,438	$	(700)	$	10,516	$	3,140	$	283	$	(85)	$	13,854
Segment net income (loss)(a)(b)	1,811		170		—		1,981		433		(263)		(12)		2,139
At June 30, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	92,742		13,402		(787)		105,357		23,618		2,457		(663)		130,769
Three Months Ended June 30, 2021
Operating revenues	$	4,031	$	490	$	(114)	$	4,407	$	677	$	154	$	(40)	$	5,198
Segment net income (loss)(a)(b)(c)	511		36		—		547		(65)		(108)		(2)		372
Six Months Ended June 30, 2021
Operating revenues	$	7,795	$	930	$	(201)	$	8,524	$	2,371	$	288	$	(75)	$	11,108
Segment net income (loss)(a)(b)(c)(d)	1,267		133		—		1,400		333		(216)		(9)		1,508
At December 31, 2021
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	89,051		13,390		(667)		101,774		23,560		2,975		(775)		127,534

(a)Attributable to Southern Company.

(b)For the traditional electric operating companies, includes pre-tax charges at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4 of $52 million ($39 million after tax) for the three and six months ended June 30, 2022 and $460 million ($343 million after tax) and $508 million ($379 million after tax) for the three and six months ended June 30, 2021, respectively. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

(c)For Southern Company Gas, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to its equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

(d)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended June 30, 2022	$	4,789	$	937	$	280	$	6,006
Three Months Ended June 30, 2021	3,599		546		262		4,407
Six Months Ended June 30, 2022	$	8,402	$	1,601	$	513	$	10,516
Six Months Ended June 30, 2021	6,941		1,091		492		8,524

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

	Southern Company Gas' Revenues
	Gas Distribution Operations		Wholesale Gas Services(*)		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended June 30, 2022	$	975	$	—	$	92	$	16	$	1,083
Three Months Ended June 30, 2021	706		(110)		64		17		677
Six Months Ended June 30, 2022	$	2,765	$	—	$	335	$	40	$	3,140
Six Months Ended June 30, 2021	1,898		188		259		26		2,371

(*)Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. See "Southern Company Gas" herein and Note 15 to the financial statements under "Southern Company Gas" 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. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information on the sale of Sequent.

Gas distribution operations 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.

Gas pipeline investments 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. Gas pipeline investments also includes a 20% ownership interest in the PennEast Pipeline project, which was cancelled in September 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Through July 1, 2021, wholesale gas services provided natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engaged in natural gas storage and gas pipeline arbitrage and related activities.

Gas marketing services 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.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

Business segment financial data for the three and six months ended June 30, 2022 and 2021 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Wholesale Gas Services(a)		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended June 30, 2022
Operating revenues	$	980	$	8	$	—	$	92	$	1,080	$	10	$	(7)	$	1,083
Segment net income (loss)	92		23		—		1		116		(1)		—		115
Six Months Ended June 30, 2022
Operating revenues	$	2,782	$	16	$	—	$	335	$	3,133	$	26	$	(19)	$	3,140
Segment net income (loss)	306		52		—		67		425		8		—		433
Total assets at June 30, 2022	21,183		1,433		—		1,554		24,170		11,999		(12,551)		23,618
Three Months Ended June 30, 2021
Operating revenues	$	710	$	8	$	(110)	$	64	$	672	$	11	$	(6)	$	677
Segment net income (loss)(b)	80		(36)		(112)		6		(62)		(3)		—		(65)
Six Months Ended June 30, 2021
Operating revenues	$	1,910	$	16	$	188	$	259	$	2,373	$	18	$	(20)	$	2,371
Segment net income (loss)(b)	263		(7)		14		62		332		1		—		333
Total assets at December 31, 2021	20,917		1,467		31		1,556		23,971		12,114		(12,525)		23,560

(a)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three and six months ended June 30, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended June 30, 2021	$	1,292	$	27	$	1,319	$	1,429	$	(110)
Six Months Ended June 30, 2021	3,881		90		3,971		3,783		188

(b)For gas pipeline investments, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to the equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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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	97
Results of Operations	100
Southern Company	100
Alabama Power	109
Georgia Power	114
Mississippi Power	120
Southern Power	124
Southern Company Gas	127
Future Earnings Potential	135
Accounting Policies	138
Financial Condition and Liquidity	139

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.

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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. Southern Company Gas' reportable segments are gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas 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 and the sale of Sequent, see BUSINESS – "The Southern Company System" in Item 1 of the Form 10-K and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K, respectively.

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. For Southern Power, these 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 July 12, 2022, the Alabama PSC approved the following items:

•Alabama Power's petition for a certificate of convenience and necessity, which authorizes Alabama Power to complete the acquisition of the Calhoun Generating Station. This transaction is expected to close by September 30, 2022.

•An increase to Rate ECR effective with August 2022 billings, which is expected to result in an increase of approximately $310 million annually. The approved increase in the Rate ECR factor will have no significant effect on Alabama Power's net income, but will increase operating cash flows related to fuel cost recovery.

•Modifications to Rate NDR.

•An accounting order authorizing Alabama Power to create a reliability reserve separate from the NDR and transition the previous Rate NDR authority related to reliability expenditures to the reliability reserve. Alabama Power may make accruals to the reliability reserve if the NDR balance exceeds $35 million.

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

Georgia Power

Plant Vogtle Units 3 and 4 Construction and Start-Up Status

Construction continues on Plant Vogtle Units 3 and 4 (with electric generating capacity of approximately 1,100 MWs each), in which Georgia Power currently holds a 45.7% ownership interest. Georgia Power's share of the total project capital cost forecast to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is $10.5 billion.

Fuel load for Unit 3 is projected during the fourth quarter 2022 with an in-service date projected during the first quarter 2023. Unit 3's projected schedule primarily depends on the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on Unit 3 progress through fuel load, startup, and testing; overall construction productivity and production levels improving, particularly in electrical installation, including terminations; and appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates and cost increases.

During the first half of 2022, established construction contingency totaling $126 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, additional craft and support resources, and procurement for Units 3 and 4. Georgia Power also increased its total project capital cost forecast as of June 30, 2022 by adding $36 million to replenish construction contingency. After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future regulatory proceedings, Georgia Power recorded a pre-tax charge to income in the second quarter 2022 of $36 million ($27 million after tax) for the increase in the total project capital cost forecast. Georgia Power may request the Georgia PSC to evaluate those expenditures for rate recovery during the prudence review following the Unit 4 fuel load pursuant to the twenty-fourth VCM stipulation described in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction – Regulatory Matters" herein.

Georgia Power and the other Vogtle Owners do not agree on the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments (as defined in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction – Joint Owner Contracts" herein). The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. Georgia Power recorded pre-tax charges to income in the fourth quarter 2021 and the second quarter 2022 of approximately $440 million ($328 million after tax) and $16 million ($12 million after tax), respectively, associated with these cost-sharing and tender provisions, which are included in the total project capital cost forecast. Georgia Power may be required to record further pre-tax charges to income of up to approximately $480 million associated with these provisions based on the current project capital cost forecast. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement, which was modified on June 3, 2022, to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 194 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022, and would require the other Vogtle Owners to notify Georgia Power of their intent to exercise their tender options by August 27, 2022. On June 17, 2022 and July 26, 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. On June 18, 2022, OPC and MEAG Power each filed a separate lawsuit against Georgia Power in the Superior Court of Fulton County, Georgia seeking a declaratory judgment that the starting dollar amount is $17.1 billion and that the cost-sharing and tender provisions have been triggered. On July 25, 2022, Georgia Power filed its answer in the lawsuit filed by MEAG Power and included counterclaims seeking a declaratory judgment that the starting dollar amount is $18.38 billion and that costs related to force majeure events are excluded prior to calculating the cost-sharing and tender provisions and when calculating Georgia Power's related financial obligations.

The ultimate impact of these matters on the construction schedule and project capital cost forecast for Plant Vogtle Units 3 and 4 cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

2022 Base Rate Case

On June 24, 2022, Georgia Power filed a base rate case (Georgia Power 2022 Base Rate Case) with the Georgia PSC. The filing proposes a three-year alternate rate plan with requested rate increases totaling $852 million, $107 million, and $45 million effective January 1, 2023, January 1, 2024, and January 1, 2025, respectively. Georgia Power expects the Georgia PSC to render a final decision in this matter on December 20, 2022. The ultimate outcome of this matter cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Georgia Power – Rate Plans – 2022 Base Rate Case" herein for additional information.

Integrated Resource Plan

On July 21, 2022, the Georgia PSC approved Georgia Power's triennial IRP (2022 IRP), as modified by a stipulated agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors and as further modified by the Georgia PSC. In the 2022 IRP decision, the Georgia PSC approved several requests, including the following:

•Decertification and retirement of Plant Wansley Units 1 and 2 (926 MWs based on 53.5% ownership) by August 31, 2022 and Plant Scherer Unit 3 (614 MWs based on 75% ownership) by December 31, 2028, as well as the reclassification to regulatory asset accounts of the remaining net book values of these units and any remaining unusable materials and supplies inventories upon retirement.

•Decertification and retirement of Plant Gaston Units 1 through 4 (500 MWs based on 50% ownership through SEGCO) by December 31, 2028. See Note 7 to the financial statements under "SEGCO" in Item 8 of the Form 10-K for additional information.

•Georgia Power's environmental compliance strategy, including approval of Georgia Power's plans to address CCR at its ash ponds and landfills.

The Georgia PSC deferred a decision on the requested decertification and retirement of Plant Bowen Units 1 and 2 (1,400 MWs) to the 2025 IRP.

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

Mississippi Power

On June 7, 2022, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2022, resulting in an annual increase in revenues of approximately $18 million, or 1.9%. The rate increase became effective with the first billing cycle of April 2022 in accordance with the PEP rate schedule.

On May 26, 2022, Mississippi Power and Cooperative Energy executed an amended shared service agreement (SSA) under which Cooperative Energy will continue to decrease its use of Mississippi Power's generation services under the MRA tariff up to 2.5% annually through 2035. At June 30, 2022, Mississippi Power is serving approximately 400 MWs of Cooperative Energy's annual demand. Beginning in 2036, Cooperative Energy will provide 100% of its electricity requirements at the MRA delivery points under the tariff. Neither party has the option to cancel the amended SSA. On June 30, 2022, Mississippi Power filed a request with the FERC for approval of the amended SSA. Mississippi Power expects to remarket this capacity, including the potential development of future arrangements with Cooperative Energy.

On July 15, 2022, Mississippi Power filed a request with the FERC for a $23 million increase in annual wholesale base revenues under the MRA tariff effective July 15, 2022, subject to refund. The ultimate outcome of this matter cannot be determined at this time.

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

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Power

During the six months ended June 30, 2022, Southern Power completed construction of and placed in service the remaining 40 MWs of the Tranquillity battery energy storage facility and the remaining 15 MWs of the Garland battery energy storage facility. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

At June 30, 2022, 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 2026 and 92% through 2031, with an average remaining contract duration of approximately 13 years.

Southern Company Gas

On May 31, 2022, Virginia Natural Gas filed a notice of intent with the Virginia State Corporation Commission to file a base rate case later in the third quarter 2022.

On July 1, 2022, Atlanta Gas Light filed its annual GRAM update with the Georgia PSC. The filing requests an annual base rate increase of $53 million based on the projected 12-month period beginning January 1, 2023. Resolution of the GRAM filing is expected by December 28, 2022, with the new rates effective January 1, 2023.

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

RESULTS OF OPERATIONS

Southern Company

Net Income

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$735	N/M	$631	41.8

N/M - Not meaningful

Consolidated net income attributable to Southern Company was $1.1 billion ($1.04 per share) in the second quarter 2022 compared to $0.4 billion ($0.35 per share) for the corresponding period in 2021. For year-to-date 2022, consolidated net income attributable to Southern Company was $2.1 billion ($2.01 per share) compared to $1.5 billion ($1.42 per share) for the corresponding period in 2021. The increases were primarily due to decreases of $304 million and $340 million in the second quarter and year-to-date 2022, respectively, in after-tax charges related to the construction of Plant Vogtle Units 3 and 4, an after-tax charge of $58 million in the second quarter 2021 related to the PennEast pipeline project at Southern Company Gas, an increase in retail electric revenues associated with rates and pricing and warmer weather, and an increase in natural gas revenues from base rate increases and continued infrastructure replacement. The second quarter 2021 net loss of $112 million at Sequent, which was sold on July 1, 2021, also contributed to the net income increase in the second quarter 2022. These increases were partially offset by higher non-fuel operations and maintenance costs.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Retail Electric Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$1,190	33.1	$1,461	21.0

In the second quarter 2022, retail electric revenues were $4.8 billion compared to $3.6 billion for the corresponding period in 2021. For year-to-date 2022, retail electric revenues were $8.4 billion compared to $6.9 billion for the corresponding period in 2021.

Details of the changes in retail electric revenues were as follows:

	Second Quarter 2022				Year-To-Date 2022
	(in millions)		(% change)		(in millions)		(% change)
Retail electric – prior year	$	3,599			$	6,941
Estimated change resulting from –
Rates and pricing	237		6.6	%	293		4.2	%
Sales growth	66		1.9		85		1.2
Weather	145		4.0		161		2.3
Fuel and other cost recovery	742		20.6		922		13.3
Retail electric – current year	$	4,789	33.1	%	$	8,402	21.0	%

Revenues associated with changes in rates and pricing increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. The increases were primarily due to higher contributions from commercial and industrial customers with variable demand-driven pricing, base tariff increases in accordance with Georgia Power's 2019 ARP, and pricing effects associated with residential customer usage. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales increased 1.0% in the second quarter 2022 when compared to the corresponding period in 2021 primarily due to strong customer growth, partially offset by decreased customer usage. Weather-adjusted residential KWH sales decreased 0.1% for year-to-date 2022 when compared to the corresponding period in 2021 and weather-adjusted commercial KWH sales increased 2.2% and 2.1% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to impacts on customer usage from increased activity outside the home as customers return to pre-pandemic levels of activity. Increased customer growth largely offset the decrease in customer usage impacting year-to-date 2022 residential KWH sales and contributed to the increase in commercial KWH sales. Industrial KWH sales increased 3.7% and 2.8% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to strength in the pipeline and paper sectors, partially offset by a decrease in the chemicals sector.

Fuel and other cost recovery revenues increased $742 million and $922 million in the second quarter and year-to-date 2022, respectively, compared to the corresponding periods in 2021 primarily due to higher fuel and purchased power costs and an increase in the volume of KWHs generated. 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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AND RESULTS OF OPERATIONS (Continued)

Wholesale Electric Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$391	71.6	$510	46.7

In the second quarter 2022, wholesale electric revenues were $937 million compared to $546 million for the corresponding period in 2021. For year-to-date 2022, wholesale electric revenues were $1.6 billion compared to $1.1 billion for the corresponding period in 2021. The increases were primarily due to increases of $376 million and $493 million in the second quarter and year-to-date 2022, respectively, in energy revenues as a result of fuel and purchased power price increases when compared to the corresponding periods in 2021 and an increase in the volume of KWHs sold primarily associated with sales under natural gas PPAs at Southern Power. In addition, increases in capacity revenues of $15 million and $18 million in the second quarter and year-to-date 2022, respectively, were primarily due to increased capacity sales under natural gas PPAs at Southern 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 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$17	9.7	$24	6.9

In the second quarter 2022, other electric revenues were $192 million compared to $175 million for the corresponding period in 2021. For year-to-date 2022, other electric revenues were $370 million compared to $346 million for the corresponding period in 2021. The increases in the second quarter and year-to-date 2022 were primarily due to increases of $19 million and $27 million, respectively, in transmission revenues, $5 million and $8 million, respectively, in cogeneration steam revenues associated with higher natural gas prices at Alabama Power, and $4 million and $5 million, respectively, in rent revenues at the traditional electric operating companies, partially offset by decreases of $12 million and $20 million, respectively, resulting from the termination of a transmission service contract at Georgia Power.

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AND RESULTS OF OPERATIONS (Continued)

Natural Gas Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$406	60.0	$769	32.4

In the second quarter 2022, natural gas revenues were $1.1 billion compared to $677 million for the corresponding period in 2021. For year-to-date 2022, natural gas revenues were $3.1 billion compared to $2.4 billion for the corresponding period in 2021.

Details of the changes in natural gas revenues were as follows:

	Second Quarter 2022				Year-To-Date 2022
	(in millions)		(% change)		(in millions)		(% change)
Natural gas revenues – prior year	$	677			$	2,371
Estimated change resulting from –
Infrastructure replacement programs and base rate changes	46		6.8	%	132		5.6	%
Gas costs and other cost recovery	239		35.3		783		33.0
Gas marketing services	(5)		(0.7)		13		0.5
Wholesale gas services	110		16.2		(187)		(7.9)
Other	16		2.4		28		1.2
Natural gas revenues – current year	$	1,083	60.0	%	$	3,140	32.4	%

Revenues from infrastructure replacement programs and base rate changes at the natural gas distribution utilities increased in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 primarily due to rate increases at Nicor Gas, Atlanta Gas Light, and Chattanooga Gas and continued investment in infrastructure replacement. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

Revenues associated with gas costs and other cost recovery increased in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 primarily due to higher volumes of natural gas sold and higher natural gas cost recovery. 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 decreased in the second quarter 2022 compared to the corresponding period in 2021 due to unrealized hedge losses and warmer weather in the second quarter 2022. For year-to-date 2022, revenues increased compared to the corresponding period in 2021 due to higher commodity prices and higher sales to commercial customers.

The changes in revenues related to Southern Company Gas' wholesale gas services were due to the sale of Sequent on July 1, 2021. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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AND RESULTS OF OPERATIONS (Continued)

Other Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$4	2.0	$(18)	(5.0)

For year-to-date 2022, other revenues were $341 million compared to $359 million for the corresponding period in 2021. The decrease was primarily due to a net decrease of $22 million in unregulated sales at Georgia Power primarily due to the timing of revenue recognition for a large, ongoing power delivery construction and maintenance contract, partially offset by increases associated with more energy conservation projects performed in 2022.

Fuel and Purchased Power Expenses

	Second Quarter 2022 vs. Second Quarter 2021			Year-To-Date 2022 vs. Year-To-Date 2021
	(change in millions)		(% change)	(change in millions)		(% change)
Fuel	$	867	102.2	$	1,130	66.6
Purchased power	191		88.0	216		50.9
Total fuel and purchased power expenses	$	1,058		$	1,346

In the second quarter 2022, total fuel and purchased power expenses were $2.1 billion compared to $1.1 billion for the corresponding period in 2021. The increase was primarily the result of an $853 million increase in the average cost of fuel and purchased power and a $205 million increase in the volume of KWHs generated and purchased.

For year-to-date 2022, total fuel and purchased power expenses were $3.5 billion compared to $2.1 billion for the corresponding period in 2021. The increase was primarily the result of a $1.1 billion increase in the average cost of fuel and purchased power and a $239 million increase in 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.

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AND RESULTS OF OPERATIONS (Continued)

Details of the Southern Company system's generation and purchased power were as follows:

	Second Quarter 2022	Second Quarter 2021	Year-To-Date 2022	Year-To-Date 2021
Total generation (in billions of KWHs)(a)	46	43	92	86
Total purchased power (in billions of KWHs)	6	4	11	8
Sources of generation (percent)(a) —
Gas	49	47	47	46
Coal	22	22	23	23
Nuclear	16	18	16	18
Hydro	3	4	5	4
Wind, Solar, and Other	10	9	9	9
Cost of fuel, generated (in cents per net KWH)—
Gas(a)	5.59	2.58	4.60	2.56
Coal	3.50	2.87	3.30	2.85
Nuclear	0.72	0.75	0.72	0.75
Average cost of fuel, generated (in cents per net KWH)(a)	4.13	2.28	3.50	2.27
Average cost of purchased power (in cents per net KWH)(b)	7.83	5.65	6.90	5.37

(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel as its fuel is provided by the purchaser under a power sales agreement. See Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

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

Fuel

In the second quarter 2022, fuel expense was $1.7 billion compared to $0.8 billion for the corresponding period in 2021. The increase was primarily due to a 116.7% increase in the average cost of natural gas per KWH generated, a 23.2% decrease in the volume of KWHs generated by hydro, a 22.0% increase in the average cost of coal per KWH generated, a 10.4% increase in the volume of KWHs generated by natural gas, and a 9.0% increase in the volume of KWHs generated by coal.

For year-to-date 2022, fuel expense was $2.8 billion compared to $1.7 billion for the corresponding period in 2021. The increase was primarily due to a 79.7% increase in the average cost of natural gas per KWH generated, a 15.8% increase in the average cost of coal per KWH generated, a 7.6% increase in the volume of KWHs generated by natural gas, and a 5.8% increase in the volume of KWHs generated by coal, partially offset by a 9.8% increase in the volume of KWHs generated by hydro.

Purchased Power

In the second quarter 2022, purchased power expense was $408 million compared to $217 million for the corresponding period in 2021. The increase was primarily due to a 38.6% increase in the average cost per KWH purchased primarily due to higher natural gas and coal prices and a 55.3% increase in the volume of KWHs purchased.

For year-to-date 2022, purchased power expense was $640 million compared to $424 million for the corresponding period in 2021. The increase was primarily due to a 28.5% increase in the average cost per KWH purchased primarily due to higher natural gas and coal prices and a 29.4% increase in the volume of KWHs purchased.

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.

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AND RESULTS OF OPERATIONS (Continued)

Cost of Natural Gas

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$221	95.7	$732	89.9

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 the natural gas distribution utilities. Cost of natural gas at the natural gas distribution utilities represented 88% and 89% of the total cost of natural gas in the second quarter and year-to-date 2022, respectively.

In the second quarter 2022, cost of natural gas was $452 million compared to $231 million for the corresponding period in 2021. For year-to-date 2022, cost of natural gas was $1.5 billion compared to $814 million for the corresponding period in 2021. The increases reflect higher gas cost recovery as a result of increases of 153.2% and 119.4% in natural gas prices in the second quarter and year-to-date 2022, respectively, compared to the corresponding periods in 2021.

Cost of Other Sales

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$11	10.7	$(2)	(1.1)

In the second quarter 2022, cost of other sales was $114 million compared to $103 million for the corresponding period in 2021. The increase was primarily due to increases of $14 million related to distributed infrastructure projects at PowerSecure, $7 million associated with unregulated merchandising and energy services expenses at Alabama Power, and $5 million related to unregulated construction and maintenance contracts at Mississippi Power, partially offset by a $16 million decrease associated with unregulated power delivery construction and maintenance projects at Georgia Power.

For year-to-date 2022, cost of other sales was $183 million compared to $185 million for the corresponding period in 2021. The decrease was primarily due to a decrease of $26 million associated with unregulated power delivery construction and maintenance projects at Georgia Power, largely offset by increases of $14 million related to distributed infrastructure projects at PowerSecure, $5 million related to unregulated construction and maintenance contracts at Mississippi Power, and $5 million associated with unregulated merchandising and energy services expenses at Alabama Power.

Other Operations and Maintenance Expenses

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$120	8.3	$265	9.4

In the second quarter 2022, other operations and maintenance expenses were $1.6 billion compared to $1.4 billion for the corresponding period in 2021. Other operations and maintenance expenses increased $124 million, excluding expenses related to Sequent in the second quarter 2021. The increase was primarily due to increases of $29 million in transmission and distribution expenses primarily related to line maintenance, $22 million in generation expenses primarily related to scheduled outage and maintenance costs, $13 million in compensation and benefit expenses, $9 million associated with more unregulated energy conservation projects in 2022 at Georgia Power, $8 million in expenses at Southern Company Gas passed through directly to customers, primarily related to bad debt, and $6 million in amortization of cloud software.

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AND RESULTS OF OPERATIONS (Continued)

For year-to-date 2022, other operations and maintenance expenses were $3.1 billion compared to $2.8 billion for the corresponding period in 2021. Excluding $53 million of expenses related to Sequent in 2021, other operations and maintenance expenses increased $318 million. The increase was primarily due to increases of $86 million in transmission and distribution expenses primarily related to line maintenance, $80 million in generation expenses primarily related to scheduled outage and maintenance costs, $24 million in expenses at Southern Company Gas passed through directly to customers, primarily related to bad debt, $23 million in compensation and benefit expenses, and $8 million in amortization of cloud software.

Depreciation and Amortization

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$22	2.5	$43	2.4

In the second quarter 2022, depreciation and amortization was $913 million compared to $891 million for the corresponding period in 2021. For year-to-date 2022, depreciation and amortization was $1.81 billion compared to $1.76 billion for the corresponding period in 2021. The increases were primarily due to additional plant in service.

Taxes Other Than Income Taxes

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$36	11.5	$64	9.7

In the second quarter 2022, taxes other than income taxes were $349 million compared to $313 million for the corresponding period in 2021. For year-to-date 2022, taxes other than income taxes were $721 million compared to $657 million for the corresponding period in 2021. The increases primarily reflect an increase in revenue tax expenses as a result of higher natural gas revenues at Nicor Gas and an increase in municipal franchise fees related to higher retail revenues at Georgia Power.

Estimated Loss on Plant Vogtle Units 3 and 4

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$(408)	(88.7)	$(456)	(89.8)

In the second quarter 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 of $52 million and $460 million, respectively. For year-to-date 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 totaling $52 million and $508 million, respectively. The losses reflect revisions to the total project capital cost forecast to complete construction and start-up of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

Gain on Dispositions, Net

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$(1)	(9.1)	$(21)	(38.9)

For year-to-date 2022, gain on dispositions, net was $33 million compared to $54 million for the corresponding period in 2021. The decrease reflects a $39 million gain at Southern Power primarily from contributions of wind turbine equipment to various equity method investments in 2021, partially offset by a $17 million gain from sales of

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AND RESULTS OF OPERATIONS (Continued)

integrated transmission system assets at Georgia Power in 2022. See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Earnings (Loss) from Equity Method Investments

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$74	N/M	$75	N/M

N/M - Not meaningful

In the second quarter 2022, earnings from equity method investments were $34 million compared to a loss of $40 million for the corresponding period in 2021. For year-to-date 2022, earnings from equity method investments were $80 million compared to $5 million for the corresponding period in 2021. The increases were primarily due to a pre-tax impairment charge of $82 million in the second quarter 2021 related to the PennEast Pipeline project at Southern Company Gas. 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 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$38	8.4	$49	5.4

In the second quarter 2022, interest expense, net of amounts capitalized was $488 million compared to $450 million for the corresponding period in 2021. The increase was primarily due to higher average outstanding borrowings.

For year-to-date 2022, interest expense, net of amounts capitalized was $950 million compared to $901 million for the corresponding period in 2021. The increase was primarily due to higher average outstanding borrowings, partially offset by lower interest rates on newly issued debt relative to the debt that was retired since the second quarter 2021.

See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.

Other Income (Expense), Net

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$38	37.6	$123	76.9

In the second quarter 2022, other income (expense), net was $139 million compared to $101 million for the corresponding period in 2021. The increase was primarily due to charitable contributions of $26 million at Southern Company Gas in the second quarter 2021 and a $16 million increase in non-service cost-related retirement benefits income.

For year-to-date 2022, other income (expense), net was $283 million compared to $160 million for the corresponding period in 2021. The increase was primarily due to charitable contributions of $101 million at Southern Company Gas for year-to-date 2021 and a $30 million increase in non-service cost-related retirement benefits income.

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

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Income Taxes (Benefit)

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$316	N/M	$299	N/M

N/M - Not meaningful

In the second quarter 2022, income tax expense was $304 million compared to income tax benefit of $12 million for the corresponding period in 2021. For year-to-date 2022, income taxes were $477 million compared to $178 million for the corresponding period in 2021. The increases were primarily due to an increase in pre-tax earnings and an adjustment in the second quarter 2022 related to a prior year state tax credit carryforward at Georgia Power. See Note (G) to the Condensed Financial Statements herein for additional information.

Net Loss Attributable to Noncontrolling Interests

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$22	N/M	$34	N/M

N/M - Not meaningful

Substantially all noncontrolling interests relate to renewable projects at Southern Power. In the second quarter 2022, net loss attributable to noncontrolling interests was $22 million compared to an immaterial loss for the corresponding period in 2021. For year-to-date 2022, net loss attributable to noncontrolling interests was $67 million compared to $33 million for the corresponding period in 2021. The increased losses attributable to noncontrolling interests were primarily due to higher HLBV loss allocations to Southern Power's tax equity partners, partially offset by higher income allocations to Southern Power's equity partners.

Alabama Power

Net Income

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$52	15.7	$40	5.8

Alabama Power's net income after dividends on preferred stock in the second quarter 2022 was $383 million compared to $331 million for the corresponding period in 2021. Alabama Power's net income after dividends on preferred stock for year-to-date 2022 was $730 million compared to $690 million for the corresponding period in 2021. These increases were primarily due to an increase in retail revenues associated with warmer weather in Alabama Power's service territory in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 and sales growth, partially offset by an increase in operations and maintenance expenses.

Retail Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$275	20.3	$302	11.2

In the second quarter 2022, retail revenues were $1.63 billion compared to $1.35 billion for the corresponding period in 2021. For year-to-date 2022, retail revenues were $3.01 billion compared to $2.71 billion for the corresponding period in 2021.

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AND RESULTS OF OPERATIONS (Continued)

Details of the changes in retail revenues were as follows:

	Second Quarter 2022				Year-To-Date 2022
	(in millions)		(% change)		(in millions)		(% change)
Retail – prior year	$	1,354			$	2,706
Estimated change resulting from –
Rates and pricing	4		0.3	%	3		0.1	%
Sales growth	19		1.4		34		1.3
Weather	63		4.6		64		2.4
Fuel and other cost recovery	189		14.0		201		7.4
Retail – current year	$	1,629	20.3	%	$	3,008	11.2	%

Revenues attributable to changes in sales increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales decreased 1.4% and 0.3% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to decreased customer usage. Weather-adjusted commercial KWH sales decreased 0.2% in the second quarter 2022 when compared to the corresponding period in 2021 primarily due to decreased customer usage. Weather-adjusted commercial KWH sales increased 0.4% for year-to-date 2022 when compared to the corresponding period in 2021 primarily due to customer growth. Industrial KWH sales increased 3.9% and 2.0% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to increases in the pipeline, mining, and pulp and paper sectors, partially offset by decreases in the chemicals sector.

Fuel and other cost recovery revenues increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021 primarily due to increases in the volume of KWHs generated and the average cost of fuel.

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 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$74	87.1	$94	52.8

In the second quarter 2022, wholesale revenues from sales to non-affiliates were $159 million compared to $85 million for the corresponding period in 2021. For year-to-date 2022, wholesale revenues from sales to non-affiliates were $272 million compared to $178 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of 41.8% and 27.3%, respectively, in KWH sales as a result of increased opportunity sales due to warmer weather in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021, as well as increases of 31.4% and 20.5%, respectively, in the price of energy due to higher natural gas prices.

Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Alabama Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not affect net income. Short-term opportunity energy sales are also included in wholesale energy sales to non-affiliates. These opportunity sales are made at market-based rates that generally provide a margin above Alabama Power's variable cost to produce the energy.

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AND RESULTS OF OPERATIONS (Continued)

Wholesale Revenues – Affiliates

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$10	41.7	$45	81.8

In the second quarter 2022, wholesale revenues from sales to affiliates were $34 million compared to $24 million for the corresponding period in 2021. The increase was primarily due to a 154.8% increase in the price of energy due to higher natural gas prices, partially offset by a 42.5% decrease in KWH sales due to lower cost system resources compared to Alabama Power's generation.

For year-to-date 2022, wholesale revenues from sales to affiliates were $100 million compared to $55 million for the corresponding period in 2021. The increase was primarily due to a 72.1% increase in the price of energy due to higher natural gas prices and a 5.1% increase in KWH sales due to lower cost resources as compared to available affiliate company generation.

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. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost and energy purchases are generally offset by energy revenues through Alabama Power's energy cost recovery clause.

Other Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$16	17.2	$24	13.6

In the second quarter 2022, other revenues were $109 million compared to $93 million for the corresponding period in 2021. For year-to-date 2022, other revenues were $200 million compared to $176 million for the corresponding period in 2021. The second quarter and year-to-date 2022 increases were primarily due to increases of $5 million and $8 million, respectively, in cogeneration steam revenue associated with higher natural gas prices, $4 million and $7 million, respectively, in transmission revenues, and $3 million and $4 million, respectively, in rent revenues.

Fuel and Purchased Power Expenses

	Second Quarter 2022 vs. Second Quarter 2021			Year-To-Date 2022 vs. Year-To-Date 2021
	(change in millions)		(% change)	(change in millions)		(% change)
Fuel	$	138	52.5	$	179	32.3
Purchased power – non-affiliates	47		97.9	65		67.0
Purchased power – affiliates	82		210.3	78		113.0
Total fuel and purchased power expenses	$	267		$	322

In the second quarter 2022, total fuel and purchased power expenses were $617 million compared to $350 million for the corresponding period in 2021. The increase was primarily due to a $199 million increase in the cost of fuel and purchased power and a $67 million increase related to the volume of KWHs generated and purchased.

For year-to-date 2022, total fuel and purchased power expenses were $1.04 billion compared to $720 million for the corresponding period in 2021. The increase was primarily due to a $235 million increase in the cost of fuel and purchased power and an $87 million increase related to the volume of KWHs generated and purchased.

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AND RESULTS OF OPERATIONS (Continued)

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.

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

	Second Quarter 2022	Second Quarter 2021	Year-To-Date 2022	Year-To-Date 2021
Total generation (in billions of KWHs)(a)	13	13	29	28
Total purchased power (in billions of KWHs)	3	2	4	3
Sources of generation (percent)(a) —
Coal	45	43	44	45
Nuclear	25	25	25	25
Gas	22	22	20	20
Hydro	8	10	11	10
Cost of fuel, generated (in cents per net KWH) —
Coal	3.35	2.73	3.11	2.74
Nuclear	0.67	0.69	0.67	0.71
Gas(a)	4.88	2.47	4.17	2.49
Average cost of fuel, generated (in cents per net KWH)(a)	2.98	2.10	2.66	2.12
Average cost of purchased power (in cents per net KWH)(b)	8.88	5.57	8.12	5.99

(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel as its fuel is provided by the purchaser under a power sales agreement. See Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

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

Fuel

In the second quarter 2022, fuel expense was $401 million compared to $263 million for the corresponding period in 2021. The increase was primarily due to a 97.6% increase in the average cost of natural gas per KWH generated, which excludes tolling agreements, a 22.7% increase in the average cost of coal per KWH generated, a 5.2% increase in the volume of KWHs generated by coal, and a 24.7% decrease in the volume of KWHs generated by hydro facilities as a result of less rainfall in the second quarter 2022 compared to the corresponding period in 2021.

For year-to-date 2022, fuel expense was $733 million compared to $554 million for the corresponding period in 2021. The increase was primarily due to a 67.5% increase in the average cost of natural gas per KWH generated, which excludes tolling agreements, and a 13.5% increase in the average cost of coal per KWH generated, partially offset by a 12.7% increase in the volume of KWHs generated by hydro facilities as a result of more rainfall for year-to-date 2022 compared to the corresponding period in 2021.

Purchased Power – Non-Affiliates

In the second quarter 2022, purchased power expense from non-affiliates was $95 million compared to $48 million for the corresponding period in 2021. The increase was primarily due to a 67.4% increase in the volume of KWHs purchased as a result of warmer weather in the second quarter 2022 compared to the corresponding period in 2021, as well as a 32.6% increase in the average cost per KWH purchased due to higher natural gas and coal prices.

For year-to-date 2022, purchased power expense from non-affiliates was $162 million compared to $97 million for the corresponding period in 2021. The increase was primarily due to a 48.1% increase in the volume of KWHs purchased as a result of warmer weather for year-to-date 2022 compared to the corresponding period in 2021, as well as a 22.5% increase in the average cost per KWH purchased due to higher natural gas and coal prices.

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AND RESULTS OF OPERATIONS (Continued)

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.

Purchased Power – Affiliates

In the second quarter 2022, purchased power expense from affiliates was $121 million compared to $39 million for the corresponding period in 2021. The increase was primarily due to a 102.3% increase in the average cost per KWH purchased due to higher natural gas and coal prices and a 54.4% increase in the volume of KWHs purchased as a result of warmer weather in the second quarter 2022 compared to the corresponding period in 2021.

For year-to-date 2022, purchased power expense from affiliates was $147 million compared to $69 million for the corresponding period in 2021. The increase was primarily due to a 61.5% increase in the average cost per KWH purchased due to higher natural gas and coal prices and a 32.1% increase in the volume of KWHs purchased as a result of warmer weather for year-to-date 2022 compared to the corresponding period in 2021.

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.

Other Operations and Maintenance Expenses

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$28	6.8	$77	9.9

In the second quarter 2022, other operations and maintenance expenses were $441 million compared to $413 million for the corresponding period in 2021. For year-to-date 2022, other operations and maintenance expenses were $852 million compared to $775 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of $11 million and $39 million, respectively, in generation expenses associated with scheduled outages and maintenance and Rate CNP Compliance-related expenses, $9 million and $23 million, respectively, in transmission and distribution expenses primarily associated with line maintenance, and $3 million and $6 million, respectively, in customer service and sales expenses primarily associated with contract services. See Note 2 to the financial statements under "Alabama Power – Rate CNP Compliance" in Item 8 of the Form 10-K for additional information.

Interest Expense, Net of Amounts Capitalized

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$7	8.3	$12	7.1

For year-to-date 2022, interest expense, net of amounts capitalized was $180 million compared to $168 million for the corresponding period in 2021. The increase was primarily due to an increase associated with higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.

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AND RESULTS OF OPERATIONS (Continued)

Income Taxes

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$17	16.3	$14	6.6

In the second quarter 2022, income taxes were $121 million compared to $104 million for the corresponding period in 2021. For year-to-date 2022, income taxes were $227 million compared to $213 million for the corresponding period in 2021. The increases were primarily due to higher pre-tax earnings.

Georgia Power

Net Income

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$465	325.2	$499	101.0

Georgia Power's net income in the second quarter 2022 was $608 million compared to $143 million for the corresponding period in 2021. For year-to-date 2022 net income was $1.0 billion compared to $0.5 billion for the corresponding period in 2021. The increases were primarily due to increases in retail revenues associated with rates and pricing and warmer weather in Georgia Power's service territory in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 and decreases of $304 million and $340 million in the second quarter and year-to-date 2022, respectively, in after-tax charges related to the construction of Plant Vogtle Units 3 and 4, partially offset by higher non-fuel operations and maintenance costs.

See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information regarding Plant Vogtle Units 3 and 4.

Retail Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$882	43.5	$1,113	29.2

In the second quarter 2022, retail revenues were $2.91 billion compared to $2.03 billion for the corresponding period in 2021. For year-to-date 2022, retail revenues were $4.93 billion compared to $3.81 billion for the corresponding period in 2021.

Details of the changes in retail revenues were as follows:

	Second Quarter 2022				Year-To-Date 2022
	(in millions)		(% change)		(in millions)		(% change)
Retail – prior year	$	2,026			$	3,813
Estimated change resulting from –
Rates and pricing	231		11.4	%	285		7.5	%
Sales growth	45		2.2		47		1.2
Weather	72		3.5		91		2.4
Fuel cost recovery	534		26.4		690		18.1
Retail – current year	$	2,908	43.5	%	$	4,926	29.2	%

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AND RESULTS OF OPERATIONS (Continued)

Revenues associated with changes in rates and pricing increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. The increases were primarily due to higher contributions from commercial and industrial customers with variable demand-driven pricing, base tariff increases in accordance with the 2019 ARP, and pricing effects associated with residential customer usage. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales increased 2.6% in the second quarter 2022 and were flat year-to-date 2022 and weather-adjusted commercial KWH sales increased 3.2% and 2.7% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to the impacts on customer usage from increased activity outside the home following the expiration of COVID-19 restrictions and customer growth. Weather-adjusted industrial KWH sales increased 3.1% and 3.3% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 primarily due to increases in the paper and pipeline sectors, partially offset by a decrease in the chemicals sector.

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 2022 when compared to the corresponding periods in 2021 due to higher fuel and purchased power 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 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information.

Wholesale Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$28	77.8	$50	62.5

In the second quarter 2022, wholesale revenues were $64 million compared to $36 million for the corresponding period in 2021. For year-to-date 2022, wholesale revenues were $130 million compared to $80 million for the corresponding period in 2021. The increases were primarily due to increases of $28 million and $46 million in the second quarter and year-to-date 2022, respectively, related to the average cost of fuel primarily due to higher natural gas and coal prices. Also contributing to the increase for year-to-date 2022 was a $6 million increase in KWH sales associated with higher market demand.

Wholesale revenues from sales to non-affiliates consist of PPAs and short-term opportunity sales. Wholesale revenues from PPAs have both capacity and energy components. Wholesale capacity revenues from PPAs are recognized in amounts billable under the contract terms and provide for recovery of fixed costs and a return on investment. Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Georgia Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Short-term opportunity sales are made at market-based rates that generally provide a margin above Georgia Power's variable cost of energy.

Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost.

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AND RESULTS OF OPERATIONS (Continued)

Other Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$(14)	(8.6)	$(30)	(9.9)

In the second quarter 2022, other revenues were $149 million compared to $163 million for the corresponding period in 2021. For year-to-date 2022, other revenues were $272 million compared to $302 million for the corresponding period in 2021. The decreases for the second quarter and year-to-date 2022 were primarily due to decreases of $12 million and $20 million, respectively, resulting from the termination of a transmission service contract and net decreases of $8 million and $15 million, respectively, in unregulated sales primarily due to the timing of revenue recognition for a large, ongoing power delivery construction and maintenance contract, partially offset by increases associated with more energy conservation projects performed in 2022 and outdoor lighting sales growth. The decreases were also partially offset by increases of $9 million and $10 million, respectively, in open access transmission tariff sales.

Fuel and Purchased Power Expenses

	Second Quarter 2022 vs. Second Quarter 2021			Year-to-Date 2022 vs. Year-to-Date 2021
	(change in millions)		(% change)	(change in millions)		(% change)
Fuel	$	285	83.1	$	390	59.5
Purchased power – non-affiliates	102		70.8	108		37.5
Purchased power – affiliates	174		116.8	244		85.6
Total fuel and purchased power expenses	$	561		$	742

In the second quarter 2022, total fuel and purchased power expenses were $1.20 billion compared to $0.64 billion for the corresponding period in 2021. For year-to-date 2022, total fuel and purchased power expenses were $1.97 billion compared to $1.23 billion for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of $474 million and $609 million, respectively, related to the average cost of fuel and purchased power and increases of $87 million and $133 million, respectively, related to the volume of KWHs generated and purchased.

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.

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AND RESULTS OF OPERATIONS (Continued)

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

	Second Quarter 2022	Second Quarter 2021	Year-To-Date 2022	Year-To-Date 2021
Total generation (in billions of KWHs)	15	15	30	30
Total purchased power (in billions of KWHs)	8	7	16	14
Sources of generation (percent) —
Gas	45	46	45	47
Nuclear	27	28	25	27
Coal	24	22	25	22
Hydro and other	4	4	5	4
Cost of fuel, generated (in cents per net KWH) —
Gas	5.10	2.65	4.34	2.62
Coal	3.68	3.09	3.54	3.01
Nuclear	0.76	0.80	0.76	0.79
Average cost of fuel, generated (in cents per net KWH)	3.52	2.21	3.18	2.18
Average cost of purchased power (in cents per net KWH)(*)	8.22	4.77	6.58	4.49

(*)Average cost of purchased power includes fuel purchased by Georgia Power for tolling agreements where power is generated by the provider.

Fuel

In the second quarter 2022, fuel expense was $628 million compared to $343 million for the corresponding period in 2021. The increase was primarily due to increases of 92.5% and 19.1% in the average cost per KWH generated by natural gas and coal, respectively, and an 11.1% increase in the volume of KWHs generated by coal.

For year-to-date 2022, fuel expense was $1.05 billion compared to $0.66 billion for the corresponding period in 2021. The increase was primarily due to increases of 65.6% and 17.6% in the average cost per KWH generated by natural gas and coal, respectively, and a 15.2% increase in the volume of KWHs generated by coal.

Purchased Power – Non-Affiliates

In the second quarter 2022, purchased power expense from non-affiliates was $246 million compared to $144 million for the corresponding period in 2021. For year-to-date 2022, purchased power expense from non-affiliates was $396 million compared to $288 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of 73.9% and 32.7%, respectively, in the volume of KWHs purchased due to higher demand primarily driven by warmer weather in the second quarter 2022 and increases of 17.0% and 16.1%, respectively, in the average cost per KWH purchased primarily due to higher natural gas and coal prices.

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.

Purchased Power – Affiliates

In the second quarter 2022, purchased power expense from affiliates was $323 million compared to $149 million for the corresponding period in 2021. For year-to-date 2022, purchased power expense from affiliates was $529 million compared to $285 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of 127.0% and 74.3%, respectively, in the average cost per KWH purchased primarily due to higher natural gas and coal prices. The increase for year-to-date 2022 was also due to an

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AND RESULTS OF OPERATIONS (Continued)

increase of 9.9% in the volume of KWHs purchased due to lower cost Southern Company system resources as compared to available Georgia Power-owned generation.

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.

Other Operations and Maintenance Expenses

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$31	5.7	$76	7.5

In the second quarter 2022, other operations and maintenance expenses were $573 million compared to $542 million for the corresponding period in 2021. The increase was primarily due to increases of $14 million in transmission and distribution expenses primarily associated with line maintenance, $9 million associated with more unregulated energy conservation projects in 2022, $8 million in generation expenses primarily related to non-outage maintenance costs, $8 million in certain compensation and benefit expenses, $7 million in legal and regulatory expenses, and $4 million in amortization of cloud software, partially offset by a decrease of $16 million related to unregulated power delivery construction and maintenance projects.

For year-to-date 2022, other operations and maintenance expenses were $1.09 billion compared to $1.02 billion for the corresponding period in 2021. The increase was primarily due to increases of $49 million in transmission and distribution expenses primarily associated with line maintenance, $27 million in generation expenses primarily related to non-outage maintenance costs, $11 million in certain compensation and benefit expenses, $7 million in legal and regulatory expenses, and $5 million in amortization of cloud software, partially offset by a decrease of $26 million related to unregulated power delivery construction and maintenance projects and $17 million in gains from sales of integrated transmission system assets.

Depreciation and Amortization

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$14	4.1	$26	3.8

In the second quarter 2022, depreciation and amortization was $356 million compared to $342 million for the corresponding period in 2021. For year-to-date 2022, depreciation and amortization was $706 million compared to $680 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to additional plant in service and increases of $4 million and $6 million, respectively, in amortization of regulatory assets related to CCR AROs under the terms of the 2019 ARP. See Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Rate Plans – 2019 ARP" for additional information on recovery of CCR AROs.

Taxes Other Than Income Taxes

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$23	19.5	$30	12.8

In the second quarter 2022, taxes other than income taxes was $141 million compared to $118 million for the corresponding period in 2021. For year-to-date 2022, taxes other than income taxes was $265 million compared to $235 million for the corresponding period in 2021. The increases were primarily due to increases in municipal franchise fees largely related to higher retail revenues.

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AND RESULTS OF OPERATIONS (Continued)

Estimated Loss on Plant Vogtle Units 3 and 4

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$(408)	(88.7)	$(456)	(89.8)

In the second quarter 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 of $52 million and $460 million, respectively. For year-to-date 2022 and 2021, Georgia Power recorded estimated probable losses on Plant Vogtle Units 3 and 4 totaling $52 million and $508 million, respectively. The losses reflect revisions to the total project capital cost forecast to complete construction and start-up of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

Interest Expense, Net of Amounts Capitalized

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$11	10.4	$14	6.7

In the second quarter 2022, interest expense, net of amounts capitalized was $117 million compared to $106 million for the corresponding period in 2021. For year-to-date 2022, interest expense, net of amounts capitalized was $224 million compared to $210 million for the corresponding period in 2021. The increases were primarily associated with higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.

Other Income (Expense), Net

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$12	28.6	$20	24.1

In the second quarter 2022, other income (expense), net was $54 million compared to $42 million for the corresponding period in 2021. For year-to-date 2022, other income (expense), net was $103 million compared to $83 million for the corresponding period in 2021. The increases for the second quarter and year-to-date 2022 were primarily due to increases of $7 million and $10 million, respectively, in customer charges related to contributions in aid of construction and $4 million and $7 million, respectively, in non-service cost-related retirement benefits income. See Note (H) to the Condensed Financial Statements herein for additional information on retirement benefits.

Income Taxes (Benefit)

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$214	N/M	$226	N/M

N/M - Not meaningful

In the second quarter 2022, income tax expense was $164 million compared to income tax benefit of $50 million for the corresponding period in 2021. For year-to-date 2022, income tax expense was $194 million compared to income tax benefit of $32 million for the corresponding period in 2021. The increases were primarily due to a reduction in pre-tax earnings largely resulting from higher charges in the second quarter and year-to-date 2021 associated with the construction of Plant Vogtle Units 3 and 4 and an adjustment in the second quarter 2022 related to a prior year state tax credit carryforward. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial

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AND RESULTS OF OPERATIONS (Continued)

statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" and Note (G) to the Condensed Financial Statements herein for additional information.

Mississippi Power

Net Income

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$7	18.4	$4	4.8

Mississippi Power's net income in the second quarter 2022 was $45 million compared to $38 million for the corresponding period in 2021. For year-to-date 2022, net income was $87 million compared to $83 million for the corresponding period in 2021. The increases were primarily due to an increase in revenues, partially offset by an increase in operations and maintenance expenses. The year-to-date increase was also partially offset by an increase in income taxes.

Retail Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$33	15.1	$47	11.1

In the second quarter 2022, retail revenues were $252 million compared to $219 million for the corresponding period in 2021. For year-to-date 2022, retail revenues were $469 million compared to $422 million for the corresponding period in 2021.

Details of the changes in retail revenues were as follows:

	Second Quarter 2022				Year-To-Date 2022
	(in millions)		(% change)		(in millions)		(% change)
Retail – prior year	$	219			$	422
Estimated change resulting from –
Rates and pricing	2		0.9	%	5		1.2	%
Sales growth	2		0.9		4		0.9
Weather	9		4.1		7		1.7
Fuel and other cost recovery	20		9.1		31		7.3
Retail – current year	$	252	15.0	%	$	469	11.1	%

Revenues associated with changes in rates and pricing increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021 primarily due to new PEP rates that became effective for the first billing cycle of April 2022, partially offset by a decrease in revenues associated with a tolling arrangement. See Note 2 to the financial statements under "Mississippi Power – Performance Evaluation Plan" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. Weather-adjusted residential KWH sales decreased 0.4% in the second quarter 2022 when compared to the corresponding period in 2021 due to a decrease in customer usage. Weather-adjusted residential KWH sales increased 0.2% for year-to-date 2022 when compared to the corresponding period in 2021 due to customer growth. Weather-adjusted commercial KWH sales increased 1.2% and 2.0% in the second quarter and year-to-date 2022, respectively, when compared to the corresponding periods in 2021 due to customer growth. Industrial KWH sales increased 3.4% and 1.8% in the second quarter and year-to-date 2022, respectively, when

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compared to the corresponding periods in 2021 primarily due to increases in the petroleum, pipeline, and transportation sectors.

Fuel and other cost recovery revenues increased in the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021 primarily as a result of higher recoverable fuel costs. Recoverable fuel costs include fuel and purchased power expenses reduced by the fuel 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 and Note (B) to the Condensed Financial Statements herein under "Mississippi Power" for additional information.

Wholesale Revenues – Non-Affiliates

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$9	16.7	$14	12.0

In the second quarter 2022, wholesale revenues from sales to non-affiliates were $63 million compared to $54 million for the corresponding period in 2021. For year-to-date 2022, wholesale revenues from sales to non-affiliates were $131 million compared to $117 million for the corresponding period in 2021. The increases were primarily due to higher fuel costs and an increase in base revenue from MRA customers primarily due to warmer weather in 2022.

Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Mississippi Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. In addition, Mississippi Power provides service under long-term contracts with rural electric cooperative associations and municipalities located in southeastern Mississippi under cost-based electric tariffs which are subject to regulation by the FERC. See Note 2 to the financial statements under "Mississippi Power" in Item 8 of the Form 10-K for additional information. See Note (B) to the Condensed Financial Statements under "Mississippi Power – Municipal and Rural Associations Tariff" herein for additional information.

Wholesale Revenues – Affiliates

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$82	N/M	$92	N/M

N/M - Not meaningful

In the second quarter 2022, wholesale revenues from sales to affiliates were $107 million compared to $25 million for the corresponding period in 2021. The increase was primarily due to increases of $69 million associated with higher fuel prices, primarily driven by natural gas, and $13 million associated with higher KWH sales due to lower cost resources as compared to the available affiliate company generation.

For year-to-date 2022, wholesale revenues from sales to affiliates were $149 million compared to $57 million for the corresponding period in 2021. The increase was primarily due to increases of $84 million associated with higher fuel prices, primarily driven by natural gas, and $7 million associated with higher KWH sales due to lower cost resources as compared to the available affiliate company generation.

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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. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost.

Other Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$7	N/M	$6	42.9

N/M - Not meaningful

In the second quarter 2022, other revenues were $12 million compared to $5 million for the corresponding period in 2021. For year-to-date 2022, other revenues were $20 million compared to $14 million for the corresponding period in 2021. The increases were primarily due to a $5 million increase in unregulated sales associated with power delivery construction and maintenance projects and outdoor lighting.

Fuel and Purchased Power Expenses

	Second Quarter 2022 vs. Second Quarter 2021			Year-to-Date 2022 vs. Year-to-Date 2021
	(change in millions)		(% change)	(change in millions)		(% change)
Fuel	$	105	116.0	$	130	67.9
Purchased power	—		1.9	1		6.8
Total fuel and purchased power expenses	$	105		$	131

In the second quarter 2022, total fuel and purchased power expenses were $207 million compared to $102 million for the corresponding period in 2021. The increase was due to a $92 million increase in the average cost of fuel and purchased power and a $13 million net increase associated with the volume of KWHs generated and purchased.

For year-to-date 2022, total fuel and purchased power expenses were $339 million compared to $208 million for the corresponding period in 2021. The increase was primarily due to a $126 million increase in the average cost of fuel and purchased power and a $5 million net increase associated with the volume of KWHs generated and purchased.

Fuel and purchased power energy transactions do not have a significant impact on earnings since energy expenses are generally offset by energy revenues through Mississippi Power's fuel cost recovery clause.

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

	Second Quarter 2022	Second Quarter 2021	Year-To-Date 2022	Year-To-Date 2021
Total generation (in millions of KWHs)	4,483	3,813	8,557	8,137
Total purchased power (in millions of KWHs)	166	317	286	438
Sources of generation (percent) –
Gas	88	91	90	91
Coal	12	9	10	9
Cost of fuel, generated (in cents per net KWH) –
Gas	4.73	2.50	4.04	2.45
Coal	3.95	3.06	3.86	3.12
Average cost of fuel, generated (in cents per net KWH)	4.63	2.56	4.02	2.52
Average cost of purchased power (in cents per net KWH)	6.57	3.38	5.72	3.57

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Fuel

In the second quarter 2022, fuel expense was $196 million compared to $91 million for the corresponding period in 2021. The increase was due to an 89.2% increase in the average cost of natural gas per KWH generated, a 29.1% increase in the average cost of coal per KWHs generated, a 52.1% increase in the volume of KWHs generated by coal, and a 16.0% increase in the volume of KWHs generated by natural gas.

For year-to-date 2022, fuel expense was $322 million compared to $192 million for the corresponding period in 2021. The increase was due to a 64.9% increase in the average cost of natural gas per KWH generated, a 23.7% increase in the average cost of coal per KWHs generated, a 15.5% increase in the volume of KWHs generated by coal, and a 4.2% increase in the volume of KWHs generated by natural gas.

Other Operations and Maintenance Expenses

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$15	19.7	$23	16.0

In the second quarter 2022, other operations and maintenance expenses were $91 million compared to $76 million for the corresponding period in 2021. The increase was due to increases of $5 million related to unregulated construction and maintenance contracts, $3 million associated with storm reserve accruals, and $3 million in transmission and distribution expenses primarily associated with line maintenance.

For year-to-date 2022, other operations and maintenance expenses were $167 million compared to $144 million for the corresponding period in 2021. The increase was primarily due to increases of $6 million in transmission and distribution expenses primarily associated with line maintenance, $5 million related to unregulated construction and maintenance contracts, $4 million associated with storm reserve accruals, and $4 million associated with the Kemper County energy facility (primarily related to lower salvage proceeds in 2022 as compared to 2021).

See Note 2 to the financial statements in Item 8 of the Form 10-K under "Mississippi Power – System Restoration Rider" for additional information on storm reserve accruals.

Income Taxes

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$4	50.0	$8	66.7

For year-to-date 2022, income taxes were $20 million compared to $12 million for the corresponding period in 2021. A reduction in the flowback of excess deferred income taxes associated with new PEP rates that became effective in April 2022 contributed $5 million to the increase, which also reflects $3 million due to higher pre-tax earnings. See Note (G) to the Condensed Financial Statements herein for additional information.

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Southern Power

Net Income Attributable to Southern Power

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$62	172.2	$37	27.8

Net income attributable to Southern Power in the second quarter 2022 was $98 million compared to $36 million for the corresponding period in 2021. Net income attributable to Southern Power for year-to-date 2022 was $170 million compared to $133 million for the corresponding period in 2021.The increases were primarily due to higher revenues driven by higher market prices of energy and new natural gas PPAs, as well as higher HLBV income associated with tax equity partnerships. The year-to-date increase was partially offset by gains from the contributions of wind turbine equipment to various equity method investments in the first quarter 2021.

Operating Revenues

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$409	83.5	$508	54.6

Total operating revenues include PPA capacity revenues, which are derived primarily from long-term contracts involving natural gas facilities, and PPA energy revenues from 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.

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Operating Revenues Details

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

	Second Quarter 2022		Second Quarter 2021		Year-To-Date 2022		Year-To-Date 2021
	(in millions)
PPA capacity revenues	$	109	$	96	$	214	$	192
PPA energy revenues	579		296		921		541
Total PPA revenues	688		392		1,135		733
Non-PPA revenues	202		93		286		188
Other revenues	9		5		17		9
Total operating revenues	$	899	$	490	$	1,438	$	930

In the second quarter 2022, total operating revenues were $899 million, reflecting a $409 million, or 83%, increase from the corresponding period in 2021. The increase in operating revenues was primarily due to the following:

•PPA capacity revenues increased $13 million, or 14%, primarily due to new natural gas PPAs and increased capacity sales under existing natural gas PPAs, partially offset by the contractual expiration of natural gas PPAs.

•PPA energy revenues increased $283 million, or 96%, primarily due to a $212 million increase in sales under existing natural gas PPAs resulting from a $171 million increase in the price of fuel and purchased power and a $41 million increase in the volume of KWHs sold. Also contributing to the increase was a $77 million increase in sales associated with new natural gas PPAs.

•Non-PPA revenues increased $109 million, or 117%, primarily due to a $124 million increase in the market price of energy, partially offset by a $16 million decrease in the volume of KWHs sold through short-term sales.

For year-to-date 2022, total operating revenues were $1.4 billion, reflecting a $508 million, or 55%, increase from the corresponding period in 2021. The increase in operating revenues was primarily due to the following:

•PPA capacity revenues increased $22 million, or 11%, primarily due to new natural gas PPAs and increased capacity sales under existing natural gas PPAs, partially offset by the contractual expiration of natural gas PPAs.

•PPA energy revenues increased $380 million, or 70%, primarily due to a $271 million increase in sales under existing natural gas PPAs resulting from a $207 million increase in the price of fuel and purchased power and a $64 million increase in the volume of KWHs sold. Also contributing to the increase was a $124 million increase in sales associated with new natural gas PPAs, partially offset by a $17 million decrease due to the contractual expiration of natural gas PPAs.

•Non-PPA revenues increased $98 million, or 52%, primarily due to a $129 million increase in the market price of energy, partially offset by a $29 million decrease in the volume of KWHs sold through short-term sales.

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Fuel and Purchased Power Expenses

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

	Second Quarter 2022	Second Quarter 2021	Year-To-Date 2022	Year-To-Date 2021
	(in billions of KWHs)
Generation	12.8	10.3	23.9	19.7
Purchased power	0.7	0.7	1.1	1.3
Total generation and purchased power	13.5	11.0	25.0	21.0
Total generation and purchased power (excluding solar, wind, fuel cells, and tolling agreements)	7.5	6.3	14.4	12.4

Southern Power's PPAs for natural gas generation generally provide that the purchasers are responsible for either procuring the fuel (tolling agreements) or reimbursing Southern Power for substantially all of the cost of fuel relating to the energy delivered under such PPAs. Consequently, changes in such fuel costs are generally accompanied by a corresponding change in related fuel revenues and do not have a significant impact on net income. Southern Power is responsible for the cost of fuel for generating units that are not covered under PPAs. Power from these generating units is sold into the wholesale market or into the Southern Company power pool for capacity owned directly by Southern Power.

Purchased power expenses will vary depending on demand, availability, and the cost of generating resources throughout the Southern Company system and other contract resources. Load requirements are submitted to the Southern Company power pool on an hourly basis and are fulfilled with the lowest cost alternative, whether that is generation owned by Southern Power, an affiliate company, or external parties. Such purchased power costs are generally recovered through PPA revenues.

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

	Second Quarter 2022 vs. Second Quarter 2021			Year-to-Date 2022 vs. Year-to-Date 2021
	(change in millions)		(% change)	(change in millions)		(% change)
Fuel	$	297	212.1	$	388	138.1
Purchased power	43		172.0	43		93.5
Total fuel and purchased power expenses	$	340		$	431

In the second quarter 2022, total fuel and purchased power expenses increased $340 million, or 206%, compared to the corresponding period in 2021. Fuel expense increased $297 million due to a $266 million increase associated with the average cost of fuel and a $31 million increase associated with the volume of KWHs generated. Purchased power expense increased $43 million primarily due to an increase in the average cost of purchased power.

For year-to-date 2022, total fuel and purchased power expenses increased $431 million, or 132%, compared to the corresponding period in 2021. Fuel expense increased $388 million due to a $333 million increase associated with the average cost of fuel and a $55 million increase associated with the volume of KWHs generated. Purchased power expense increased $43 million primarily due to an increase in the average cost of purchased power.

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Gain on Dispositions, Net

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$—	—	$(37)	(94.9)

For year-to-date 2022, gain on dispositions, net was $2 million compared to $39 million for the corresponding period in 2021. The decrease primarily resulted from gains associated with contributions of wind turbine equipment to various equity method investments in the first quarter 2021. See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements under "Southern Power" herein for additional information.

Income Taxes (Benefit)

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$27	N/M	$24	N/M

N/M - Not meaningful

In the second quarter 2022, income tax expense was $25 million compared to a benefit of $2 million for the corresponding period in 2021. The change was primarily due to higher pre-tax earnings, partially offset by higher wind PTCs.

For year-to-date 2022, income tax expense was $13 million compared to a benefit of $11 million for the corresponding period in 2021. The change was primarily due to higher pre-tax earnings for year-to-date 2022 and a change in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in the first quarter 2021, partially offset by higher wind PTCs for year-to-date 2022.

Net Loss Attributable to Noncontrolling Interests

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$22	N/M	$34	103.0

N/M - Not meaningful

In the second quarter 2022, net loss attributable to noncontrolling interests was $22 million compared to an immaterial loss for the corresponding period in 2021. For year-to-date 2022, net loss attributable to noncontrolling interests was $67 million compared to $33 million for the corresponding period in 2021. The increased losses attributable to noncontrolling interests were primarily due to higher HLBV loss allocations to tax equity partners, partially offset by higher income allocations to equity partners.

Southern Company Gas

Operating Metrics

Southern Company Gas continues to focus on several operating metrics, including Heating Degree Days, customer count, and volumes of natural gas sold.

Southern Company Gas measures weather and the effect on its business using Heating Degree Days. Generally, increased Heating Degree Days result 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.

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The number of customers served by gas distribution operations and gas marketing services can be impacted by natural gas prices, economic conditions, and competition from alternative fuels. Gas distribution operations and gas marketing services' customers are primarily located in Georgia and Illinois.

Southern Company Gas' natural gas volume metrics for gas distribution operations and gas marketing services illustrate the effects of weather and customer demand for natural gas.

Seasonality of Results

During the Heating Season, natural gas usage and operating revenues are generally higher as more customers are connected to the gas distribution systems and natural gas usage is higher in periods of colder weather. Prior to the sale of Sequent on July 1, 2021, wholesale gas services' operating revenues occasionally were impacted due to peak usage by power generators in response to summer energy demands. Southern Company Gas' base operating expenses, excluding cost of natural gas, bad debt expense, and certain incentive compensation costs, 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.

Net Income

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$180	N/M	$100	30.0

N/M - Not meaningful

In the second quarter 2022, net income was $115 million compared to a net loss of $65 million for the corresponding period in 2021. The second quarter 2021 results include $112 million of net loss from Sequent, which was sold on July 1, 2021. Net income increased $59 million at gas pipeline investments primarily as a result of a 2021 impairment charge related to the PennEast pipeline project and $12 million at gas distribution operations primarily due to base rate increases and continued investment in infrastructure replacement.

For year-to-date 2022, net income was $433 million compared to $333 million for the corresponding period in 2021. Net income increased $59 million at gas pipeline investments as a result of a 2021 impairment charge related to the PennEast pipeline project, $43 million at gas distribution operations primarily due to base rate increases and continued investment in infrastructure replacement, and $5 million at gas marketing services primarily related to higher commodity prices and higher sales to commercial customers. The year-to-date 2021 results also included $14 million of net income from Sequent, which was sold on July 1, 2021.

See Notes 2, 7, and 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Natural Gas Revenues, including Alternative Revenue Programs

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$406	60.0	$769	32.4

In the second quarter 2022, natural gas revenues, including alternative revenue programs, were $1.1 billion compared to $677 million for the corresponding period in 2021. For year-to-date 2022, natural gas revenues, including alternative revenue programs, were $3.1 billion compared to $2.4 billion for the corresponding period in 2021.

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Details of the changes in natural gas revenues, including alternative revenue programs, were as follows:

	Second Quarter 2022				Year-To-Date 2022
	(in millions)		(% change)		(in millions)		(% change)
Natural gas revenues – prior year	$	677			$	2,371
Estimated change resulting from –
Infrastructure replacement programs and base rate changes	46		6.8	%	132		5.6	%
Gas costs and other cost recovery	239		35.3		783		33.0
Gas marketing services	(5)		(0.7)		13		0.5
Wholesale gas services	110		16.2		(187)		(7.9)
Other	16		2.4		28		1.2
Natural gas revenues – current year	$	1,083	60.0	%	$	3,140	32.4	%

Revenues from infrastructure replacement programs and base rate changes increased in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 primarily due to rate increases at Nicor Gas, Atlanta Gas Light, and Chattanooga Gas and continued investment in infrastructure replacement. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

Revenues associated with gas costs and other cost recovery increased in the second quarter and year-to-date 2022 compared to the corresponding periods in 2021 primarily due to higher volumes of natural gas sold and higher natural gas cost recovery. See "Cost of Natural Gas" herein for additional information. Revenue impacts from weather and customer growth are described further below.

Revenues from gas marketing services decreased in the second quarter 2022 compared to the corresponding period in 2021 due to unrealized hedge losses and warmer weather in the second quarter 2022. Revenues from gas marketing services increased for year-to-date 2022 compared to the corresponding period in 2021 due to higher commodity prices and higher sales to commercial customers.

The changes in revenues related to wholesale gas services were due to the sale of Sequent on July 1, 2021. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Southern Company Gas' natural gas distribution utilities have various regulatory mechanisms that limit their exposure to weather changes. Southern Company Gas also uses hedges for any remaining exposure to 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. The following table presents Heating Degree Days information for Illinois and Georgia, the primary locations where Southern Company Gas' operations are impacted by weather.

	Second Quarter			2022 vs. normal		2022 vs. 2021		Year-to-Date			2022 vs. normal		2022 vs. 2021
	Normal(*)	2022	2021	(warmer)		(warmer)		Normal(*)	2022	2021	colder (warmer)		colder (warmer)
	(in thousands)							(in thousands)
Illinois	645	620	634	(3.9)	%	(2.2)	%	3,644	3,627	3,580	(0.5)	%	1.3	%
Georgia	126	110	142	(12.7)	%	(22.5)	%	1,428	1,361	1,396	(4.7)	%	(2.5)	%

(*)Normal represents the 10-year average from January 1, 2012 through June 30, 2021 for Illinois at Chicago Midway International Airport and for Georgia at Atlanta Hartsfield-Jackson International Airport, based on information obtained from the National Oceanic and Atmospheric Administration, National Climatic Data Center.

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AND RESULTS OF OPERATIONS (Continued)

The following table provides the number of customers served by Southern Company Gas at June 30, 2022 and 2021:

	June 30,
	2022		2021		2022 vs. 2021
	(in thousands, except market share %)				(% change)
Gas distribution operations	4,314		4,300		0.3	%
Gas marketing services
Energy customers(*)	610		612		(0.3)	%
Market share of energy customers in Georgia	28.6	%	29.1	%

(*)Gas marketing services' customers are primarily located in Georgia and Illinois.

Southern Company Gas anticipates customer growth and uses a variety of targeted marketing programs to attract new customers and to retain existing customers.

Cost of Natural Gas

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$221	95.7	$732	89.9

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 88% and 89% of the total cost of natural gas in the second quarter and year-to-date 2022, 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, including Alternative Revenue Programs" herein for additional information.

In the second quarter 2022, cost of natural gas was $452 million compared to $231 million for the corresponding period in 2021. For year-to-date 2022, cost of natural gas was $1.5 billion compared to $814 million for the corresponding period in 2021. The increases reflect higher gas cost recovery as a result of increases of 153.2% and 119.4% in natural gas prices in the second quarter and year-to-date 2022, respectively, compared to the corresponding periods in 2021.

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

	Second Quarter		2022 vs. 2021		Year-to-Date		2022 vs. 2021
	2022	2021			2022	2021
Gas distribution operations (mmBtu in millions)
Firm	111	103	7.8	%	415	391	6.1	%
Interruptible	22	23	(4.3)		47	50	(6.0)
Total	133	126	5.6	%	462	441	4.8	%
Wholesale gas services (mmBtu in millions/day)
Daily physical sales(*)	—	6.1	(100.0)	%	—	6.6	(100.0)	%
Gas marketing services (mmBtu in millions)
Firm:
Georgia	5	4	25.0	%	21	23	(8.7)	%
Illinois	1	1	—		4	5	(20.0)
Other	3	2	50.0		7	8	(12.5)
Interruptible large commercial and industrial	3	3	—		7	7	—
Total	12	10	20.0	%	39	43	(9.3)	%

(*)As a result of the sale of Sequent, wholesale gas services had no sales in the second quarter and year-to-date 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Other Operations and Maintenance Expenses

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$33	14.2	$38	7.1

In the second quarter 2022, other operations and maintenance expenses were $266 million compared to $233 million for the corresponding period in 2021. Other operations and maintenance expenses increased approximately $37 million excluding expenses related to Sequent in the second quarter 2021. The increase was primarily due to higher compensation and benefit expenses and higher expenses passed through directly to customers primarily related to bad debt at gas distribution operations.

For year-to-date 2022, other operations and maintenance expenses were $570 million compared to $532 million for the corresponding period in 2021. Excluding $53 million of expenses related to Sequent for year-to-date 2021, other operations and maintenance expenses increased approximately $91 million. The increase was primarily due to increases of $33 million in compensation and benefit expenses, $24 million in expenses passed through directly to customers primarily related to bad debt at gas distribution operations, $16 million in technology-related costs, $8 million in customer accounts expenses, and $7 million in expenses primarily related to higher fuel costs.

Depreciation and Amortization

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$5	3.8	$12	4.6

For year-to-date 2022, depreciation and amortization was $275 million compared to $263 million for the corresponding period in 2021. The increase was primarily due to continued infrastructure investments at the natural gas distribution utilities.

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Taxes Other Than Income Taxes

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$13	26.5	$33	25.4

In the second quarter 2022, taxes other than income taxes were $62 million compared to $49 million for the corresponding period in 2021. For year-to-date 2022, taxes other than income taxes were $163 million compared to $130 million for the corresponding period in 2021. The increases primarily reflect an increase in revenue tax expenses as a result of higher natural gas revenues at Nicor Gas. These revenue tax expenses are passed directly to customers and have no impact on net income.

Earnings (Loss) from Equity Method Investments

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$83	159.6	$82	N/M

N/M - Not meaningful

In the second quarter 2022, earnings from equity method investments were $31 million compared to a loss of $52 million for the corresponding period in 2021. For year-to-date 2022, earnings from equity method investments were $71 million compared to a loss of $11 million for the corresponding period in 2021. The changes were primarily due to a pre-tax impairment charge of $82 million recorded in the second quarter 2021 related to the PennEast Pipeline project. 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.

Other Income (Expense), Net

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$30	214.3	$110	141.0

In the second quarter 2022, other income (expense), net was $16 million of income compared to $14 million of expense for the corresponding period in 2021. For year-to-date 2022, other income (expense), net was $32 million of income compared to $78 million of expense for the corresponding period in 2021. The changes were largely due to charitable contributions of $26 million and $101 million in the second quarter and year-to-date 2021, respectively.

Income Taxes (Benefit)

Second Quarter 2022 vs. Second Quarter 2021		Year-To-Date 2022 vs. Year-To-Date 2021
(change in millions)	(% change)	(change in millions)	(% change)
$65	224.1	$42	45.7

In the second quarter 2022, income tax expense was $36 million compared to income tax benefit of $29 million for the corresponding period in 2021. The change was primarily due to the pre-tax impairment charge at gas pipeline investments in 2021 related to the PennEast Pipeline project, a pre-tax loss at wholesale gas services in the second quarter 2021, and higher pre-tax earnings primarily at gas distribution operations.

For year-to-date 2022, income taxes were $134 million compared to $92 million for the corresponding period in 2021. The increase was primarily due to the pre-tax impairment charge at gas pipeline investments in 2021 related to the PennEast Pipeline project and higher pre-tax earnings primarily at gas distribution operations.

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See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information on the impairment charge related to the PennEast Pipeline project.

Segment Information

Operating revenues, operating expenses, and net income (loss) 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.

	2022						2021
	Operating Revenues		Operating Expenses		Net Income (Loss)		Operating Revenues		Operating Expenses		Net Income (Loss)
	(in millions)						(in millions)
Second Quarter
Gas distribution operations	$	980	$	819	$	92	$	710	$	564	$	80
Gas pipeline investments	8		2		23		8		3		(36)
Wholesale gas services(*)	—		—		—		(110)		11		(112)
Gas marketing services	92		90		1		64		54		6
All other	10		14		(1)		11		20		(3)
Intercompany eliminations	(7)		(7)		—		(6)		(6)		—
Consolidated	$	1,083	$	918	$	115	$	677	$	646	$	(65)
Year-to-Date
Gas distribution operations	$	2,782	$	2,293	$	306	$	1,910	$	1,477	$	263
Gas pipeline investments	16		5		52		16		6		(7)
Wholesale gas services(*)	—		—		—		188		67		14
Gas marketing services	335		240		67		259		174		62
All other	26		35		8		18		35		1
Intercompany eliminations	(19)		(19)		—		(20)		(20)		—
Consolidated	$	3,140	$	2,554	$	433	$	2,371	$	1,739	$	333

(*)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the second quarter and year-to-date 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Gas Distribution Operations

Gas distribution operations 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.

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In the second quarter and year-to-date 2022, net income increased $12 million, or 15.0%, and $43 million, or 16.3%, respectively, when compared to the corresponding periods in 2021, as described further below:

•Operating revenues increased $270 million and $872 million, respectively, when compared to the corresponding periods in 2021 primarily due to higher gas cost recovery, rate increases, and continued investment in infrastructure replacement. Gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas.

•Operating expenses increased $255 million and $816 million, respectively, when compared to the corresponding periods in 2021 primarily due to increases of $195 million and $673 million, respectively, in the cost of gas as a result of higher natural gas prices and higher volumes sold compared to 2021, higher compensation expenses, and higher depreciation resulting from additional assets placed in service. The increase in operating expenses also includes higher costs passed through directly to customers, primarily related to bad debt expenses and revenue taxes.

•Other income and (expense) increased $4 million and $9 million, respectively, when compared to the corresponding periods in 2021, primarily due to an increase in non-service cost-related retirement benefits income. See Note (H) to the Condensed Financial Statements herein for additional information.

•Interest expense, net of amounts capitalized increased $3 million and $6 million, respectively, when compared to the corresponding periods in 2021 primarily due to additional debt issued to finance continued investments. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.

•Income taxes increased $4 million and $16 million, respectively, when compared to the corresponding periods in 2021 primarily due to higher pre-tax earnings.

Gas Pipeline Investments

Gas pipeline investments consists primarily of joint ventures in natural gas pipeline investments including SNG, Dalton Pipeline, and PennEast Pipeline. See Note (E) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information.

Net income increased $59 million for both the second quarter and year-to-date 2022 when compared to the corresponding periods in 2021. The increases were primarily due to a pre-tax impairment charge of $82 million ($58 million after tax) in the second quarter 2021 related to the equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Gas Marketing Services

Gas marketing services provides energy-related products and services to natural gas markets and participants in customer choice programs that were approved in various states to increase competition. These programs allow customers to choose their natural gas supplier while the local distribution utility continues to provide distribution and transportation services. Gas marketing services is weather sensitive and uses a variety of hedging strategies, such as weather derivative instruments and other risk management tools, to partially mitigate potential weather impacts.

In the second quarter 2022, net income decreased $5 million, or 83.3%, when compared to the corresponding period in 2021. The decrease was primarily due to an increase of $36 million in operating expenses primarily due to $32 million in higher cost of gas, largely offset by a related increase of $28 million in operating revenues.

For year-to-date 2022, net income increased $5 million, or 8.1%, when compared to the corresponding period in 2021. The increase was primarily due to a $76 million increase in operating revenues as a result of higher commodity prices and higher sales to commercial customers, partially offset by a $66 million increase in operating expenses primarily due to higher cost of natural gas and an increase of $5 million in income taxes as a result of higher pre-tax earnings.

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All Other

All other includes natural gas storage businesses, 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.

For year-to-date 2022, net income increased $7 million when compared to the corresponding period in 2021. Operating revenues increased $8 million primarily related to higher demand fees and favorable hedge gains at the natural gas storage businesses and higher sales from the renewable natural gas business.

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.

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 and expanding and improving the transmission and distribution systems; continued customer growth; and the trends of higher inflation and reduced electricity usage per customer, especially in residential and commercial markets. For Georgia Power, completing construction of Plant Vogtle Units 3 and 4 and the related cost recovery proceedings is another major factor.

Earnings in the electricity business will also depend upon maintaining and growing sales, considering, among other things, the adoption and/or penetration rates of increasingly energy-efficient technologies and increasing volumes of electronic commerce transactions, which could contribute to a net reduction in customer usage.

Global and U.S. economic conditions have been significantly affected by a series of demand and supply shocks that caused a global and national economic recession in 2020. The drivers, speed, and depth of the 2020 economic contraction were unprecedented and continue to reduce energy demand across the Southern Company system's service territory, primarily in the commercial class. Retail electric revenues attributable to changes in sales increased in the first half of 2022 when compared to the corresponding period in 2021 primarily due to the normalization of economic activity; however, total retail electric sales for the Southern Company system continued to be negatively impacted by the COVID-19 pandemic when compared to pre-pandemic trends. Most prominently, the COVID-19 pandemic has negatively impacted global supply chains and business operations as suppliers continue to experience difficulties keeping up with strong demand for factory goods, which is being driven by low business inventories. In addition, rising inflation in 2021 and 2022 has resulted in increasing costs for many goods and services. As a result of persistently high inflation, interest rates have been on the rise and are expected to continue rising in the near term. Based on these factors, the probability of the U.S. economy falling into a recession has heightened. The impacts of new COVID-19 variants, responses to the COVID-19 pandemic by both customers and governments, ongoing geopolitical threats, such as the escalation of the Russia-Ukraine war, and the potential of future COVID-19-related lockdowns in Asian markets or elsewhere could further disrupt global supply chains and increase the severity of a possible economic downturn in the Southern Company system's service territory. See RESULTS OF OPERATIONS herein for information on COVID-19-related impacts on energy demand in the Southern Company system's service territory during the first half of 2022.

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 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; availability of federal and state ITCs

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and PTCs, which could be impacted by future tax legislation; transmission constraints; cost of generation from units within the Southern Company power pool; and operational limitations.

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; certain policies to limit the use of natural gas, such as the potential across certain parts of the U.S. for state or municipal bans on the use of natural gas; and Southern Company Gas' ability to re-contract storage rates at favorable prices. 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 have recently resulted 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.

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; energy conservation practiced by customers; the use of alternative energy sources by customers; government incentives to reduce overall energy usage; the prices of electricity and natural gas; costs and availability of labor and materials in a time of rising costs, impacted by heightened inflation caused by unprecedented shocks to the broader economy, and 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, 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 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 and Note (K) to the Condensed Financial Statements 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" in Item 7 and Note 3 to the financial statements under "Environmental Remediation" in Item 8 of the Form 10-K, as well as Note (C) to the Condensed Financial Statements under "Environmental Remediation" herein, for additional information.

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Environmental Laws and Regulations

Coal Combustion Residuals

On July 20, 2022, Mobile Baykeeper, through its counsel Southern Environmental Law Center, released an advance notice of intent to sue Alabama Power for alleged violations of the Resource Conservation and Recovery Act (RCRA) and regulations governing CCR. Mobile Baykeeper claims that Alabama Power's plan to close the Plant Barry ash pond under the closure-in-place methodology violates regulations governing CCR and the RCRA. Under the RCRA, Mobile Baykeeper is required to give Alabama Power advance notice of intent at least 60 days before filing suit. See Note 6 to the financial statements in Item 8 of the Form 10-K for a discussion of Alabama Power's ARO liabilities related to facilities that are subject to the CCR Rule and the related state rule. The ultimate outcome of this matter cannot be determined at this time.

Global Climate Issues

On June 30, 2022, the U.S. Supreme Court issued an opinion limiting the EPA's authority to regulate greenhouse gas emissions under the Clean Air Act. The Court's review in the case focused on whether the EPA's authority under the Clean Air Act allows the EPA to regulate the electric industry in a manner as broad as the Clean Power Plan (CPP), which was repealed and replaced by the Affordable Clean Energy rule (ACE Rule). The Court held that the generation shifting to lower carbon emitting sources approach in the CPP is not authorized by the Clean Air Act. However, the Court did not decide whether the EPA may adopt measures only applied at the individual electric generating source, which is the basis for the ACE Rule. The EPA has announced its intent to propose a rule for existing power plants pursuant to the Clean Air Act by March 2023. The ultimate impact of the Court's decision 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 Subsidiary Registrants are engaged in continuous construction programs to accommodate existing and estimated future loads on their respective systems. 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.

For the traditional electric operating companies, major generation construction projects are subject to state PSC approval in order to be included in retail rates. The largest construction project currently underway in the Southern Company system is Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information. Also see Note 2 to the financial statements under "Alabama Power – Certificates of Convenience and Necessity" in Item 8 of the Form 10-K for information regarding Alabama Power's construction of Plant Barry Unit 8.

See Note 15 to the financial statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein under "Southern Power" for information about costs 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 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. See Note 2 to the financial statements in

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Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Southern Company Gas" 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.

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.

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.

Estimated Cost, Schedule, and Rate Recovery for the Construction of Plant Vogtle Units 3 and 4

(Southern Company and Georgia Power)

As of June 30, 2022, Georgia Power revised its total project capital cost forecast to $10.5 billion (net of $1.7 billion received under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds). This forecast includes construction contingency of $60 million and is based on projected in-service dates at the end of the first quarter 2023 and the fourth quarter 2023 for Units 3 and 4, respectively.

The projected schedule for Unit 3 primarily depends on the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. Unit 4's projected schedule primarily depends on Unit 3 progress through fuel load, startup, and testing; overall construction productivity and production levels improving, particularly in electrical installation, including terminations; and appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates and cost increases.

During the first half of 2022, established construction contingency totaling $126 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, additional craft and support resources, and procurement for Units 3 and 4. Georgia Power also increased its total project capital cost forecast as of June 30, 2022 and recorded a pre-tax charge of $36 million ($27 million after tax) to replenish construction contingency.

Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments (as defined in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction – Joint Owner Contracts"

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herein) or the extent to which COVID-19-related costs impact those provisions. Georgia Power recorded an additional pre-tax charge to income in the second quarter 2022 of approximately $16 million ($12 million after tax) associated with these cost-sharing and tender provisions, which is included in the total project capital cost forecast. Georgia Power may be required to record further pre-tax charges to income of up to approximately $480 million associated with these provisions based on the current project capital cost forecast. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement, which was modified on June 3, 2022, to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 194 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022, and would require the other Vogtle Owners to notify Georgia Power of their intent to exercise their tender options by August 27, 2022. On June 17, 2022 and July 26, 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options.

The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein, is estimated to result in additional base capital costs for Georgia Power of up to $35 million per month for Unit 3 and $45 million per month for Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing 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 under "Georgia Power – Nuclear Construction" for additional information.

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, 2022. 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 2022, the market price of Southern Company's common stock was $71.31 per share (based on the closing price as reported on the NYSE) and the book value was $27.03 per share, representing a market-to-book ratio of 264%, compared to $68.58, $26.30, and 261%, respectively, at the end of 2021. Southern Company's common stock dividend for the second quarter 2022 was $0.68 per share compared to $0.66 per share in the second quarter 2021.

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 and/or regulation; 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. The continued impacts of the COVID-19 pandemic could also impair the ability to develop, construct, and operate facilities, as discussed further in Item 1A of the Form 10-K. In addition, there can be no assurance that costs related to capital expenditures

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

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. See Note 15 to the financial statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein under "Southern Power" for additional information regarding Southern Power's plant acquisitions and construction projects.

The construction program of Georgia Power includes Plant Vogtle Units 3 and 4, which includes components based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale and which may be subject to additional revised cost estimates during construction. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Georgia Power – Nuclear Construction" for information regarding Plant Vogtle Units 3 and 4 and additional factors that may impact construction expenditures.

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, 2021.

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 and equity issuances. Equity capital can be provided from any combination of Southern Company's stock plans, private placements, or public offerings. With the exception of the settlement on August 1, 2022 of stock purchase contracts associated with its equity units, Southern Company does not expect to issue any equity in the capital markets through 2026, but may issue equity through its stock plans during this time. 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 "Equity Units" for additional information.

The Subsidiary Registrants plan to obtain the funds to meet their future capital needs from sources similar to those they used in the past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity contributions from Southern Company. In addition, Southern Power plans to utilize tax equity partnership contributions (as discussed further herein). During the six months ended June 30, 2022, Southern Power utilized tax credits, which provided $239 million in operating cash flows.

The amount, type, and timing of any financings in 2022, 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.

Southern Power utilizes tax equity partnerships as one of its financing sources, where the tax partner takes significantly all of the federal tax benefits. These tax equity partnerships are consolidated in Southern Power's financial statements and are accounted for using HLBV methodology to allocate partnership gains and losses. During the first half of 2022, Southern Power obtained tax equity funding for existing tax equity partnerships totaling $51 million. See Note 1 to the financial statements under "General" in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

By regulation, Nicor Gas is restricted, to the extent of 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, 2022, the amount of subsidiary retained earnings restricted to dividend totaled $1.4 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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

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, 2022 for the applicable Registrants:

At June 30, 2022	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Current liabilities in excess of current assets	$	1,706	$	1,036	$	15	$	1	$	105

The Registrants believe the need for working capital can be adequately met by utilizing operating cash flows, as well as commercial paper, lines of credit, and short-term bank notes, as market conditions permit. In addition, under certain circumstances, the Subsidiary Registrants may utilize equity contributions and/or loans from Southern Company.

Bank Credit Arrangements

At June 30, 2022, the Registrants' unused committed credit arrangements with banks were as follows:

At June 30, 2022	Southern Company parent		Alabama Power		Georgia Power		Mississippi Power		Southern  Power(a)		Southern Company Gas(b)		SEGCO		Southern Company
	(in millions)
Unused committed credit	$	1,998	$	1,250	$	1,726	$	275	$	568	$	1,748	$	30	$	7,595

(a)At June 30, 2022, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $16 million was unused. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)Includes $798 million and $950 million at Southern Company Gas Capital and Nicor Gas, respectively.

Subject to applicable market conditions, the Registrants, Nicor Gas, and SEGCO expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, the Registrants, Nicor Gas, and SEGCO may extend the maturity dates and/or increase or decrease the lending commitments thereunder.

A portion of the unused credit with banks is allocated to provide liquidity support to the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at June 30, 2022 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi Power). In addition, at June 30, 2022, Georgia Power had approximately $445 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

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-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, 2022				Short-term Debt During the Period(*)
	Amount Outstanding		Weighted Average Interest Rate		Average Amount Outstanding		Weighted Average Interest Rate		Maximum Amount Outstanding
	(in millions)				(in millions)				(in millions)
Southern Company	$	2,510	2.0	%	$	2,061	1.2	%	$	2,588
Alabama Power	—		—		10		0.8		100
Georgia Power	400		1.8		551		1.1		916
Mississippi Power	16		2.1		21		2.0		35
Southern Power	306		1.9		115		1.3		350
Southern Company Gas:
Southern Company Gas Capital	$	316	2.0	%	$	314	1.2	%	$	446
Nicor Gas	200		2.1		203		1.2		273
Southern Company Gas Total	$	516	2.0	%	$	517	1.2	%

(*)Average and maximum amounts are based upon daily balances during the three-month period ended June 30, 2022.

Analysis of Cash Flows

Net cash flows provided from (used for) operating, investing, and financing activities for the six months ended June 30, 2022 and 2021 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, 2022
Operating activities	$	3,579	$	510	$	926	$	112	$	552	$	1,478
Investing activities	(3,460)		(889)		(1,668)		(133)		(73)		(658)
Financing activities	(213)		227		939		(18)		(403)		(650)
Six Months Ended June 30, 2021
Operating activities	$	2,904	$	584	$	1,313	$	41	$	411	$	722
Investing activities	(4,026)		(893)		(1,730)		(117)		(601)		(668)
Financing activities	1,671		506		457		515		196		(25)

Fluctuations in cash flows from financing activities vary from year to year based on capital needs and the maturity or redemption of securities.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Company

Net cash provided from operating activities increased $675 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments and increased natural gas cost recovery at the natural gas distribution utilities, partially offset by the timing of customer receivable collections and decreased fuel cost recovery at the traditional electric operating companies.

The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to the Subsidiary Registrants' construction programs.

The net cash used for financing activities for the six months ended June 30, 2022 was primarily related to common stock dividend payments, largely offset by an increase in short-term debt and net issuances of long-term debt.

Alabama Power

Net cash provided from operating activities decreased $74 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to the timing of customer receivable collections and decreased fuel cost recovery, partially offset by the timing of vendor payments and customer refunds issued in 2021.

The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to gross property additions.

The net cash provided from financing activities for the six months ended June 30, 2022 was primarily related to capital contributions from Southern Company and the net issuance of long-term debt, partially offset by common stock dividend payments.

Georgia Power

Net cash provided from operating activities decreased $387 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to decreased fuel cost recovery and the timing of customer receivable collections, partially offset by the timing of vendor payments.

The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to gross property additions, including a total of approximately $500 million related to the construction of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information on construction of Plant Vogtle Units 3 and 4.

The net cash provided from financing activities for the six months ended June 30, 2022 was primarily related to net issuances of senior notes, capital contributions from Southern Company, and a net increase in short-term borrowings, partially offset by common stock dividend payments.

Mississippi Power

Net cash provided from operating activities increased $71 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments, partially offset by the timing of customer receivable collections.

The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to gross property additions.

The net cash used for financing activities for the six months ended June 30, 2022 was primarily related to common stock dividend payments, partially offset by capital contributions from Southern Company and an increase in commercial paper borrowings.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Power

Net cash provided from operating activities increased $141 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to an increase in wholesale revenues driven by higher market prices of energy, the timing of vendor payments, and an increase in the utilization of tax credits in 2022, partially offset by the timing of customer receivable collections.

The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to construction payments. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

The net cash used for financing activities for the six months ended June 30, 2022 was primarily related to the repayment of senior notes at maturity, common stock dividend payments, and net capital distributions to noncontrolling interests, partially offset by a capital contribution from Southern Company and an increase in commercial paper borrowings.

Southern Company Gas

Net cash provided from operating activities increased $756 million for the six months ended June 30, 2022 as compared to the corresponding period in 2021 primarily due to increased natural gas cost recovery and the timing of vendor payments.

The net cash used for investing activities for the six months ended June 30, 2022 was primarily related to construction of transportation and distribution assets recovered through base rates and infrastructure investment recovered through replacement programs at gas distribution operations.

The net cash used for financing activities for the six months ended June 30, 2022 was primarily related to net repayments of short-term debt, common stock dividend payments, and repayment of medium-term notes, partially offset by capital contributions from Southern Company.

Significant Balance Sheet Changes

Southern Company

Significant balance sheet changes for the six months ended June 30, 2022 included:

•an increase of $1.7 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants' construction programs;

•an increase of $1.1 billion in notes payable due to an increase in short-term bank debt and commercial paper borrowings;

•an increase of $0.8 billion in accumulated deferred income taxes primarily related to the utilization of ITCs in 2022 and an increase in under recovered fuel clause revenues, as discussed further below;

•an increase of $0.7 billion in total stockholders' equity primarily related to net income, partially offset by common stock dividend payments;

•an increase of $0.7 billion in accounts payable primarily related to the timing of vendor payments;

•an increase of $0.6 billion in other deferred charges and assets primarily related to an increase in under recovered fuel clause revenues at Georgia Power due to higher fuel and purchased power costs;

•an increase of $0.5 billion in regulatory assets associated with AROs primarily due to a decrease of $0.4 billion in the fair value of the investments held in Alabama Power's and Georgia Power's nuclear decommissioning trusts; and

•an increase of $0.5 billion in customer accounts receivable primarily related to the timing of collections.

See "Financing Activities" herein and Notes (B), (G), and (I) 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)

Alabama Power

Significant balance sheet changes for the six months ended June 30, 2022 included:

•an increase of $881 million in common stockholder's equity primarily due to capital contributions from Southern Company, partially offset by dividends paid to Southern Company;

•an increase of $361 million in total property, plant, and equipment primarily related to construction of distribution and transmission facilities, construction of Plant Barry Unit 8, and the installation of equipment to comply with environmental standards; and

•an increase of $298 million in regulatory assets associated with AROs primarily due to a decrease of $201 million in the fair value of the investments held in Alabama Power's nuclear decommissioning trust.

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

Georgia Power

Significant balance sheet changes for the six months ended June 30, 2022 included:

•an increase of $1.1 billion in total property, plant, and equipment primarily related to the construction of generation, transmission, and distribution facilities, including $534 million for Plant Vogtle Units 3 and 4 (net of a pre-tax charge of $52 million recorded in the second quarter 2022 for estimated probable loss);

•an increase of $914 million in long-term debt (including securities due within one year) primarily due to net issuances of senior notes;

•an increase of $663 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 $538 million in deferred under recovered fuel clause revenues due to higher fuel and purchased power costs;

•an increase of $400 million in notes payable due to an increase in short-term bank debt;

•an increase of $299 million in accumulated deferred income taxes primarily due to the increase in under recovered fuel clause revenues and the expected reduction in federal and state credit carryforward balances in 2022;

•an increase of $283 million in customer accounts receivable primarily due to higher customer usage and the timing of collections; and

•an increase of $252 million in regulatory assets associated with AROs primarily due to a decrease of $192 million in the fair value of the investments held in Georgia Power's nuclear decommissioning trust.

See "Financing Activities – Georgia Power" herein and Note (B) under "Georgia Power – Nuclear Construction" and Note (I) to the Condensed Financial Statements herein for additional information.

Mississippi Power

Significant balance sheet changes for the six months ended June 30, 2022 included:

•an increase of $54 million in common stockholder's equity related to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company; and

•an increase of $52 million in customer accounts receivables primarily due to fuel under recovery.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Power

Significant balance sheet changes for the six months ended June 30, 2022 included:

•a decrease of $724 million in long-term debt (including securities due within one year) primarily due to the redemption of senior notes;

•an increase of $281 million in common stockholder's equity primarily due to capital contributions from Southern Company and net income, partially offset by common stock dividend payments and distributions to noncontrolling interests; and

•an increase of $256 million in accumulated deferred income tax liabilities primarily related to the utilization of ITCs in 2022.

See "Financing Activities – Southern Power" herein and Note (G) to the Condensed Financial Statements herein for additional information.

Southern Company Gas

Significant balance sheet changes for the six months ended June 30, 2022 included:

•a decrease of $693 million in notes payable due to repayments of short-term debt and commercial paper borrowings;

•an increase of $544 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 $440 million in total property, plant, and equipment primarily related to the construction of transportation and distribution assets and additional infrastructure investment; and

•a decrease of $230 million in other regulatory assets, deferred primarily due to a $192 million reduction in natural gas cost under recovery.

See "Financing Activities – Southern Company Gas" herein and Note (B) to the Condensed Financial Statements herein for additional information.

Financing Activities

The following table outlines the Registrants' long-term debt financing activities for the first six months of 2022:

			Maturities and Redemptions
Company	Senior Note Issuances		Senior Notes		Other Long-Term Debt(*)
	(in millions)
Alabama Power	$	700	$	550	$	—
Georgia Power	1,500		400		171
Southern Power	—		677		—
Southern Company Gas	—		—		46
Other	—		—		7
Southern Company	$	2,200	$	1,627	$	224

(*)Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization payments totaling $45 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.

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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

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 half of 2022, Southern Company issued approximately 3.1 million shares of common stock primarily through employee equity compensation plans and received proceeds of approximately $61 million.

In March 2022, Southern Company entered into a $400 million short-term floating rate bank loan bearing interest based on term SOFR.

In May 2022, Southern Company borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a rate agreed upon by Southern Company and the bank from time to time and payable on demand, following specified notice by the bank.

See Note (F) to the Condensed Financial Statements herein under "Equity Units" for information regarding Southern Company's May 2022 remarketing of its Series 2019A and Series 2019B Remarketable Junior Subordinated Notes. Southern Company did not receive any proceeds from the remarketing.

Alabama Power

In February 2022, Alabama Power redeemed all $550 million aggregate principal amount of its Series 2017A 2.45% Senior Notes due March 30, 2022.

In March 2022, Alabama Power issued $700 million aggregate principal amount of Series 2022A 3.05% Senior Notes due March 15, 2032.

In June 2022, Alabama Power redeemed the following series of preferred stock: 4.20% Preferred Stock, Par Value $100 Per Share, 4.60% Preferred Stock, Par Value $100 Per Share, 4.92% Preferred Stock, Par Value $100 Per Share, 4.52% Preferred Stock, Par Value $100 Per Share, 4.64% Preferred Stock, Par Value $100 Per Share, and 4.72% Preferred Stock, Par Value $100 Per Share. The redemption price per share for each series of preferred stock equaled the redemption price per share provided in Note 8 to the financial statements under "Outstanding Classes of Capital Stock – Alabama Power" in Item 8 of the Form 10-K, plus accrued and unpaid dividends to the redemption date.

Georgia Power

In January 2022, Georgia Power redeemed all $400 million aggregate principal amount of its Series 2012B 2.85% Senior Notes due May 15, 2022.

In February 2022, Georgia Power borrowed $250 million pursuant to a short-term uncommitted bank credit arrangement, which it repaid in May 2022.

In each of March and April 2022, Georgia Power entered into a $200 million short-term floating rate bank loan bearing interest based on term SOFR.

In May 2022, Georgia Power issued $700 million aggregate principal amount of Series 2022A 4.70% Senior Notes due May 15, 2032 and $800 million aggregate principal amount of Series 2022B 5.125% Senior Notes due May 15, 2052. An amount equal to the net proceeds of the Series 2022B Senior Notes will be allocated to finance or refinance, in whole or in part, one or more renewable energy projects and/or expenditures and programs related to enabling opportunities for diverse and small businesses/suppliers.

In May 2022, Georgia Power repaid its $125 million long-term bank loan that was scheduled to mature in June 2022.

Subsequent to June 30, 2022, Georgia Power repaid at maturity $53 million aggregate principal amount of Development Authority of Floyd County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Hammond Project), First Series 2010.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Mississippi Power

In June 2022, Mississippi Power repaid $20 million, which was borrowed in March 2022 under its $125 million revolving credit arrangement.

Southern Power

In June 2022, Southern Power repaid at maturity €600 million (approximately $677 million) aggregate principal amount of Series 2016A 1.00% Senior Notes.

Southern Company Gas

During the first quarter 2022, Nicor Gas repaid one of its three $100 million short-term floating rate bank loans entered into in March 2021. Nicor Gas also repaid $50 million of one of the other loans and increased the borrowing amount under the other loan to $150 million. In addition, both loans were renewed and amended to extend the maturity dates and change the interest rate provisions so the loans bear interest based on term SOFR.

During the second quarter 2022, Atlanta Gas Light repaid at maturity $46 million aggregate principal amount of medium-term notes with a weighted average interest rate of 8.63%.

Credit Rating Risk

At June 30, 2022, the Registrants did not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade.

There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change of certain Registrants to BBB and/or Baa2 or below. These contracts are primarily for physical electricity and natural gas purchases and sales, fuel purchases, fuel transportation and storage, energy price risk management, transmission, interest rate management, and, for Georgia Power, construction of new generation at Plant Vogtle Units 3 and 4.

The maximum potential collateral requirements under these contracts at June 30, 2022 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	$	33	$	1	$	—	$	—	$	32	$	—
At BBB- and/or Baa3	414		2		61		1		353		—
At BB+ and/or Ba1 or below	1,948		416		917		316		1,215		7

(*)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, 2022.

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.

On February 22, 2022, Fitch downgraded the senior unsecured long-term debt rating of Georgia Power to BBB+ from A- with a stable outlook.

Also on February 22, 2022, Fitch revised the ratings outlook of Southern Company, Alabama Power, Southern Power, Nicor Gas, and SEGCO to negative from stable.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

During the six months ended June 30, 2022, 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 Sections 13a-15(e) and 15d-15(e) of 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 controls 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 2022 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 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.

(4) Instruments Describing Rights of Security Holders, Including Indentures
Southern Company
(a)1	-	Thirteenth Supplemental Indenture to Subordinated Note Indenture dated as of May 9, 2022, providing for the remarketing of the Series 2019A Remarketable Junior Subordinated Notes due August 1, 2024. (Designated in Form 8-K dated May 9, 2022, File No. 1-3526, as Exhibit 4.4(a).)
(a)2	-	Fourteenth Supplemental Indenture to Subordinated Note Indenture dated as of May 9, 2022, providing for the remarketing of the Series 2019B Remarketable Junior Subordinated Notes due August 1, 2027. (Designated in Form 8-K dated May 9, 2022, File No. 1-3526, as Exhibit 4.4(b).)
Georgia Power
(c)1	-	Sixty-Fourth Supplemental Indenture to Senior Note Indenture dated as of May 4, 2022, providing for the issuance of the Series 2022A 4.70% Senior Notes due May 15, 2032. (Designated in Form 8-K dated May 2, 2022, File No. 1-6468, as Exhibit 4.2(a).)
(c)2	-	Sixty-Fifth Supplemental Indenture to Senior Note Indenture dated as of May 4, 2022, providing for the issuance of the Series 2022B 5.125% Senior Notes due May 15, 2052. (Designated in Form 8-K dated May 2, 2022, File No. 1-6468, as Exhibit 4.2(b).)
(24) Power of Attorney and Resolutions
Southern Company
(a)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, 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, 2021, 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, 2021, 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, 2021, File No. 001-11229 as Exhibit 24(d)1.)

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	Southern Power
	(e)1	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, File No. 001-37803 as Exhibit 24(e)1.)
*	(e)2	-	Power of Attorney of Gary Kerr.
	Southern Company Gas
	(f)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, 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
*	(c)1	-	Certificate of Georgia Power's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
*	(c)2	-	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.
	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.

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	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	-	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	-	XBRL Taxonomy Extension Schema Document
*	CAL	-	XBRL Taxonomy Calculation Linkbase Document
*	DEF	-	XBRL Definition Linkbase Document
*	LAB	-	XBRL Taxonomy Label Linkbase Document
*	PRE	-	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	Thomas A. Fanning
	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 27, 2022

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ALABAMA POWER 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.

	ALABAMA POWER COMPANY
By	Mark A. Crosswhite
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Philip C. Raymond
	Executive Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: July 27, 2022

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GEORGIA POWER 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.

	GEORGIA POWER COMPANY
By	Christopher C. Womack
	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 27, 2022

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MISSISSIPPI POWER 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.

	MISSISSIPPI POWER COMPANY
By	Anthony L. Wilson
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Moses H. Feagin
	Senior Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: July 27, 2022

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SOUTHERN POWER 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.

	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 27, 2022

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SOUTHERN COMPANY GAS

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.

	SOUTHERN COMPANY GAS
By	Kimberly S. Greene
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	David P. Poroch
	Executive Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: July 27, 2022

158

EX-24.E2

Exhibit 24(e)2

Gary Kerr SVP, CFO & Treasurer SPC 3535 Colonnade Parkway
Bin S901-EC
Birmingham, AL 35243

June 30, 2022

Mr. Matt Madison

Southern Power Company

3535 Colonnade Pkwy

Birmingham, AL 35243

Ms. Melissa K. Caen

Southern Company Services, Inc.

30 Ivan Allen Jr. Blvd, NW

Atlanta, GA 30308

Dear Mr. Madison and Ms. Caen:

As an officer of Southern Power Company, I hereby make, constitute, and appoint you my true and lawful Attorney in my name, place, and stead, to sign and cause to be filed with the Securities and Exchange Commission the Company’s Quarterly Reports on Form 10-Q for the quarters ended June 30, 2022 and September 30, 2022. This includes any necessary or appropriate amendment or amendments to such reports, to the Company’s other Quarterly Reports on Form 10-Q filed during 2022 or to the Company’s Annual Report on Form 10-K for the year ended December 31, 2021, such reports or amendments to such reports to be accompanied in each case by any necessary or appropriate exhibits or schedules thereto.

Yours very truly,

/s/Gary S. Kerr

Gary S. Kerr

SVP, CFO & Treasurer SPC

EX-31.A1

Exhibit 31(a)1

THE SOUTHERN COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Thomas A. Fanning, certify that:

1.I have reviewed this quarterly report on Form 10-Q of The Southern Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Thomas A. Fanning

Thomas A. Fanning

Chairman, President and
Chief Executive Officer

EX-31.A2

Exhibit 31(a)2

THE SOUTHERN COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Daniel S. Tucker, certify that:

1.I have reviewed this quarterly report on Form 10-Q of The Southern Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: July 27, 2022

/s/Daniel S. Tucker

Daniel S. Tucker

Executive Vice President and Chief Financial Officer

EX-31.B1

Exhibit 31(b)1

ALABAMA POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Mark A. Crosswhite, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Alabama Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Mark A. Crosswhite

Mark A. Crosswhite

Chairman, President and Chief Executive Officer

EX-31.B2

Exhibit 31(b)2

ALABAMA POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Philip C. Raymond, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Alabama Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Philip C. Raymond

Philip C. Raymond

Executive Vice President, Chief Financial Officer
and Treasurer

EX-31.C1

Exhibit 31(c)1

GEORGIA POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Christopher C. Womack, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Georgia Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Christopher C. Womack

Christopher C. Womack

Chairman, President and Chief Executive Officer

EX-31.C2

Exhibit 31(c)2

GEORGIA POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Aaron P. Abramovitz, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Georgia Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Aaron P. Abramovitz

Aaron P. Abramovitz

Executive Vice President, Chief Financial Officer and Treasurer

EX-31.D1

Exhibit 31(d)1

MISSISSIPPI POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Anthony L. Wilson, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Mississippi Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Anthony L. Wilson

Anthony L. Wilson

Chairman, President and
 Chief Executive Officer

EX-31.D2

Exhibit 31(d)2

MISSISSIPPI POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Moses H. Feagin, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Mississippi Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Moses H. Feagin

Moses H. Feagin

Senior Vice President, Treasurer and
Chief Financial Officer

EX-31.E1

Exhibit 31(e)1

SOUTHERN POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Christopher Cummiskey, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:   July 27, 2022

/s/Christopher Cummiskey

Christopher Cummiskey

Chairman and Chief Executive Officer

EX-31.E2

Exhibit 31(e)2

SOUTHERN POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Gary Kerr, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Gary Kerr

Gary Kerr

Senior Vice President, Chief
Financial Officer and Treasurer

EX-31.F1

Exhibit 31(f)1

SOUTHERN COMPANY GAS

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Kimberly S. Greene, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Company Gas;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/Kimberly S. Greene

Kimberly S. Greene

Chairman, President and Chief

 Executive Officer

EX-31.F2

Exhibit 31(f)2

SOUTHERN COMPANY GAS

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, David P. Poroch, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Company Gas;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  July 27, 2022

/s/David P. Poroch

David P. Poroch

Executive Vice President, Chief Financial
Officer and Treasurer

EX-32.A

Exhibit 32(a)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of The Southern Company for the quarter ended June 30, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of The Southern Company for the quarter ended June 30, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of The Southern Company for the quarter ended June 30, 2022, fairly presents, in all material respects, the financial condition and results of operations of The Southern Company.

/s/Thomas A. Fanning

Thomas A. Fanning

Chairman, President and
Chief Executive Officer

/s/Daniel S. Tucker

Daniel S. Tucker

Executive Vice President and
Chief Financial Officer

July 27, 2022

EX-32.B

Exhibit 32(b)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Alabama Power Company for the quarter ended June 30, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Alabama Power Company for the quarter ended June 30, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Alabama Power Company for the quarter ended June 30, 2022, fairly presents, in all material respects, the financial condition and results of operations of Alabama Power Company.

/s/Mark A. Crosswhite

Mark A. Crosswhite

Chairman, President and Chief Executive Officer

/s/Philip C. Raymond

Philip C. Raymond

Executive Vice President,
Chief Financial Officer and Treasurer

July 27, 2022

EX-32.C

Exhibit 32(c)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Georgia Power Company for the quarter ended June 30, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Georgia Power Company for the quarter ended June 30, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Georgia Power Company for the quarter ended June 30, 2022, fairly presents, in all material respects, the financial condition and results of operations of Georgia Power Company.

/s/Christopher C. Womack

Christopher C. Womack

Chairman, President and Chief Executive Officer

/s/Aaron P. Abramovitz

Aaron P. Abramovitz

Executive Vice President, Chief Financial Officer and Treasurer

July 27, 2022

EX-32.D

Exhibit 32(d)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Mississippi Power Company for the quarter ended June 30, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Mississippi Power Company for the quarter ended June 30, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Mississippi Power Company for the quarter ended June 30, 2022, fairly presents, in all material respects, the financial condition and results of operations of Mississippi Power Company.

/s/Anthony L. Wilson

Anthony L. Wilson

Chairman, President and Chief Executive Officer

/s/Moses H. Feagin

Moses H. Feagin

Senior Vice President, Treasurer and
Chief Financial Officer

July 27, 2022

EX-32.E

Exhibit 32(e)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Southern Power Company for the quarter ended June 30, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Southern Power Company for the quarter ended June 30, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Southern Power Company for the quarter ended June 30, 2022, fairly presents, in all material respects, the financial condition and results of operations of Southern Power Company.

/s/Christopher Cummiskey

Christopher Cummiskey

Chairman and Chief Executive Officer

/s/Gary Kerr

Gary Kerr

Senior Vice President, Chief Financial Officer and Treasurer

July 27, 2022

EX-32.F

Exhibit 32(f)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Southern Company Gas for the quarter ended June 30, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Southern Company Gas for the quarter ended June 30, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Southern Company Gas for the quarter ended June 30, 2022, fairly presents, in all material respects, the financial condition and results of operations of Southern Company Gas.

/s/Kimberly S. Greene

Kimberly S. Greene

Chairman, President and Chief Executive Officer

/s/David P. Poroch

David P. Poroch

Executive Vice President, Chief Financial

Officer and Treasurer

July 27, 2022

XML

Cover Page	6 Months Ended
	Jun. 30, 2022 shares
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2022
Document Transition Report	false
Entity File Number	1-3526
Entity Registrant Name	The Southern Company
Entity Tax Identification Number	58-0690070
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	30 Ivan Allen Jr. Boulevard, N.W.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30308
City Area Code	404
Local Phone Number	506-5000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	1,063,001,320
Entity Central Index Key	0000092122
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Common Stock, par value $5 per share
Document Information [Line Items]
Title of 12(b) Security	Common Stock, par value $5 per share
Trading Symbol	SO
Security Exchange Name	NYSE
Series 2017B 5.25% Junior Subordinated Notes due 2077
Document Information [Line Items]
Title of 12(b) Security	Series 2017B 5.25% Junior Subordinated Notes due 2077
Trading Symbol	SOJC
Security Exchange Name	NYSE
2019 Series A Corporate Units
Document Information [Line Items]
Title of 12(b) Security	2019 Series A Corporate Units
Trading Symbol	SOLN
Security Exchange Name	NYSE
Series 2020A 4.95% Junior Subordinated Notes due 2080
Document Information [Line Items]
Title of 12(b) Security	Series 2020A 4.95% Junior Subordinated Notes due 2080
Trading Symbol	SOJD
Security Exchange Name	NYSE
Series 2020C 4.20% Junior Subordinated Notes due 2060
Document Information [Line Items]
Title of 12(b) Security	Series 2020C 4.20% Junior Subordinated Notes due 2060
Trading Symbol	SOJE
Security Exchange Name	NYSE
Series 2021B 1.875% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due 2081
Document Information [Line Items]
Title of 12(b) Security	Series 2021B 1.875% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due 2081
Trading Symbol	SO 81
Security Exchange Name	NYSE
ALABAMA POWER CO
Document Information [Line Items]
Entity File Number	1-3164
Entity Registrant Name	Alabama Power Company
Entity Tax Identification Number	63-0004250
Entity Incorporation, State or Country Code	AL
Entity Address, Address Line One	600 North 18th Street
Entity Address, City or Town	Birmingham
Entity Address, State or Province	AL
Entity Address, Postal Zip Code	35203
City Area Code	205
Local Phone Number	257-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	30,537,500
Entity Central Index Key	0000003153
ALABAMA POWER CO | 5.00% Series Class A Preferred Stock
Document Information [Line Items]
Title of 12(b) Security	5.00% Series Class A Preferred Stock
Trading Symbol	ALP PR Q
Security Exchange Name	NYSE
GEORGIA POWER CO
Document Information [Line Items]
Entity File Number	1-6468
Entity Registrant Name	Georgia Power Company
Entity Tax Identification Number	58-0257110
Entity Incorporation, State or Country Code	GA
Entity Address, Address Line One	241 Ralph McGill Boulevard, N.E.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30308
City Area Code	404
Local Phone Number	506-6526
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	9,261,500
Entity Central Index Key	0000041091
GEORGIA POWER CO | Series 2017A 5.00% Junior Subordinated Notes due 2077
Document Information [Line Items]
Title of 12(b) Security	Series 2017A 5.00% Junior Subordinated Notes due 2077
Trading Symbol	GPJA
Security Exchange Name	NYSE
MISSISSIPPI POWER CO
Document Information [Line Items]
Entity File Number	001-11229
Entity Registrant Name	Mississippi Power Company
Entity Tax Identification Number	64-0205820
Entity Incorporation, State or Country Code	MS
Entity Address, Address Line One	2992 West Beach Boulevard
Entity Address, City or Town	Gulfport
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39501
City Area Code	228
Local Phone Number	864-1211
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	1,121,000
Entity Central Index Key	0000066904
SOUTHERN POWER CO
Document Information [Line Items]
Entity File Number	001-37803
Entity Registrant Name	Southern Power Company
Entity Tax Identification Number	58-2598670
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	30 Ivan Allen Jr. Boulevard, N.W.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30308
City Area Code	404
Local Phone Number	506-5000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	1,000
Entity Central Index Key	0001160661
SOUTHERN POWER CO | Series 2016A 1.000% Senior Notes due 2022
Document Information [Line Items]
Title of 12(b) Security	Series 2016A 1.000% Senior Notes due 2022
Trading Symbol	SO/22B
Security Exchange Name	NYSE
SOUTHERN POWER CO | Series 2016B 1.850% Senior Notes due 2026
Document Information [Line Items]
Title of 12(b) Security	Series 2016B 1.850% Senior Notes due 2026
Trading Symbol	SO/26A
Security Exchange Name	NYSE
SOUTHERN Co GAS
Document Information [Line Items]
Entity File Number	1-14174
Entity Registrant Name	Southern Company Gas
Entity Tax Identification Number	58-2210952
Entity Incorporation, State or Country Code	GA
Entity Address, Address Line One	Ten Peachtree Place, N.E.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30309
City Area Code	404
Local Phone Number	584-4000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	100
Entity Central Index Key	0001004155

XML

Condensed Consolidated Statements of Income (Unaudited) - Southern - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating Revenues:
Total operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Operating Expenses:
Other operations and maintenance	1,558	1,438	3,075	2,810
Depreciation and amortization	913	891	1,805	1,762
Taxes other than income taxes	349	313	721	657
Estimated loss on Plant Vogtle Units 3 and 4	52	460	52	508
Gain on dispositions, net	(10)	(11)	(33)	(54)
Total operating expenses	5,551	4,490	10,815	8,802
Operating Income	1,655	708	3,039	2,306
Other Income and (Expense):
Allowance for equity funds used during construction	53	45	104	90
Earnings (loss) from equity method investments	34	(40)	80	5
Interest expense, net of amounts capitalized	(488)	(450)	(950)	(901)
Other income (expense), net	139	101	283	160
Total other income and (expense)	(262)	(344)	(483)	(646)
Earnings (Loss) Before Income Taxes	1,393	364	2,556	1,660
Income taxes (benefit)	304	(12)	477	178
Consolidated Net Income	1,089	376	2,079	1,482
Dividends on preferred stock of subsidiaries	4	4	7	7
Net loss attributable to noncontrolling interests	(22)	0	(67)	(33)
Net Income	$ 1,107	$ 372	$ 2,139	$ 1,508
Earnings per share -
Basic (in dollars per share)	$ 1.04	$ 0.35	$ 2.01	$ 1.42
Diluted (in dollars per share)	$ 1.03	$ 0.35	$ 2.00	$ 1.41
Average number of shares of common stock outstanding — (in millions)
Basic (in shares)	1,065	1,061	1,064	1,060
Diluted (in shares)	1,072	1,067	1,070	1,066
Retail electric revenues
Operating Revenues:
Total operating revenues	$ 4,789	$ 3,599	$ 8,402	$ 6,941
Wholesale Electric
Operating Revenues:
Total operating revenues	937	546	1,601	1,091
Other electric revenues
Operating Revenues:
Total operating revenues	192	175	370	346
Natural Gas
Operating Revenues:
Total operating revenues	1,083	677	3,140	2,371
Natural gas
Operating Expenses:
Less Gross Gas Costs	452	231	1,546	814
Alternative revenue programs
Operating Revenues:
Total operating revenues	2	2	1	4
Other revenues
Operating Revenues:
Total operating revenues	205	201	341	359
Operating Expenses:
Less Gross Gas Costs	114	103	183	185
Fuel
Operating Expenses:
Less Gross Gas Costs	1,715	848	2,826	1,696
Purchased power
Operating Expenses:
Less Gross Gas Costs	$ 408	$ 217	$ 640	$ 424

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Condensed Consolidated Statements of Income (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Total operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Natural Gas
Total operating revenues	1,083	677	3,140	2,371
Alternative revenue programs
Total operating revenues	$ 2	$ 2	$ 1	$ 4

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - Southern - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Comprehensive Income [Abstract]
Net income	$ 1,089	$ 376	$ 2,079	$ 1,482
Qualifying hedges:
Changes in fair value, net of tax	(45)	14	(26)	(16)
Reclassification adjustment for amounts included in net income, net of tax	54	(5)	74	50
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	2	3	5	6
Total other comprehensive income	11	12	53	40
Comprehensive Income	1,100	388	2,132	1,522
Dividends on preferred stock of subsidiaries	4	4	7	7
Comprehensive loss attributable to noncontrolling interests	(22)	0	(67)	(33)
Comprehensive Income	$ 1,118	$ 384	$ 2,192	$ 1,548

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Comprehensive Income [Abstract]
Changes in fair value, tax	$ (15)	$ 5	$ (7)	$ (5)
Qualifying hedges, reclassification adjustment, tax	17	(1)	24	17
Reclassification adjustment for amounts included in net income, tax	$ 1	$ 2	$ 2	$ 3

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Condensed Consolidated Statements of Cash Flows (Unaudited) - Southern - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating Activities:
Net income (loss)	$ 2,079	$ 1,482
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,995	1,949
Deferred income taxes	240	(101)
Utilization of federal investment tax credits	281	224
Allowance for equity funds used during construction	(104)	(90)
Mark-to-market adjustments	14	136
Pension, postretirement, and other employee benefits	(211)	(115)
Settlement of asset retirement obligations	(198)	(228)
Stock based compensation expense	100	105
Estimated loss on Plant Vogtle Units 3 and 4	52	508
Storm damage accruals	107	112
Natural gas cost under recovery – long-term	192	(119)
Retail fuel cost under recovery – long-term	(729)	0
Other, net	21	117
Changes in certain current assets and liabilities —
Receivables	(637)	29
Prepayments	(90)	(79)
Materials and supplies	(109)	(57)
Natural gas for sale, net of temporary LIFO liquidation	335	375
Natural gas cost under recovery	(94)	(485)
Other current assets	12	94
Accounts payable	703	(177)
Accrued taxes	(150)	(157)
Accrued compensation	(260)	(238)
Retail fuel cost over recovery	0	(146)
Other current liabilities	30	(235)
Net cash provided from operating activities	3,579	2,904
Investing Activities:
Business acquisitions, net of cash acquired	0	(345)
Property additions	(3,213)	(3,384)
Nuclear decommissioning trust fund purchases	(628)	(930)
Nuclear decommissioning trust fund sales	624	926
Proceeds from dispositions	119	25
Cost of removal, net of salvage	(377)	(184)
Payments pursuant to LTSAs	(81)	(114)
Other investing activities	96	(20)
Net cash used for investing activities	(3,460)	(4,026)
Financing Activities:
Increase (decrease) in notes payable, net	263	492
Proceeds —
Long-term debt	2,200	4,646
Short-term borrowings	1,200	325
Common stock	61	24
Redemptions and repurchases —
Long-term debt	(1,851)	(2,477)
Short-term borrowings	(400)	(25)
Capital contributions from noncontrolling interests	73	343
Distributions to noncontrolling interests	(115)	(113)
Payment of common stock dividends	(1,425)	(1,377)
Other financing activities	(219)	(167)
Net cash provided from (used for) financing activities	(213)	1,671
Net Change in Cash, Cash Equivalents, and Restricted Cash	(94)	549
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,735	1,617
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	836	884
Income taxes, net	157	88
Noncash transactions —
Accrued property additions at year-end	837	943
Contributions from noncontrolling interests	0	89
Contributions of wind turbine equipment	0	82
Right-of-use assets obtained under leases	15	90
Reassessment of right-of-use assets under operating leases	$ 40	$ 0

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Condensed Consolidated Statements of Cash Flows (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Statement of Cash Flows [Abstract]
Net cash paid for capitalized interest	$ 46	$ 43

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Condensed Consolidated Balance Sheets (Unaudited) - Southern - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,724	$ 1,798
Receivables —
Customer accounts	2,277	1,806
Unbilled revenues	807	711
Other accounts and notes	534	523
Accumulated provision for uncollectible accounts	(94)	(78)
Materials and supplies	1,641	1,543
Fossil fuel for generation	431	450
Natural gas for sale	209	362
Prepaid expenses	528	330
Assets from risk management activities, net of collateral	247	151
Regulatory assets – asset retirement obligations	263	219
Natural gas cost under recovery	361	266
Other regulatory assets	641	653
Other current assets	212	231
Total current assets	9,781	8,965
Property, Plant, and Equipment:
In service	117,418	115,592
Less: Accumulated depreciation	35,203	34,079
Plant in service, net of depreciation	82,215	81,513
Nuclear fuel, at amortized cost	837	824
Construction work in progress	9,770	8,771
Total property, plant, and equipment	92,822	91,108
Other Property and Investments:
Goodwill	5,280	5,280
Nuclear decommissioning trusts, at fair value	2,150	2,542
Equity investments in unconsolidated subsidiaries	1,305	1,282
Other intangible assets, net of amortization	425	445
Miscellaneous property and investments	576	653
Total other property and investments	9,736	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,623	1,701
Deferred charges related to income taxes	843	824
Prepaid pension costs	1,893	1,657
Unamortized loss on reacquired debt	248	258
Regulatory assets – asset retirement obligations, deferred	5,982	5,466
Other regulatory assets, deferred	5,448	5,577
Other deferred charges and assets	2,393	1,776
Total deferred charges and other assets	18,430	17,259
Total Assets	130,769	127,534
Current Liabilities:
Securities due within one year	1,052	2,157
Notes payable	2,510	1,440
Accounts payable	2,908	2,169
Customer deposits	461	479
Accrued taxes —
Accrued income taxes	17	50
Other accrued taxes	635	641
Accrued interest	553	533
Accrued compensation	807	1,070
Asset retirement obligations	693	697
Operating lease obligations	232	250
Other regulatory liabilities	557	563
Other current liabilities	1,062	872
Total current liabilities	11,487	10,921
Long-term Debt	51,204	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,620	8,862
Deferred credits related to income taxes	5,318	5,401
Accumulated deferred ITCs	2,175	2,216
Employee benefit obligations	1,509	1,550
Operating lease obligations, deferred	1,464	1,503
Asset retirement obligations, deferred	11,010	10,990
Other cost of removal obligations	1,993	2,103
Other regulatory liabilities, deferred	536	485
Other deferred credits and liabilities	1,198	816
Total deferred credits and other liabilities	34,823	33,926
Total Liabilities	97,514	94,967
Redeemable preferred stock	242	291
Common Stockholder's Equity (See accompanying statements)	33,013	32,276
Total Liabilities and Stockholders' Equity	$ 130,769	$ 127,534

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Condensed Consolidated Balance Sheets (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Other intangible assets, amortization	$ 326	$ 307

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - Southern - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Treasury	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests
Beginning balance (in shares) at Dec. 31, 2020		1,058
Beginning balance (in shares) at Dec. 31, 2020			(1)
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ (46)	$ 11,834	$ 11,311	$ (395)	$ 4,262
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	1,103				1,135		(32)
Other comprehensive income (loss)	28					28
Stock issued (in shares)		2
Stock issued	14	$ 5		9
Stock-based compensation	9			9
Cash dividends on common stock	(678)				(678)
Capital contributions from noncontrolling interests	403						403
Distributions to noncontrolling interests	(46)						(46)
Other	1			2			(1)
Ending balance (in shares) at Mar. 31, 2021		1,060
Ending balance (in shares) at Mar. 31, 2021			(1)
Ending balance at Mar. 31, 2021	33,068	$ 5,273	$ (46)	11,854	11,768	(367)	4,586
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	372				372		0
Other comprehensive income (loss)	12					12
Stock issued	10	$ 1		9
Stock-based compensation	22			22
Cash dividends on common stock	(699)				(699)
Capital contributions from noncontrolling interests	29						29
Distributions to noncontrolling interests	(68)						(68)
Other	0		$ (2)	1	1
Ending balance (in shares) at Jun. 30, 2021		1,060
Ending balance (in shares) at Jun. 30, 2021			(1)
Ending balance at Jun. 30, 2021	32,746	$ 5,274	$ (48)	11,886	11,442	(355)	4,547
Beginning balance (in shares) at Dec. 31, 2021		1,061
Beginning balance (in shares) at Dec. 31, 2021			(1)
Beginning balance at Dec. 31, 2021	32,276	$ 5,279	$ (47)	11,950	10,929	(237)	4,402
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	987				1,032		(45)
Other comprehensive income (loss)	42					42
Stock issued (in shares)		3
Stock issued	38	$ 7		31
Stock-based compensation	6			6
Cash dividends on common stock	(702)				(702)
Capital contributions from noncontrolling interests	73						73
Distributions to noncontrolling interests	(98)						(98)
Other	7		$ (2)	7	2
Ending balance (in shares) at Mar. 31, 2022		1,064
Ending balance (in shares) at Mar. 31, 2022			(1)
Ending balance at Mar. 31, 2022	32,629	$ 5,286	$ (49)	11,994	11,261	(195)	4,332
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	1,085				1,107		(22)
Other comprehensive income (loss)	11					11
Stock issued	23	$ 2		21
Stock-based compensation	14			14
Cash dividends on common stock	(723)				(723)
Distributions to noncontrolling interests	(28)						(28)
Other	2		$ (2)	4
Ending balance (in shares) at Jun. 30, 2022		1,064
Ending balance (in shares) at Jun. 30, 2022			(1)
Ending balance at Jun. 30, 2022	$ 33,013	$ 5,288	$ (51)	$ 12,033	$ 11,645	$ (184)	$ 4,282

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - Southern (Parenthetical) - $ / shares	3 Months Ended
	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2021	Mar. 31, 2021
Statement of Stockholders' Equity [Abstract]
Cash dividends (in dollars per share)	$ 0.68	$ 0.66	$ 0.66	$ 0.64

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Condensed Statements of Income (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating Revenues:
Total operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Operating Expenses:
Other operations and maintenance	1,558	1,438	3,075	2,810
Depreciation and amortization	913	891	1,805	1,762
Taxes other than income taxes	349	313	721	657
Total operating expenses	5,551	4,490	10,815	8,802
Operating Income	1,655	708	3,039	2,306
Other Income and (Expense):
Allowance for equity funds used during construction	53	45	104	90
Interest expense, net of amounts capitalized	(488)	(450)	(950)	(901)
Total other income (expense), net	139	101	283	160
Total other income and (expense)	(262)	(344)	(483)	(646)
Earnings (Loss) Before Income Taxes	1,393	364	2,556	1,660
Income taxes (benefit)	304	(12)	477	178
Net income	1,089	376	2,079	1,482
Dividends on preferred stock of subsidiaries	4	4	7	7
Net Income	1,107	372	2,139	1,508
Retail electric revenues
Operating Revenues:
Total operating revenues	4,789	3,599	8,402	6,941
Wholesale Electric
Operating Revenues:
Total operating revenues	937	546	1,601	1,091
Other electric revenues
Operating Revenues:
Total operating revenues	192	175	370	346
Natural Gas
Operating Revenues:
Total operating revenues	1,083	677	3,140	2,371
Other revenues
Operating Revenues:
Total operating revenues	205	201	341	359
Operating Expenses:
Total cost of sales	114	103	183	185
Fuel
Operating Expenses:
Total cost of sales	1,715	848	2,826	1,696
Purchased power
Operating Expenses:
Total cost of sales	408	217	640	424
Alabama Power
Operating Revenues:
Total operating revenues	1,931	1,556	3,580	3,115
Operating Expenses:
Other operations and maintenance	441	413	852	775
Depreciation and amortization	218	214	432	425
Taxes other than income taxes	100	101	204	203
Total operating expenses	1,376	1,078	2,530	2,123
Operating Income	555	478	1,050	992
Other Income and (Expense):
Allowance for equity funds used during construction	17	12	33	24
Interest expense, net of amounts capitalized	(91)	(84)	(180)	(168)
Total other income (expense), net	27	33	61	62
Total other income and (expense)	(47)	(39)	(86)	(82)
Earnings (Loss) Before Income Taxes	508	439	964	910
Income taxes (benefit)	121	104	227	213
Net income	387	335	737	697
Dividends on preferred stock of subsidiaries	4	4	7	7
Net Income	383	331	730	690
Alabama Power | Retail electric revenues
Operating Revenues:
Total operating revenues	1,629	1,354	3,008	2,706
Alabama Power | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	159	85	272	178
Alabama Power | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	34	24	100	55
Alabama Power | Other revenues
Operating Revenues:
Total operating revenues	109	93	200	176
Alabama Power | Fuel
Operating Expenses:
Total cost of sales	401	263	733	554
Alabama Power | Purchased power
Operating Expenses:
Total cost of sales	95	48	162	97
Alabama Power | Purchased power, affiliates
Operating Expenses:
Total cost of sales	$ 121	$ 39	$ 147	$ 69

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Condensed Statements of Comprehensive Income (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 1,089	$ 376	$ 2,079	$ 1,482
Qualifying hedges:
Changes in fair value, net of tax	(45)	14	(26)	(16)
Reclassification adjustment for amounts included in net income, net of tax	54	(5)	74	50
Total other comprehensive income	11	12	53	40
Comprehensive Income	1,100	388	2,132	1,522
Alabama Power
Net income	387	335	737	697
Qualifying hedges:
Changes in fair value, net of tax	0	0	(1)	0
Reclassification adjustment for amounts included in net income, net of tax	1	1	2	2
Total other comprehensive income	1	1	1	2
Comprehensive Income	$ 388	$ 336	$ 738	$ 699

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Condensed Statements of Comprehensive Income (Unaudited) - APC (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Changes in fair value, tax	$ (15)	$ 5	$ (7)	$ (5)
Qualifying hedges, reclassification adjustment, tax	17	(1)	24	17
Alabama Power
Changes in fair value, tax	0	0	(1)	0
Qualifying hedges, reclassification adjustment, tax	$ 0	$ 0	$ 1	$ 1

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Condensed Statements of Cash Flows (Unaudited) - APC - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating Activities:
Net income (loss)	$ 2,079	$ 1,482
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,995	1,949
Deferred income taxes	240	(101)
Pension, postretirement, and other employee benefits	(211)	(115)
Settlement of asset retirement obligations	(198)	(228)
Other, net	21	117
Changes in certain current assets and liabilities —
Receivables	(637)	29
Prepayments	(90)	(79)
Other current assets	12	94
Accounts payable	703	(177)
Accrued compensation	(260)	(238)
Other current liabilities	30	(235)
Net cash provided from operating activities	3,579	2,904
Investing Activities:
Property additions	(3,213)	(3,384)
Nuclear decommissioning trust fund purchases	(628)	(930)
Nuclear decommissioning trust fund sales	624	926
Cost of removal, net of salvage	(377)	(184)
Other investing activities	96	(20)
Net cash used for investing activities	(3,460)	(4,026)
Redemptions and repurchases —
Payment of common stock dividends	(1,425)	(1,377)
Other financing activities	(219)	(167)
Net cash provided from (used for) financing activities	(213)	1,671
Net Change in Cash, Cash Equivalents, and Restricted Cash	(94)	549
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,735	1,617
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	836	884
Income taxes, net	157	88
Noncash transactions —
Accrued property additions at year-end	837	943
Right-of-use assets obtained under leases	15	90
Alabama Power
Operating Activities:
Net income (loss)	737	697
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	494	496
Deferred income taxes	117	87
Pension, postretirement, and other employee benefits	(59)	(39)
Settlement of asset retirement obligations	(91)	(104)
Retail fuel cost under recovery – long-term	(191)	0
Other, net	(67)	(35)
Changes in certain current assets and liabilities —
Receivables	(296)	(85)
Prepayments	(69)	(53)
Other current assets	(33)	(23)
Accounts payable	14	(236)
Accrued compensation	(55)	(60)
Other current liabilities	9	(61)
Net cash provided from operating activities	510	584
Investing Activities:
Property additions	(759)	(844)
Nuclear decommissioning trust fund purchases	(180)	(473)
Nuclear decommissioning trust fund sales	180	473
Cost of removal, net of salvage	(104)	(56)
Change in construction payables, net	(8)	25
Other investing activities	(18)	(18)
Net cash used for investing activities	(889)	(893)
Proceeds —
Senior notes	700	600
Redemptions and repurchases —
Senior notes	(550)	(200)
Capital contributions from parent company	656	624
Payment of common stock dividends	(508)	(492)
Other financing activities	(71)	(26)
Net cash provided from (used for) financing activities	227	506
Net Change in Cash, Cash Equivalents, and Restricted Cash	(152)	197
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,060	530
Cash, Cash Equivalents, and Restricted Cash at End of Period	908	727
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	166	154
Income taxes, net	192	171
Noncash transactions —
Accrued property additions at year-end	141	191
Right-of-use assets obtained under leases	$ 6	$ 2

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Condensed Statements of Cash Flows (Unaudited) - APC (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Net cash paid for capitalized interest	$ 46	$ 43
Alabama Power
Net cash paid for capitalized interest	$ 9	$ 7

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Condensed Balance Sheets (Unaudited) - APC - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,724	$ 1,798
Receivables —
Customer accounts	2,277	1,806
Unbilled revenues	807	711
Other accounts and notes	534	523
Accumulated provision for uncollectible accounts	(94)	(78)
Fossil fuel for generation	431	450
Materials and supplies	1,641	1,543
Prepaid expenses	528	330
Other regulatory assets	641	653
Other current assets	212	231
Total current assets	9,781	8,965
Property, Plant, and Equipment:
In service	117,418	115,592
Less: Accumulated depreciation	35,203	34,079
Plant in service, net of depreciation	82,215	81,513
Nuclear fuel, at amortized cost	837	824
Construction work in progress	9,770	8,771
Total property, plant, and equipment	92,822	91,108
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	2,150	2,542
Equity investments in unconsolidated subsidiaries	1,305	1,282
Miscellaneous property and investments	576	653
Total other property and investments	9,736	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,623	1,701
Deferred charges related to income taxes	843	824
Regulatory assets – asset retirement obligations, deferred	5,982	5,466
Other regulatory assets, deferred	5,448	5,577
Other deferred charges and assets	2,393	1,776
Total deferred charges and other assets	18,430	17,259
Total Assets	130,769	127,534
Current Liabilities:
Securities due within one year	1,052	2,157
Accounts payable —
Customer deposits	461	479
Accrued interest	553	533
Accrued compensation	807	1,070
Asset retirement obligations	693	697
Other regulatory liabilities	557	563
Other current liabilities	1,062	872
Total current liabilities	11,487	10,921
Long-term Debt	51,204	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,620	8,862
Deferred credits related to income taxes	5,318	5,401
Accumulated deferred ITCs	2,175	2,216
Employee benefit obligations	1,509	1,550
Operating lease obligations, deferred	1,464	1,503
Asset retirement obligations, deferred	11,010	10,990
Other cost of removal obligations	1,993	2,103
Other regulatory liabilities, deferred	536	485
Other deferred credits and liabilities	1,198	816
Total deferred credits and other liabilities	34,823	33,926
Total Liabilities	97,514	94,967
Redeemable preferred stock	242	291
Common Stockholder's Equity (See accompanying statements)	33,013	32,276
Total Liabilities and Stockholders' Equity	130,769	127,534
Alabama Power
Current Assets:
Cash and cash equivalents	908	1,060
Receivables —
Customer accounts	501	410
Unbilled revenues	189	138
Affiliated	85	37
Other accounts and notes	101	55
Accumulated provision for uncollectible accounts	(14)	(14)
Fossil fuel for generation	161	159
Materials and supplies	568	548
Prepaid expenses	147	41
Other regulatory assets	263	208
Other current assets	113	67
Total current assets	3,022	2,709
Property, Plant, and Equipment:
In service	33,596	33,135
Less: Accumulated depreciation	10,589	10,313
Plant in service, net of depreciation	23,007	22,822
Nuclear fuel, at amortized cost	251	247
Construction work in progress	1,319	1,147
Total property, plant, and equipment	24,577	24,216
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,124	1,325
Equity investments in unconsolidated subsidiaries	56	57
Miscellaneous property and investments	128	126
Total other property and investments	1,308	1,508
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	89	108
Deferred charges related to income taxes	246	240
Prepaid pension and other postretirement benefit costs	568	513
Regulatory assets – asset retirement obligations, deferred	1,845	1,547
Other regulatory assets, deferred	1,860	1,807
Other deferred charges and assets	395	334
Total deferred charges and other assets	5,003	4,549
Total Assets	33,910	32,982
Current Liabilities:
Securities due within one year	201	751
Accounts payable —
Affiliated	414	309
Other	351	459
Customer deposits	107	106
Accrued taxes	128	98
Accrued interest	109	100
Accrued compensation	174	219
Asset retirement obligations	325	320
Other regulatory liabilities	133	215
Other current liabilities	121	125
Total current liabilities	2,063	2,702
Long-term Debt	9,633	8,936
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,719	3,573
Deferred credits related to income taxes	1,944	1,968
Accumulated deferred ITCs	84	88
Employee benefit obligations	176	171
Operating lease obligations, deferred	66	66
Asset retirement obligations, deferred	3,998	4,014
Other cost of removal obligations	106	192
Other regulatory liabilities, deferred	227	210
Other deferred credits and liabilities	58	58
Total deferred credits and other liabilities	10,378	10,340
Total Liabilities	22,074	21,978
Redeemable preferred stock	242	291
Common Stockholder's Equity (See accompanying statements)	11,594	10,713
Total Liabilities and Stockholders' Equity	$ 33,910	$ 32,982

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Condensed Statements of Common Stockholders' Equity (Unaudited) - APC - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Alabama Power	Alabama Power Common Stock	Alabama Power Paid-In Capital	Alabama Power Retained Earnings (Accumulated Deficit)	Alabama Power Accumulated Other Comprehensive Income (Loss)
Beginning balance (in shares) at Dec. 31, 2020							31
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ 11,834	$ 11,311	$ (395)	$ 9,810	$ 1,222	$ 5,413	$ 3,194	$ (19)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock						359			359
Capital contributions from parent company						602		602
Other comprehensive income (loss)	28				28	1				1
Cash dividends on common stock	(678)			(678)		(246)			(246)
Other	1		2
Ending balance (in shares) at Mar. 31, 2021							31
Ending balance at Mar. 31, 2021	33,068	5,273	11,854	11,768	(367)	10,526	$ 1,222	6,015	3,307	(18)
Beginning balance (in shares) at Dec. 31, 2020							31
Beginning balance at Dec. 31, 2020	32,234	5,268	11,834	11,311	(395)	9,810	$ 1,222	5,413	3,194	(19)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock	1,508					690
Ending balance (in shares) at Jun. 30, 2021							31
Ending balance at Jun. 30, 2021	32,746	5,274	11,886	11,442	(355)	10,637	$ 1,222	6,041	3,391	(17)
Beginning balance (in shares) at Mar. 31, 2021							31
Beginning balance at Mar. 31, 2021	33,068	5,273	11,854	11,768	(367)	10,526	$ 1,222	6,015	3,307	(18)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock	372					331			331
Capital contributions from parent company						26		26
Other comprehensive income (loss)	12				12	1				1
Cash dividends on common stock	(699)			(699)		(246)			(246)
Other	0		1	1		(1)			(1)
Ending balance (in shares) at Jun. 30, 2021							31
Ending balance at Jun. 30, 2021	32,746	5,274	11,886	11,442	(355)	10,637	$ 1,222	6,041	3,391	(17)
Beginning balance (in shares) at Dec. 31, 2021							31
Beginning balance at Dec. 31, 2021	32,276	5,279	11,950	10,929	(237)	10,713	$ 1,222	6,056	3,448	(13)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock						347			347
Capital contributions from parent company						626		626
Other comprehensive income (loss)	42				42
Cash dividends on common stock	(702)			(702)		(254)			(254)
Other	7		7	2
Ending balance (in shares) at Mar. 31, 2022							31
Ending balance at Mar. 31, 2022	32,629	5,286	11,994	11,261	(195)	11,432	$ 1,222	6,682	3,541	(13)
Beginning balance (in shares) at Dec. 31, 2021							31
Beginning balance at Dec. 31, 2021	32,276	5,279	11,950	10,929	(237)	10,713	$ 1,222	6,056	3,448	(13)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock	2,139					730
Ending balance (in shares) at Jun. 30, 2022							31
Ending balance at Jun. 30, 2022	33,013	5,288	12,033	11,645	(184)	11,594	$ 1,222	6,714	3,670	(12)
Beginning balance (in shares) at Mar. 31, 2022							31
Beginning balance at Mar. 31, 2022	32,629	5,286	11,994	11,261	(195)	11,432	$ 1,222	6,682	3,541	(13)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock	1,107					383			383
Capital contributions from parent company						32		32
Other comprehensive income (loss)	11				11	1				1
Cash dividends on common stock	(723)			(723)		(254)			(254)
Other	2		4
Ending balance (in shares) at Jun. 30, 2022							31
Ending balance at Jun. 30, 2022	$ 33,013	$ 5,288	$ 12,033	$ 11,645	$ (184)	$ 11,594	$ 1,222	$ 6,714	$ 3,670	$ (12)

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Condensed Statements of Income (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating Revenues:
Total operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Operating Expenses:
Other operations and maintenance	1,558	1,438	3,075	2,810
Depreciation and amortization	913	891	1,805	1,762
Taxes other than income taxes	349	313	721	657
Estimated loss on Plant Vogtle Units 3 and 4	52	460	52	508
Total operating expenses	5,551	4,490	10,815	8,802
Operating Income	1,655	708	3,039	2,306
Other Income and (Expense):
Allowance for equity funds used during construction	53	45	104	90
Interest expense, net of amounts capitalized	(488)	(450)	(950)	(901)
Other income (expense), net	139	101	283	160
Total other income and (expense)	(262)	(344)	(483)	(646)
Earnings (Loss) Before Income Taxes	1,393	364	2,556	1,660
Income taxes (benefit)	304	(12)	477	178
Consolidated Net Income	1,089	376	2,079	1,482
Retail electric revenues
Operating Revenues:
Total operating revenues	4,789	3,599	8,402	6,941
Wholesale Electric
Operating Revenues:
Total operating revenues	937	546	1,601	1,091
Other electric revenues
Operating Revenues:
Total operating revenues	192	175	370	346
Natural Gas
Operating Revenues:
Total operating revenues	1,083	677	3,140	2,371
Other revenues
Operating Revenues:
Total operating revenues	205	201	341	359
Operating Expenses:
Less Gross Gas Costs	114	103	183	185
Fuel
Operating Expenses:
Less Gross Gas Costs	1,715	848	2,826	1,696
Purchased power
Operating Expenses:
Less Gross Gas Costs	408	217	640	424
GEORGIA POWER CO
Operating Revenues:
Total operating revenues	3,121	2,225	5,328	4,195
Operating Expenses:
Other operations and maintenance	573	542	1,091	1,015
Depreciation and amortization	356	342	706	680
Taxes other than income taxes	141	118	265	235
Estimated loss on Plant Vogtle Units 3 and 4	52	460	52	508
Total operating expenses	2,319	2,098	4,085	3,667
Operating Income	802	127	1,243	528
Other Income and (Expense):
Allowance for equity funds used during construction	33	30	65	61
Interest expense, net of amounts capitalized	(117)	(106)	(224)	(210)
Other income (expense), net	54	42	103	83
Total other income and (expense)	(30)	(34)	(56)	(66)
Earnings (Loss) Before Income Taxes	772	93	1,187	462
Income taxes (benefit)	164	(50)	194	(32)
Consolidated Net Income	608	143	993	494
GEORGIA POWER CO | Retail electric revenues
Operating Revenues:
Total operating revenues	2,908	2,026	4,926	3,813
GEORGIA POWER CO | Wholesale Electric
Operating Revenues:
Total operating revenues	64	36	130	80
GEORGIA POWER CO | Other revenues
Operating Revenues:
Total operating revenues	149	163	272	302
GEORGIA POWER CO | Fuel
Operating Expenses:
Less Gross Gas Costs	628	343	1,046	656
GEORGIA POWER CO | Purchased power
Operating Expenses:
Less Gross Gas Costs	246	144	396	288
GEORGIA POWER CO | Purchased power, affiliates
Operating Expenses:
Less Gross Gas Costs	$ 323	$ 149	$ 529	$ 285

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Condensed Statements of Comprehensive Income (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 1,089	$ 376	$ 2,079	$ 1,482
Qualifying hedges:
Changes in fair value, net of tax	(45)	14	(26)	(16)
Reclassification adjustment for amounts included in net income, net of tax	54	(5)	74	50
Total other comprehensive income	11	12	53	40
Comprehensive Income	1,100	388	2,132	1,522
GEORGIA POWER CO
Net income	608	143	993	494
Qualifying hedges:
Changes in fair value, net of tax	15	0	23	0
Reclassification adjustment for amounts included in net income, net of tax	1	1	3	3
Total other comprehensive income	16	1	26	3
Comprehensive Income	$ 624	$ 144	$ 1,019	$ 497

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Condensed Statements of Comprehensive Income (Unaudited) - GPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Changes in fair value, tax	$ (15)	$ 5	$ (7)	$ (5)
Qualifying hedges, reclassification adjustment, tax	17	(1)	24	17
GEORGIA POWER CO
Changes in fair value, tax	4	0	8	0
Qualifying hedges, reclassification adjustment, tax	$ 0	$ 1	$ 1	$ 1

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Condensed Statements of Cash Flows (Unaudited) - GPC - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating Activities:
Net income (loss)	$ 2,079	$ 1,482
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,995	1,949
Deferred income taxes	240	(101)
Allowance for equity funds used during construction	(104)	(90)
Pension, postretirement, and other employee benefits	(211)	(115)
Settlement of asset retirement obligations	(198)	(228)
Storm damage accruals	107	112
Retail fuel cost under recovery – long-term	(729)	0
Estimated loss on Plant Vogtle Units 3 and 4	52	508
Other, net	21	117
Changes in certain current assets and liabilities —
Receivables	(637)	29
Materials and supplies	(109)	(57)
Other current assets	12	94
Accounts payable	703	(177)
Accrued compensation	(260)	(238)
Retail fuel cost over recovery	0	(146)
Other current liabilities	30	(235)
Net cash provided from operating activities	3,579	2,904
Investing Activities:
Property additions	(3,213)	(3,384)
Nuclear decommissioning trust fund purchases	(628)	(930)
Nuclear decommissioning trust fund sales	624	926
Cost of removal, net of salvage	(377)	(184)
Proceeds from dispositions	119	25
Other investing activities	96	(20)
Net cash used for investing activities	(3,460)	(4,026)
Financing Activities:
Increase (decrease) in notes payable, net	263	492
Proceeds —
Short-term borrowings	1,200	325
Redemptions and repurchases —
Short-term borrowings	(400)	(25)
Payment of common stock dividends	(1,425)	(1,377)
Other financing activities	(219)	(167)
Net cash provided from (used for) financing activities	(213)	1,671
Net Change in Cash, Cash Equivalents, and Restricted Cash	(94)	549
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,735	1,617
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	836	884
Income taxes, net	157	88
Noncash transactions —
Accrued property additions at year-end	837	943
GEORGIA POWER CO
Operating Activities:
Net income (loss)	993	494
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	803	772
Deferred income taxes	72	(309)
Allowance for equity funds used during construction	(65)	(61)
Pension, postretirement, and other employee benefits	(114)	(59)
Settlement of asset retirement obligations	(91)	(100)
Storm damage accruals	107	107
Retail fuel cost under recovery – long-term	(538)	0
Estimated loss on Plant Vogtle Units 3 and 4	52	508
Other, net	7	90
Changes in certain current assets and liabilities —
Receivables	(424)	(73)
Fossil fuel stock	31	55
Materials and supplies	(46)	(46)
Other current assets	(25)	15
Accounts payable	235	83
Accrued compensation	(50)	(39)
Retail fuel cost over recovery	0	(113)
Other current liabilities	(21)	(11)
Net cash provided from operating activities	926	1,313
Investing Activities:
Property additions	(1,654)	(1,575)
Nuclear decommissioning trust fund purchases	(448)	(458)
Nuclear decommissioning trust fund sales	444	453
Cost of removal, net of salvage	(207)	(73)
Change in construction payables, net of joint owner portion	51	(72)
Contributions in aid of construction	109	45
Proceeds from dispositions	56	3
Other investing activities	(19)	(53)
Net cash used for investing activities	(1,668)	(1,730)
Financing Activities:
Increase (decrease) in notes payable, net	0	250
Proceeds —
Senior notes	1,500	750
FFB loan	0	371
Short-term borrowings	650	0
Redemptions and repurchases —
Senior notes	(400)	(325)
Pollution control revenue bonds	0	(69)
FFB loan	(45)	(45)
Short-term borrowings	(250)	0
Other long-term debt	(125)	0
Capital contributions from parent company	491	368
Payment of common stock dividends	(845)	(824)
Other financing activities	(37)	(19)
Net cash provided from (used for) financing activities	939	457
Net Change in Cash, Cash Equivalents, and Restricted Cash	197	40
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	33	9
Cash, Cash Equivalents, and Restricted Cash at End of Period	230	49
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	188	182
Income taxes, net	106	139
Noncash transactions —
Accrued property additions at year-end	500	476
Right-of-use assets obtained under operating leases	$ 1	$ 3

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Condensed Statements of Cash Flows (Unaudited) - GPC (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Net cash paid for capitalized interest	$ 46	$ 43
GEORGIA POWER CO
Net cash paid for capitalized interest	$ 33	$ 30

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Condensed Balance Sheets (Unaudited) - GPC - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,724	$ 1,798
Receivables —
Customer accounts	2,277	1,806
Unbilled revenues	807	711
Other accounts and notes	534	523
Fossil fuel for generation	431	450
Materials and supplies	1,641	1,543
Regulatory assets – asset retirement obligations	263	219
Assets from risk management activities	247	151
Other regulatory assets	641	653
Other current assets	212	231
Total current assets	9,781	8,965
Property, Plant, and Equipment:
In service	117,418	115,592
Less: Accumulated depreciation	35,203	34,079
Plant in service, net of depreciation	82,215	81,513
Nuclear fuel, at amortized cost	837	824
Construction work in progress	9,770	8,771
Total property, plant, and equipment	92,822	91,108
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	2,150	2,542
Equity investments in unconsolidated subsidiaries	1,305	1,282
Miscellaneous property and investments	576	653
Total other property and investments	9,736	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,623	1,701
Deferred charges related to income taxes	843	824
Prepaid pension costs	1,893	1,657
Regulatory assets – asset retirement obligations, deferred	5,982	5,466
Other regulatory assets, deferred	5,448	5,577
Other deferred charges and assets	2,393	1,776
Total deferred charges and other assets	18,430	17,259
Total Assets	130,769	127,534
Current Liabilities:
Securities due within one year	1,052	2,157
Notes payable	2,510	1,440
Accounts payable —
Customer deposits	461	479
Accrued interest	553	533
Accrued compensation	807	1,070
Operating lease obligations	232	250
Asset retirement obligations	693	697
Other regulatory liabilities	557	563
Other current liabilities	1,062	872
Total current liabilities	11,487	10,921
Long-term Debt	51,204	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,620	8,862
Deferred credits related to income taxes	5,318	5,401
Accumulated deferred ITCs	2,175	2,216
Employee benefit obligations	1,509	1,550
Operating lease obligations, deferred	1,464	1,503
Asset retirement obligations, deferred	11,010	10,990
Other deferred credits and liabilities	1,198	816
Total deferred credits and other liabilities	34,823	33,926
Total Liabilities	97,514	94,967
Common Stockholder's Equity (See accompanying statements)	33,013	32,276
Total Liabilities and Stockholders' Equity	130,769	127,534
GEORGIA POWER CO
Current Assets:
Cash and cash equivalents	230	33
Receivables —
Customer accounts	830	547
Unbilled revenues	450	231
Joint owner accounts	44	116
Affiliated	54	25
Other accounts and notes	33	44
Fossil fuel for generation	218	248
Materials and supplies	712	670
Regulatory assets – asset retirement obligations	222	178
Assets from risk management activities	94	48
Other regulatory assets	244	289
Other current assets	124	130
Total current assets	3,255	2,559
Property, Plant, and Equipment:
In service	42,067	41,332
Less: Accumulated depreciation	13,233	12,854
Plant in service, net of depreciation	28,834	28,478
Nuclear fuel, at amortized cost	586	577
Construction work in progress	7,420	6,688
Total property, plant, and equipment	36,840	35,743
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,025	1,217
Equity investments in unconsolidated subsidiaries	51	50
Miscellaneous property and investments	75	69
Total other property and investments	1,151	1,336
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,083	1,157
Deferred charges related to income taxes	564	550
Prepaid pension costs	652	563
Deferred under recovered fuel clause revenues	948	410
Regulatory assets – asset retirement obligations, deferred	3,896	3,688
Other regulatory assets, deferred	2,073	1,964
Other deferred charges and assets	512	491
Total deferred charges and other assets	9,728	8,823
Total Assets	50,974	48,461
Current Liabilities:
Securities due within one year	248	675
Notes payable	400	0
Accounts payable —
Affiliated	863	757
Other	892	702
Customer deposits	255	259
Accrued taxes	322	335
Accrued interest	150	136
Accrued compensation	174	232
Operating lease obligations	157	156
Asset retirement obligations	312	317
Other regulatory liabilities	260	280
Other current liabilities	258	254
Total current liabilities	4,291	4,103
Long-term Debt	14,450	13,109
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,318	3,019
Deferred credits related to income taxes	2,283	2,321
Accumulated deferred ITCs	323	328
Employee benefit obligations	384	402
Operating lease obligations, deferred	950	999
Asset retirement obligations, deferred	6,537	6,507
Other deferred credits and liabilities	541	439
Total deferred credits and other liabilities	14,336	14,015
Total Liabilities	33,077	31,227
Common Stockholder's Equity (See accompanying statements)	17,897	17,234
Total Liabilities and Stockholders' Equity	$ 50,974	$ 48,461

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Condensed Statements of Common Stockholders' Equity (Unaudited) - GPC - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	GEORGIA POWER CO	GEORGIA POWER CO Common Stock	GEORGIA POWER CO Paid-In Capital	GEORGIA POWER CO Retained Earnings (Accumulated Deficit)	GEORGIA POWER CO Accumulated Other Comprehensive Income (Loss)
Beginning balance (in shares) at Dec. 31, 2020							9
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ 11,834	$ 11,311	$ (395)	$ 16,501	$ 398	$ 12,361	$ 3,789	$ (47)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income						351			351
Capital contributions from parent company						332		332
Other comprehensive income (loss)	28				28	2				2
Cash dividends on common stock	(678)			(678)		(412)			(412)
Ending balance (in shares) at Mar. 31, 2021							9
Ending balance at Mar. 31, 2021	33,068	5,273	11,854	11,768	(367)	16,774	$ 398	12,693	3,728	(45)
Beginning balance (in shares) at Dec. 31, 2020							9
Beginning balance at Dec. 31, 2020	32,234	5,268	11,834	11,311	(395)	16,501	$ 398	12,361	3,789	(47)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,482					494
Ending balance (in shares) at Jun. 30, 2021							9
Ending balance at Jun. 30, 2021	32,746	5,274	11,886	11,442	(355)	16,546	$ 398	12,733	3,459	(44)
Beginning balance (in shares) at Mar. 31, 2021							9
Beginning balance at Mar. 31, 2021	33,068	5,273	11,854	11,768	(367)	16,774	$ 398	12,693	3,728	(45)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	376					143			143
Capital contributions from parent company						40		40
Other comprehensive income (loss)	12				12	1				1
Cash dividends on common stock	(699)			(699)		(412)			(412)
Ending balance (in shares) at Jun. 30, 2021							9
Ending balance at Jun. 30, 2021	32,746	5,274	11,886	11,442	(355)	16,546	$ 398	12,733	3,459	(44)
Beginning balance (in shares) at Dec. 31, 2021							9
Beginning balance at Dec. 31, 2021	32,276	5,279	11,950	10,929	(237)	17,234	$ 398	14,153	2,724	(41)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income						385			385
Capital contributions from parent company						443		443
Other comprehensive income (loss)	42				42	10				10
Cash dividends on common stock	(702)			(702)		(423)			(423)
Ending balance (in shares) at Mar. 31, 2022							9
Ending balance at Mar. 31, 2022	32,629	5,286	11,994	11,261	(195)	17,649	$ 398	14,596	2,686	(31)
Beginning balance (in shares) at Dec. 31, 2021							9
Beginning balance at Dec. 31, 2021	32,276	5,279	11,950	10,929	(237)	17,234	$ 398	14,153	2,724	(41)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,079					993
Ending balance (in shares) at Jun. 30, 2022							9
Ending balance at Jun. 30, 2022	33,013	5,288	12,033	11,645	(184)	17,897	$ 398	14,642	2,872	(15)
Beginning balance (in shares) at Mar. 31, 2022							9
Beginning balance at Mar. 31, 2022	32,629	5,286	11,994	11,261	(195)	17,649	$ 398	14,596	2,686	(31)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,089					608			608
Capital contributions from parent company						46		46
Other comprehensive income (loss)	11				11	16				16
Cash dividends on common stock	(723)			(723)		(422)			(422)
Ending balance (in shares) at Jun. 30, 2022							9
Ending balance at Jun. 30, 2022	$ 33,013	$ 5,288	$ 12,033	$ 11,645	$ (184)	$ 17,897	$ 398	$ 14,642	$ 2,872	$ (15)

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Condensed Statements of Common Stockholders' Equity (Unaudited) - GPC (Parenthetical) - $ / shares	3 Months Ended
	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2021	Mar. 31, 2021
Statement of Stockholders' Equity [Abstract]
Cash dividends (in dollars per share)	$ 0.68	$ 0.66	$ 0.66	$ 0.64

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Condensed Statements of Income (Unaudited) - MPC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating Revenues:
Total operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Operating Expenses:
Other operations and maintenance	1,558	1,438	3,075	2,810
Depreciation and amortization	913	891	1,805	1,762
Taxes other than income taxes	349	313	721	657
Total operating expenses	5,551	4,490	10,815	8,802
Operating Income	1,655	708	3,039	2,306
Other Income and (Expense):
Interest expense, net of amounts capitalized	(488)	(450)	(950)	(901)
Other income (expense), net	139	101	283	160
Total other income and (expense)	(262)	(344)	(483)	(646)
Earnings (Loss) Before Income Taxes	1,393	364	2,556	1,660
Income taxes (benefit)	304	(12)	477	178
Consolidated Net Income	1,089	376	2,079	1,482
Retail electric revenues
Operating Revenues:
Total operating revenues	4,789	3,599	8,402	6,941
Wholesale Electric
Operating Revenues:
Total operating revenues	937	546	1,601	1,091
Other electric revenues
Operating Revenues:
Total operating revenues	192	175	370	346
Natural Gas
Operating Revenues:
Total operating revenues	1,083	677	3,140	2,371
Other revenues
Operating Revenues:
Total operating revenues	205	201	341	359
Operating Expenses:
Total cost of sales	114	103	183	185
Mississippi Power
Operating Revenues:
Total operating revenues	434	303	769	610
Operating Expenses:
Other operations and maintenance	91	76	167	144
Depreciation and amortization	45	44	90	91
Taxes other than income taxes	32	32	61	63
Total operating expenses	375	254	657	506
Operating Income	59	49	112	104
Other Income and (Expense):
Interest expense, net of amounts capitalized	(14)	(14)	(27)	(29)
Other income (expense), net	12	11	22	20
Total other income and (expense)	(2)	(3)	(5)	(9)
Earnings (Loss) Before Income Taxes	57	46	107	95
Income taxes (benefit)	12	8	20	12
Consolidated Net Income	45	38	87	83
Mississippi Power | Retail electric revenues
Operating Revenues:
Total operating revenues	252	219	469	422
Mississippi Power | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	63	54	131	117
Mississippi Power | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	107	25	149	57
Mississippi Power | Other revenues
Operating Revenues:
Total operating revenues	12	5	20	14
Mississippi Power | Fuel and purchased power
Operating Expenses:
Total cost of sales	$ 207	$ 102	$ 339	$ 208

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Condensed Statements of Comprehensive Income - MPC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 1,089	$ 376	$ 2,079	$ 1,482
Qualifying hedges:
Reclassification adjustment for amounts included in net income, net of tax	54	(5)	74	50
Total other comprehensive income	11	12	53	40
Comprehensive Income	1,100	388	2,132	1,522
Mississippi Power
Net income	45	38	87	83
Qualifying hedges:
Reclassification adjustment for amounts included in net income, net of tax	0	0	0	1
Total other comprehensive income	0	0	0	1
Comprehensive Income	$ 45	$ 38	$ 87	$ 84

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Condensed Statements of Comprehensive Income - MPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Qualifying hedges, reclassification adjustment, tax	$ 17	$ (1)	$ 24	$ 17
Mississippi Power
Qualifying hedges, reclassification adjustment, tax	$ 0	$ 0	$ 0	$ 0

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Condensed Statements of Cash Flows (Unaudited) - MPC - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating Activities:
Net income (loss)	$ 2,079	$ 1,482
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,995	1,949
Other, net	21	117
Changes in certain current assets and liabilities —
Receivables	(637)	29
Other current assets	12	94
Accounts payable	703	(177)
Accrued taxes	(150)	(157)
Retail fuel cost over recovery	0	(146)
Other current liabilities	30	(235)
Net cash provided from operating activities	3,579	2,904
Investing Activities:
Property additions	(3,213)	(3,384)
Payments pursuant to LTSAs	(81)	(114)
Other investing activities	96	(20)
Net cash used for investing activities	(3,460)	(4,026)
Financing Activities:
Increase (decrease) in notes payable, net	263	492
Payment of common stock dividends	(1,425)	(1,377)
Other financing activities	(219)	(167)
Net cash provided from (used for) financing activities	(213)	1,671
Net Change in Cash, Cash Equivalents, and Restricted Cash	(94)	549
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,735	1,617
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	836	884
Income taxes, net	157	88
Noncash transactions —
Accrued property additions at year-end	837	943
Mississippi Power
Operating Activities:
Net income (loss)	87	83
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	110	106
Other, net	13	(28)
Changes in certain current assets and liabilities —
Receivables	(92)	1
Retail fuel cost under recovery	(25)	0
Other current assets	(23)	(4)
Accounts payable	79	(33)
Accrued taxes	(36)	(51)
Retail fuel cost over recovery	0	(15)
Other current liabilities	(1)	(18)
Net cash provided from operating activities	112	41
Investing Activities:
Property additions	(87)	(90)
Construction payables	(16)	(3)
Payments pursuant to LTSAs	(15)	(14)
Other investing activities	(15)	(10)
Net cash used for investing activities	(133)	(117)
Financing Activities:
Increase (decrease) in notes payable, net	16
Increase (decrease) in notes payable, net		(25)
Proceeds — Senior notes	0	525
Capital contributions from parent company	51	101
Payment of common stock dividends	(85)	(79)
Other financing activities	0	(7)
Net cash provided from (used for) financing activities	(18)	515
Net Change in Cash, Cash Equivalents, and Restricted Cash	(39)	439
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	61	39
Cash, Cash Equivalents, and Restricted Cash at End of Period	22	478
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	26	31
Income taxes, net	5	7
Noncash transactions —
Accrued property additions at year-end	$ 9	$ 31

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Condensed Statements of Cash Flows (Unaudited) - MPC (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Net cash paid for capitalized interest	$ 46	$ 43

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Condensed Balance Sheets (Unaudited) - MPC - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,724	$ 1,798
Receivables —
Customer accounts	2,277	1,806
Unbilled revenues	807	711
Other accounts and notes	534	523
Fossil fuel for generation	431	450
Materials and supplies	1,641	1,543
Assets from risk management activities	247	151
Other regulatory assets	641	653
Other current assets	212	231
Total current assets	9,781	8,965
Property, Plant, and Equipment:
In service	117,418	115,592
Less: Accumulated depreciation	35,203	34,079
Plant in service, net of depreciation	82,215	81,513
Construction work in progress	9,770	8,771
Total property, plant, and equipment	92,822	91,108
Other Property and Investments:
Total other property and investments	9,736	10,202
Deferred Charges and Other Assets:
Deferred charges related to income taxes	843	824
Regulatory assets – asset retirement obligations, deferred	5,982	5,466
Other regulatory assets, deferred	5,448	5,577
Other deferred charges and assets	2,393	1,776
Total deferred charges and other assets	18,430	17,259
Total Assets	130,769	127,534
Current Liabilities:
Securities due within one year	1,052	2,157
Notes payable	2,510	1,440
Accounts payable —
Accrued compensation	807	1,070
Asset retirement obligations	693	697
Other regulatory liabilities	557	563
Other current liabilities	1,062	872
Total current liabilities	11,487	10,921
Long-term Debt	51,204	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,620	8,862
Deferred credits related to income taxes	5,318	5,401
Employee benefit obligations	1,509	1,550
Asset retirement obligations, deferred	11,010	10,990
Other cost of removal obligations	1,993	2,103
Other regulatory liabilities, deferred	536	485
Other deferred credits and liabilities	1,198	816
Total deferred credits and other liabilities	34,823	33,926
Total Liabilities	97,514	94,967
Total Liabilities and Stockholders' Equity	130,769	127,534
Mississippi Power
Current Assets:
Cash and cash equivalents	22	61
Receivables —
Customer accounts	89	37
Unbilled revenues	44	34
Affiliated	76	29
Other accounts and notes	37	28
Fossil fuel for generation	33	28
Materials and supplies	76	70
Assets from risk management activities	62	28
Other regulatory assets	62	54
Other current assets	15	13
Total current assets	516	382
Property, Plant, and Equipment:
In service	5,197	5,106
Less: Accumulated depreciation	1,648	1,591
Plant in service, net of depreciation	3,549	3,515
Construction work in progress	127	127
Total property, plant, and equipment	3,676	3,642
Other Property and Investments:
Total other property and investments	175	179
Deferred Charges and Other Assets:
Deferred charges related to income taxes	30	31
Prepaid pension costs	91	79
Regulatory assets – asset retirement obligations, deferred	236	232
Other regulatory assets, deferred	286	317
Accumulated deferred income taxes	112	118
Other deferred charges and assets	129	100
Total deferred charges and other assets	884	877
Total Assets	5,251	5,080
Current Liabilities:
Securities due within one year	1	1
Notes payable	16	0
Accounts payable —
Affiliated	129	81
Other	62	47
Accrued taxes	83	120
Accrued compensation	28	36
Asset retirement obligations	24	30
Other regulatory liabilities	92	59
Other current liabilities	96	65
Total current liabilities	531	439
Long-term Debt	1,510	1,510
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	466	464
Deferred credits related to income taxes	265	269
Employee benefit obligations	88	88
Asset retirement obligations, deferred	162	160
Other cost of removal obligations	193	195
Other regulatory liabilities, deferred	91	64
Other deferred credits and liabilities	24	24
Total deferred credits and other liabilities	1,289	1,264
Total Liabilities	3,330	3,213
Total common stockholders' equity	1,921	1,867
Total Liabilities and Stockholders' Equity	$ 5,251	$ 5,080

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Condensed Statements of Common Stockholders' Equity (Unaudited) - MPC - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Mississippi Power	Mississippi Power Common Stock	Mississippi Power Paid-In Capital	Mississippi Power Retained Earnings (Accumulated Deficit)	Mississippi Power Accumulated Other Comprehensive Income (Loss)
Beginning balance (in shares) at Dec. 31, 2020							1
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ 11,834	$ 11,311	$ (395)	$ 1,742	$ 38	$ 4,460	$ (2,754)	$ (2)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income						45			45
Capital contributions from parent company						100		100
Cash dividends on common stock	(678)			(678)		(39)			(39)
Other	1		2
Ending balance (in shares) at Mar. 31, 2021							1
Ending balance at Mar. 31, 2021	33,068	5,273	11,854	11,768	(367)	1,848	$ 38	4,560	(2,748)	(2)
Beginning balance (in shares) at Dec. 31, 2020							1
Beginning balance at Dec. 31, 2020	32,234	5,268	11,834	11,311	(395)	1,742	$ 38	4,460	(2,754)	(2)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,508
Ending balance (in shares) at Jun. 30, 2021							1
Ending balance at Jun. 30, 2021	32,746	5,274	11,886	11,442	(355)	1,849	$ 38	4,562	(2,750)	(1)
Beginning balance (in shares) at Mar. 31, 2021							1
Beginning balance at Mar. 31, 2021	33,068	5,273	11,854	11,768	(367)	1,848	$ 38	4,560	(2,748)	(2)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	372					38			38
Capital contributions from parent company						2		2
Cash dividends on common stock	(699)			(699)		(39)			(39)
Other	0		1	1					(1)	1
Ending balance (in shares) at Jun. 30, 2021							1
Ending balance at Jun. 30, 2021	32,746	5,274	11,886	11,442	(355)	1,849	$ 38	4,562	(2,750)	(1)
Beginning balance (in shares) at Dec. 31, 2021							1
Beginning balance at Dec. 31, 2021	32,276	5,279	11,950	10,929	(237)	1,867	$ 38	4,582	(2,753)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income						42			42
Capital contributions from parent company						51		51
Cash dividends on common stock	(702)			(702)		(43)			(43)
Other	7		7	2
Ending balance (in shares) at Mar. 31, 2022							1
Ending balance at Mar. 31, 2022	32,629	5,286	11,994	11,261	(195)	1,917	$ 38	4,633	(2,754)	0
Beginning balance (in shares) at Dec. 31, 2021							1
Beginning balance at Dec. 31, 2021	32,276	5,279	11,950	10,929	(237)	1,867	$ 38	4,582	(2,753)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,139
Ending balance (in shares) at Jun. 30, 2022							1
Ending balance at Jun. 30, 2022	33,013	5,288	12,033	11,645	(184)	1,921	$ 38	4,634	(2,751)	0
Beginning balance (in shares) at Mar. 31, 2022							1
Beginning balance at Mar. 31, 2022	32,629	5,286	11,994	11,261	(195)	1,917	$ 38	4,633	(2,754)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,107					45			45
Capital contributions from parent company						1		1
Cash dividends on common stock	(723)			(723)		(42)			(42)
Other	2		4
Ending balance (in shares) at Jun. 30, 2022							1
Ending balance at Jun. 30, 2022	$ 33,013	$ 5,288	$ 12,033	$ 11,645	$ (184)	$ 1,921	$ 38	$ 4,634	$ (2,751)	$ 0

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Condensed Consolidated Statements of Income (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating Revenues:
Total operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Operating Expenses:
Other operations and maintenance	1,558	1,438	3,075	2,810
Depreciation and amortization	913	891	1,805	1,762
Taxes other than income taxes	349	313	721	657
Gain on dispositions, net	(10)	(11)	(33)	(54)
Total operating expenses	5,551	4,490	10,815	8,802
Operating Income	1,655	708	3,039	2,306
Other Income and (Expense):
Interest expense, net of amounts capitalized	(488)	(450)	(950)	(901)
Other income (expense), net	139	101	283	160
Total other income and (expense)	(262)	(344)	(483)	(646)
Earnings (Loss) Before Income Taxes	1,393	364	2,556	1,660
Income taxes (benefit)	304	(12)	477	178
Consolidated Net Income	1,089	376	2,079	1,482
Net loss attributable to noncontrolling interests	(22)	0	(67)	(33)
Net Income	1,107	372	2,139	1,508
Retail electric revenues
Operating Revenues:
Total operating revenues	4,789	3,599	8,402	6,941
Wholesale Electric
Operating Revenues:
Total operating revenues	937	546	1,601	1,091
Other electric revenues
Operating Revenues:
Total operating revenues	192	175	370	346
Natural Gas
Operating Revenues:
Total operating revenues	1,083	677	3,140	2,371
Other revenues
Operating Revenues:
Total operating revenues	205	201	341	359
Operating Expenses:
Total cost of sales	114	103	183	185
Fuel
Operating Expenses:
Total cost of sales	1,715	848	2,826	1,696
Purchased power
Operating Expenses:
Total cost of sales	408	217	640	424
SOUTHERN POWER CO
Operating Revenues:
Total operating revenues	899	490	1,438	930
Operating Expenses:
Other operations and maintenance	115	111	220	211
Depreciation and amortization	131	132	251	251
Taxes other than income taxes	12	12	25	24
Gain on dispositions, net	0	0	(2)	(39)
Total operating expenses	763	420	1,252	774
Operating Income	136	70	186	156
Other Income and (Expense):
Interest expense, net of amounts capitalized	(36)	(37)	(73)	(75)
Other income (expense), net	1	1	3	8
Total other income and (expense)	(35)	(36)	(70)	(67)
Earnings (Loss) Before Income Taxes	101	34	116	89
Income taxes (benefit)	25	(2)	13	(11)
Consolidated Net Income	76	36	103	100
Net loss attributable to noncontrolling interests	(22)	0	(67)	(33)
Net Income	98	36	170	133
SOUTHERN POWER CO | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	658	373	1,084	728
SOUTHERN POWER CO | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	232	112	337	193
SOUTHERN POWER CO | Other revenues
Operating Revenues:
Total operating revenues	9	5	17	9
SOUTHERN POWER CO | Fuel
Operating Expenses:
Total cost of sales	437	140	669	281
SOUTHERN POWER CO | Purchased power
Operating Expenses:
Total cost of sales	$ 68	$ 25	$ 89	$ 46

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 1,089	$ 376	$ 2,079	$ 1,482
Qualifying hedges:
Changes in fair value, net of tax	(45)	14	(26)	(16)
Reclassification adjustment for amounts included in net income, net of tax	54	(5)	74	50
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	2	3	5	6
Total other comprehensive income	11	12	53	40
Comprehensive Income	1,100	388	2,132	1,522
Comprehensive loss attributable to noncontrolling interests	(22)	0	(67)	(33)
Comprehensive Income	1,118	384	2,192	1,548
SOUTHERN POWER CO
Net income	76	36	103	100
Qualifying hedges:
Changes in fair value, net of tax	(54)	6	(72)	(26)
Reclassification adjustment for amounts included in net income, net of tax	57	(9)	79	38
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	0	0	1	1
Total other comprehensive income	3	(3)	8	13
Comprehensive Income	79	33	111	113
Comprehensive loss attributable to noncontrolling interests	(22)	0	(67)	(33)
Comprehensive Income	$ 101	$ 33	$ 178	$ 146

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Changes in fair value, tax	$ (15)	$ 5	$ (7)	$ (5)
Qualifying hedges, reclassification adjustment, tax	17	(1)	24	17
Reclassification adjustment for amounts included in net income, tax	1	2	2	3
SOUTHERN POWER CO
Changes in fair value, tax	(18)	2	(23)	(8)
Qualifying hedges, reclassification adjustment, tax	19	(3)	26	13
Reclassification adjustment for amounts included in net income, tax	$ 0	$ 1	$ 0	$ 1

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Condensed Consolidated Statements of Cash Flows (Unaudited) - SPC - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating Activities:
Net income (loss)	$ 2,079	$ 1,482
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,995	1,949
Deferred income taxes	240	(101)
Utilization of federal investment tax credits	281	224
Other, net	21	117
Changes in certain current assets and liabilities —
Receivables	(637)	29
Other current assets	12	94
Accounts payable	703	(177)
Accrued taxes	(150)	(157)
Other current liabilities	30	(235)
Net cash provided from operating activities	3,579	2,904
Investing Activities:
Business acquisitions, net of cash acquired	0	(345)
Property additions	(3,213)	(3,384)
Payments pursuant to LTSAs	(81)	(114)
Other investing activities	96	(20)
Net cash used for investing activities	(3,460)	(4,026)
Financing Activities:
Increase (decrease) in notes payable, net	263	492
Proceeds —
Capital contributions from noncontrolling interests	73	343
Distributions to noncontrolling interests	(115)	(113)
Payment of common stock dividends	(1,425)	(1,377)
Other financing activities	(219)	(167)
Net cash provided from (used for) financing activities	(213)	1,671
Net Change in Cash, Cash Equivalents, and Restricted Cash	(94)	549
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,735	1,617
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	836	884
Income taxes, net	157	88
Noncash transactions —
Contributions from noncontrolling interests	0	89
Contributions of wind turbine equipment	0	82
Accrued property additions at year-end	837	943
Reassessment of right-of-use assets under operating leases	40	0
SOUTHERN POWER CO
Operating Activities:
Net income (loss)	103	100
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	264	264
Deferred income taxes	14	(20)
Utilization of federal investment tax credits	239	205
Amortization of investment tax credits	(29)	(29)
Gain on dispositions, net	(2)	(39)
Other, net	(25)	(18)
Changes in certain current assets and liabilities —
Receivables	(161)	(91)
Prepaid income taxes	22	28
Other current assets	(6)	2
Accounts payable	114	14
Accrued taxes	42	8
Other current liabilities	(23)	(13)
Net cash provided from operating activities	552	411
Investing Activities:
Business acquisitions, net of cash acquired	0	(345)
Property additions	(34)	(224)
Proceeds from dispositions	48	17
Change in construction payables	(54)	(14)
Payments pursuant to LTSAs	(33)	(47)
Other investing activities	0	12
Net cash used for investing activities	(73)	(601)
Financing Activities:
Increase (decrease) in notes payable, net	94
Increase (decrease) in notes payable, net		(56)
Proceeds —
Senior notes	0	400
Capital contributions from parent company	326	4
Redemptions — Senior notes	(677)	0
Return of capital to parent company	0	(271)
Capital contributions from noncontrolling interests	73	343
Distributions to noncontrolling interests	(115)	(113)
Payment of common stock dividends	(99)	(102)
Other financing activities	(5)	(9)
Net cash provided from (used for) financing activities	(403)	196
Net Change in Cash, Cash Equivalents, and Restricted Cash	76	6
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	135	183
Cash, Cash Equivalents, and Restricted Cash at End of Period	211	189
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	91	91
Income taxes, net	(263)	(189)
Noncash transactions —
Contributions from noncontrolling interests	0	89
Contributions of wind turbine equipment	0	82
Accrued property additions at year-end	28	59
Right-of-use assets obtained under operating leases	0	65
Reassessment of right-of-use assets under operating leases	$ 40	$ 0

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Condensed Consolidated Statements of Cash Flows (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Net cash paid for capitalized interest	$ 46	$ 43
SOUTHERN POWER CO
Net cash paid for capitalized interest	$ 0	$ 2

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Condensed Consolidated Balance Sheets (Unaudited) - SPC - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,724	$ 1,798
Receivables —
Customer accounts	2,277	1,806
Other accounts and notes	534	523
Materials and supplies	1,641	1,543
Other current assets	212	231
Total current assets	9,781	8,965
Property, Plant, and Equipment:
In service	117,418	115,592
Less: Accumulated depreciation	35,203	34,079
Plant in service, net of depreciation	82,215	81,513
Construction work in progress	9,770	8,771
Total property, plant, and equipment	92,822	91,108
Other Property and Investments:
Equity investments in unconsolidated subsidiaries	1,305	1,282
Total other property and investments	9,736	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,623	1,701
Other deferred charges and assets	2,393	1,776
Total deferred charges and other assets	18,430	17,259
Total Assets	130,769	127,534
Current Liabilities:
Securities due within one year	1,052	2,157
Notes payable	2,510	1,440
Accounts payable —
Accrued interest	553	533
Other current liabilities	1,062	872
Total current liabilities	11,487	10,921
Long-term Debt	51,204	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,620	8,862
Accumulated deferred ITCs	2,175	2,216
Operating lease obligations, deferred	1,464	1,503
Other deferred credits and liabilities	1,198	816
Total deferred credits and other liabilities	34,823	33,926
Total Liabilities	97,514	94,967
Total Stockholders' Equity (See accompanying statements)	33,013	32,276
Total Liabilities and Stockholders' Equity	130,769	127,534
SOUTHERN POWER CO
Current Assets:
Cash and cash equivalents	202	107
Receivables —
Customer accounts	278	139
Affiliated	83	51
Other accounts and notes	19	29
Materials and supplies	108	106
Prepaid income taxes	5	27
Other current assets	48	46
Total current assets	743	505
Property, Plant, and Equipment:
In service	14,637	14,585
Less: Accumulated depreciation	3,462	3,241
Plant in service, net of depreciation	11,175	11,344
Construction work in progress	34	45
Total property, plant, and equipment	11,209	11,389
Other Property and Investments:
Intangible assets, net of amortization	274	282
Equity investments in unconsolidated subsidiaries	49	86
Net investment in sales-type leases	156	161
Total other property and investments	479	529
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	493	479
Prepaid LTSAs	192	210
Other deferred charges and assets	286	278
Total deferred charges and other assets	971	967
Total Assets	13,402	13,390
Current Liabilities:
Securities due within one year	0	679
Notes payable	306	211
Accounts payable —
Affiliated	192	92
Other	77	85
Accrued taxes	56	14
Accrued interest	24	32
Other current liabilities	89	140
Total current liabilities	744	1,253
Long-term Debt	2,964	3,009
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	471	215
Accumulated deferred ITCs	1,585	1,614
Operating lease obligations, deferred	514	497
Other deferred credits and liabilities	245	204
Total deferred credits and other liabilities	2,815	2,530
Total Liabilities	6,523	6,792
Total Stockholders' Equity (See accompanying statements)	6,879	6,598
Total Liabilities and Stockholders' Equity	$ 13,402	$ 13,390

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Condensed Consolidated Balance Sheets (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Other intangible assets, amortization	$ 326	$ 307
SOUTHERN POWER CO
Other intangible assets, amortization	$ 119	$ 109

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - SPC - USD ($) $ in Millions	Total	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests	SOUTHERN POWER CO	SOUTHERN POWER CO Total Common Stockholders' Equity	SOUTHERN POWER CO Paid-In Capital	SOUTHERN POWER CO Retained Earnings (Accumulated Deficit)	SOUTHERN POWER CO Accumulated Other Comprehensive Income (Loss)	SOUTHERN POWER CO Noncontrolling Interests
Beginning balance at Dec. 31, 2020	$ 32,234	$ 11,834	$ 11,311	$ (395)	$ 4,262	$ 6,631	$ 2,369	$ 914	$ 1,522	$ (67)	$ 4,262
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income						65	97		97		(32)
Return of capital to parent company						(271)	(271)	(271)
Other comprehensive income (loss)	28			28		16	16			16
Cash dividends on common stock	(678)		(678)			(51)	(51)		(51)
Capital contributions from noncontrolling interests	403				403	403					403
Distributions to noncontrolling interests	(46)				(46)	(46)					(46)
Other	1	2			(1)	(3)	(2)	(2)	1	(1)	(1)
Ending balance at Mar. 31, 2021	33,068	11,854	11,768	(367)	4,586	6,744	2,158	641	1,569	(52)	4,586
Beginning balance at Dec. 31, 2020	32,234	11,834	11,311	(395)	4,262	6,631	2,369	914	1,522	(67)	4,262
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,482					100
Ending balance at Jun. 30, 2021	32,746	11,886	11,442	(355)	4,547	6,690	2,143	643	1,554	(54)	4,547
Beginning balance at Mar. 31, 2021	33,068	11,854	11,768	(367)	4,586	6,744	2,158	641	1,569	(52)	4,586
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	376					36	36		36		0
Other comprehensive income (loss)	12			12		(3)	(3)			(3)
Cash dividends on common stock	(699)		(699)			(51)	(51)		(51)
Capital contributions from noncontrolling interests	29				29	29					29
Distributions to noncontrolling interests	(68)				(68)	(68)					(68)
Other	0	1	1			3	3	2		1
Ending balance at Jun. 30, 2021	32,746	11,886	11,442	(355)	4,547	6,690	2,143	643	1,554	(54)	4,547
Beginning balance at Dec. 31, 2021	32,276	11,950	10,929	(237)	4,402	6,598	2,196	638	1,585	(27)	4,402
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income						27	72		72		(45)
Other comprehensive income (loss)	42			42		5	5			5
Cash dividends on common stock	(702)		(702)			(49)	(49)		(49)
Capital contributions from noncontrolling interests	73				73	73					73
Distributions to noncontrolling interests	(98)				(98)	(98)					(98)
Other	7	7	2
Ending balance at Mar. 31, 2022	32,629	11,994	11,261	(195)	4,332	6,556	2,224	638	1,608	(22)	4,332
Beginning balance at Dec. 31, 2021	32,276	11,950	10,929	(237)	4,402	6,598	2,196	638	1,585	(27)	4,402
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,079					103
Ending balance at Jun. 30, 2022	33,013	12,033	11,645	(184)	4,282	6,879	2,597	960	1,656	(19)	4,282
Beginning balance at Mar. 31, 2022	32,629	11,994	11,261	(195)	4,332	6,556	2,224	638	1,608	(22)	4,332
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,089					76	98		98		(22)
Capital contributions from parent company						322	322	322
Other comprehensive income (loss)	11			11		3	3			3
Cash dividends on common stock	(723)		(723)			(50)	(50)		(50)
Distributions to noncontrolling interests	(28)				(28)	(28)					(28)
Other	2	4
Ending balance at Jun. 30, 2022	$ 33,013	$ 12,033	$ 11,645	$ (184)	$ 4,282	$ 6,879	$ 2,597	$ 960	$ 1,656	$ (19)	$ 4,282

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Condensed Consolidated Statements of Income (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Operating Revenues:
Total operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Operating Expenses:
Other operations and maintenance	1,558	1,438	3,075	2,810
Depreciation and amortization	913	891	1,805	1,762
Taxes other than income taxes	349	313	721	657
Total operating expenses	5,551	4,490	10,815	8,802
Operating Income	1,655	708	3,039	2,306
Other Income and (Expense):
Earnings (loss) from equity method investments	34	(40)	80	5
Interest expense, net of amounts capitalized	(488)	(450)	(950)	(901)
Other income (expense), net	139	101	283	160
Total other income and (expense)	(262)	(344)	(483)	(646)
Earnings (Loss) Before Income Taxes	1,393	364	2,556	1,660
Income taxes (benefit)	304	(12)	477	178
Consolidated Net Income	1,089	376	2,079	1,482
Retail electric revenues
Operating Revenues:
Total operating revenues	4,789	3,599	8,402	6,941
Wholesale Electric
Operating Revenues:
Total operating revenues	937	546	1,601	1,091
Other electric revenues
Operating Revenues:
Total operating revenues	192	175	370	346
Natural Gas
Operating Revenues:
Total operating revenues	1,083	677	3,140	2,371
Natural gas
Operating Expenses:
Total cost of sales	452	231	1,546	814
Alternative revenue programs
Operating Revenues:
Total operating revenues	2	2	1	4
Other revenues
Operating Revenues:
Total operating revenues	205	201	341	359
Operating Expenses:
Total cost of sales	114	103	183	185
SOUTHERN Co GAS
Operating Revenues:
Total operating revenues	$ 1,083	$ 677	$ 3,140	$ 2,371
Operating Expenses:
Cost, Product and Service [Extensible Enumeration]	Natural gas	Natural gas	Natural gas	Natural gas
Other operations and maintenance	$ 266	$ 233	$ 570	$ 532
Depreciation and amortization	138	133	275	263
Taxes other than income taxes	62	49	163	130
Total operating expenses	918	646	2,554	1,739
Operating Income	165	31	586	632
Other Income and (Expense):
Earnings (loss) from equity method investments	31	(52)	71	(11)
Interest expense, net of amounts capitalized	(61)	(59)	(122)	(118)
Other income (expense), net	16	(14)	32	(78)
Total other income and (expense)	(14)	(125)	(19)	(207)
Earnings (Loss) Before Income Taxes	151	(94)	567	425
Income taxes (benefit)	36	(29)	134	92
Consolidated Net Income	115	(65)	433	333
SOUTHERN Co GAS | Natural gas
Operating Revenues:
Total operating revenues	1,081	675	3,139	2,367
Operating Expenses:
Total cost of sales	452	231	1,546	814
SOUTHERN Co GAS | Alternative revenue programs
Operating Revenues:
Total operating revenues	$ 2	$ 2	$ 1	$ 4

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Condensed Consolidated Statements of Income (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
SOUTHERN Co GAS
Revenue taxes collected	$ 33	$ 23	$ 104	$ 77

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net income	$ 1,089	$ 376	$ 2,079	$ 1,482
Qualifying hedges:
Changes in fair value, net of tax	(45)	14	(26)	(16)
Reclassification adjustment for amounts included in net income, net of tax	54	(5)	74	50
Total other comprehensive income	11	12	53	40
Comprehensive Income	1,100	388	2,132	1,522
SOUTHERN Co GAS
Net income	115	(65)	433	333
Qualifying hedges:
Changes in fair value, net of tax	(5)	8	22	9
Reclassification adjustment for amounts included in net income, net of tax	(7)	0	(13)	3
Total other comprehensive income	(12)	8	9	12
Comprehensive Income	$ 103	$ (57)	$ 442	$ 345

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Changes in fair value, tax	$ (15)	$ 5	$ (7)	$ (5)
Qualifying hedges, reclassification adjustment, tax	17	(1)	24	17
SOUTHERN Co GAS
Changes in fair value, tax	(2)	3	8	3
Qualifying hedges, reclassification adjustment, tax	$ (3)	$ 0	$ (5)	$ 1

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Condensed Consolidated Statements of Cash Flows (Unaudited) - GAS - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Operating Activities:
Net income (loss)	$ 2,079	$ 1,482
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,995	1,949
Deferred income taxes	240	(101)
Mark-to-market adjustments	14	136
Natural gas cost under recovery – long-term	192	(119)
Other, net	21	117
Changes in certain current assets and liabilities —
Receivables	(637)	29
Natural gas for sale, net of temporary LIFO liquidation	335	375
Natural gas cost under recovery	(94)	(485)
Other current assets	12	94
Accounts payable	703	(177)
Accrued taxes	(150)	(157)
Other current liabilities	30	(235)
Net cash provided from operating activities	3,579	2,904
Investing Activities:
Property additions	(3,213)	(3,384)
Cost of removal, net of salvage	(377)	(184)
Other investing activities	96	(20)
Net cash used for investing activities	(3,460)	(4,026)
Financing Activities:
Increase (decrease) in notes payable, net	263	492
Proceeds —
Proceeds - Short-term borrowings	1,200	325
Redemptions and repurchases —
Short-term borrowings	(400)	(25)
Payment of common stock dividends	(1,425)	(1,377)
Net cash provided from (used for) financing activities	(213)	1,671
Net Change in Cash, Cash Equivalents, and Restricted Cash	(94)	549
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,735	1,617
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	836	884
Income taxes, net	157	88
Noncash transactions —
Accrued property additions at year-end	837	943
SOUTHERN Co GAS
Operating Activities:
Net income (loss)	433	333
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	275	263
Deferred income taxes	35	110
Mark-to-market adjustments	13	137
Impairment of PennEast Pipeline investment	0	82
Natural gas cost under recovery – long-term	192	(119)
Other, net	42	15
Changes in certain current assets and liabilities —
Receivables	244	262
Natural gas for sale, net of temporary LIFO liquidation	335	375
Prepaid income taxes	(70)	(129)
Natural gas cost under recovery	(94)	(485)
Other current assets	19	7
Accounts payable	101	(42)
Accrued taxes	(41)	1
Other current liabilities	(6)	(88)
Net cash provided from operating activities	1,478	722
Investing Activities:
Property additions	(637)	(635)
Cost of removal, net of salvage	(53)	(44)
Other investing activities	32	11
Net cash used for investing activities	(658)	(668)
Financing Activities:
Increase (decrease) in notes payable, net	(593)
Increase (decrease) in notes payable, net		210
Proceeds —
Proceeds - Short-term borrowings	50	300
Redemptions and repurchases —
Short-term borrowings	(150)	0
Senior notes	0	300
Medium-term notes	(46)	(30)
Capital contributions from parent company	349	60
Payment of common stock dividends	(260)	(265)
Net cash provided from (used for) financing activities	(650)	(25)
Net Change in Cash, Cash Equivalents, and Restricted Cash	170	29
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	48	19
Cash, Cash Equivalents, and Restricted Cash at End of Period	218	48
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	129	127
Income taxes, net	210	100
Noncash transactions —
Accrued property additions at year-end	$ 126	$ 137

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Condensed Consolidated Statements of Cash Flows (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Net cash paid for capitalized interest	$ 46	$ 43
SOUTHERN Co GAS
Net cash paid for capitalized interest	$ 4	$ 3

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Condensed Consolidated Balance Sheets (Unaudited) - GAS - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,724	$ 1,798
Receivables —
Customer accounts	2,277	1,806
Unbilled revenues	807	711
Other accounts and notes	534	523
Accumulated provision for uncollectible accounts	(94)	(78)
Natural gas for sale	209	362
Prepaid expenses	528	330
Assets from risk management activities, net of collateral	247	151
Natural gas cost under recovery	361	266
Other regulatory assets	641	653
Other current assets	212	231
Total current assets	9,781	8,965
Property, Plant, and Equipment:
In service	117,418	115,592
Less: Accumulated depreciation	35,203	34,079
Plant in service, net of depreciation	82,215	81,513
Construction work in progress	9,770	8,771
Total property, plant, and equipment	92,822	91,108
Other Property and Investments:
Goodwill	5,280	5,280
Equity investments in unconsolidated subsidiaries	1,305	1,282
Other intangible assets, net of amortization	425	445
Miscellaneous property and investments	576	653
Total other property and investments	9,736	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,623	1,701
Prepaid pension costs	1,893	1,657
Other regulatory assets, deferred	5,448	5,577
Other deferred charges and assets	2,393	1,776
Total deferred charges and other assets	18,430	17,259
Total Assets	130,769	127,534
Current Liabilities:
Securities due within one year	1,052	2,157
Notes payable	2,510	1,440
Accounts payable —
Customer deposits	461	479
Accrued interest	553	533
Accrued compensation	807	1,070
Other regulatory liabilities	557	563
Other current liabilities	1,062	872
Total current liabilities	11,487	10,921
Long-term Debt	51,204	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,620	8,862
Deferred credits related to income taxes	5,318	5,401
Employee benefit obligations	1,509	1,550
Operating lease obligations, deferred	1,464	1,503
Other cost of removal obligations	1,993	2,103
Other deferred credits and liabilities	1,198	816
Total deferred credits and other liabilities	34,823	33,926
Total Liabilities	97,514	94,967
Common Stockholder's Equity (See accompanying statements)	33,013	32,276
Total Liabilities and Stockholders' Equity	130,769	127,534
SOUTHERN Co GAS
Current Assets:
Cash and cash equivalents	217	45
Receivables —
Customer accounts	379	462
Unbilled revenues	109	278
Other accounts and notes	53	49
Accumulated provision for uncollectible accounts	(55)	(39)
Natural gas for sale	209	362
Prepaid expenses	185	114
Assets from risk management activities, net of collateral	22	33
Natural gas cost under recovery	361	266
Other regulatory assets	105	136
Other current assets	53	49
Total current assets	1,638	1,755
Property, Plant, and Equipment:
In service	19,362	18,880
Less: Accumulated depreciation	5,201	5,067
Plant in service, net of depreciation	14,161	13,813
Construction work in progress	776	684
Total property, plant, and equipment	14,937	14,497
Other Property and Investments:
Goodwill	5,015	5,015
Equity investments in unconsolidated subsidiaries	1,134	1,173
Other intangible assets, net of amortization	31	37
Miscellaneous property and investments	19	19
Total other property and investments	6,199	6,244
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	63	70
Prepaid pension costs	192	175
Other regulatory assets, deferred	459	689
Other deferred charges and assets	130	130
Total deferred charges and other assets	844	1,064
Total Assets	23,618	23,560
Current Liabilities:
Securities due within one year	0	47
Notes payable	516	1,209
Accounts payable —
Affiliated	54	58
Other	494	361
Customer deposits	81	95
Accrued taxes	74	124
Accrued interest	58	59
Accrued compensation	91	110
Temporary LIFO liquidation	177	0
Other regulatory liabilities	37	8
Other current liabilities	161	155
Total current liabilities	1,743	2,226
Long-term Debt	6,785	6,855
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,595	1,555
Deferred credits related to income taxes	800	816
Employee benefit obligations	168	176
Operating lease obligations, deferred	55	59
Other cost of removal obligations	1,694	1,683
Accrued environmental remediation	181	197
Other deferred credits and liabilities	137	77
Total deferred credits and other liabilities	4,630	4,563
Total Liabilities	13,158	13,644
Common Stockholder's Equity (See accompanying statements)	10,460	9,916
Total Liabilities and Stockholders' Equity	$ 23,618	$ 23,560

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Condensed Consolidated Balance Sheets (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Other intangible assets, amortization	$ 326	$ 307
SOUTHERN Co GAS
Other intangible assets, amortization	$ 151	$ 145

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - GAS - USD ($) $ in Millions	Total	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	SOUTHERN Co GAS	SOUTHERN Co GAS Paid-In Capital	SOUTHERN Co GAS Retained Earnings (Accumulated Deficit)	SOUTHERN Co GAS Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2020	$ 32,234	$ 11,834	$ 11,311	$ (395)	$ 9,767	$ 9,930	$ (141)	$ (22)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income					398		398
Capital contributions from parent company					57	57
Other comprehensive income (loss)	28			28	4			4
Cash dividends on common stock	(678)		(678)		(132)		(132)
Ending balance at Mar. 31, 2021	33,068	11,854	11,768	(367)	10,094	9,987	125	(18)
Beginning balance at Dec. 31, 2020	32,234	11,834	11,311	(395)	9,767	9,930	(141)	(22)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,482				333
Ending balance at Jun. 30, 2021	32,746	11,886	11,442	(355)	9,929	10,012	(73)	(10)
Beginning balance at Mar. 31, 2021	33,068	11,854	11,768	(367)	10,094	9,987	125	(18)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	376				(65)		(65)
Capital contributions from parent company					25	25
Other comprehensive income (loss)	12			12	8			8
Cash dividends on common stock	(699)		(699)		(133)		(133)
Ending balance at Jun. 30, 2021	32,746	11,886	11,442	(355)	9,929	10,012	(73)	(10)
Beginning balance at Dec. 31, 2021	32,276	11,950	10,929	(237)	9,916	10,024	(132)	24
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income					319		319
Capital contributions from parent company					50	50
Other comprehensive income (loss)	42			42	20			20
Cash dividends on common stock	(702)		(702)		(130)		(130)
Ending balance at Mar. 31, 2022	32,629	11,994	11,261	(195)	10,175	10,074	57	44
Beginning balance at Dec. 31, 2021	32,276	11,950	10,929	(237)	9,916	10,024	(132)	24
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	2,079				433
Ending balance at Jun. 30, 2022	33,013	12,033	11,645	(184)	10,460	10,386	42	32
Beginning balance at Mar. 31, 2022	32,629	11,994	11,261	(195)	10,175	10,074	57	44
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,089				115		115
Capital contributions from parent company					312	312
Other comprehensive income (loss)	11			11	(12)			(12)
Cash dividends on common stock	(723)		(723)		(130)		(130)
Ending balance at Jun. 30, 2022	$ 33,013	$ 12,033	$ 11,645	$ (184)	$ 10,460	$ 10,386	$ 42	$ 32

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Introduction

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Introduction

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, 2021 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, 2022 and 2021. Certain information and footnote 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.

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 June 30, 2022 and December 31, 2021 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,280
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 impairment indicators arise.

Other intangible assets were as follows:

	At June 30, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(157)	$	55	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(119)		271		390		(109)		281
Other	10		(9)		1		11		(10)		1
Total other intangible assets subject to amortization	$	676	$	(326)	$	350	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	751	$	(326)	$	425	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(119)	$	271	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(135)	$	21	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(151)	$	31	$	182	$	(145)	$	37

Amortization associated with other intangible assets was as follows:

	Three Months Ended		Six Months Ended
	June 30, 2022
	(in millions)
Southern Company(a)	$	9	$	19
Southern Power(b)	5		10
Southern Company Gas	2		5

(a)Includes $5 million and $10 million for the three and six months ended June 30, 2022, respectively, recorded as a reduction to operating revenues.

(b)Recorded as a reduction to operating revenues.

Cash, Cash Equivalents, and Restricted Cash

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,724	$	1,798	$	202	$	107	$	217	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,735	$	1,829	$	211	$	135	$	218	$	48

(a)For Southern Power, reflects $9 million and $10 million at June 30, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

Natural Gas for Sale

With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG considered to be other than 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, 2022 is expected to be restored prior to year end.

Depreciation and Amortization

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

Effective January 1, 2022, Southern Power revised the depreciable lives of its wind generating facilities from up to 30 years to up to 35 years. This revision resulted in an immaterial decrease in depreciation for the three and six months ended June 30, 2022 and is expected to result in an immaterial decrease in annual depreciation for 2022.

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Regulatory Matters

6 Months Ended

Jun. 30, 2022

Regulated Operations [Abstract]

Regulatory Matters

REGULATORY MATTERS

See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information relating to regulatory matters.

The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at June 30, 2022 and December 31, 2021 were as follows:

Regulatory Clause	Balance Sheet Line Item	June 30, 2022		December 31, 2021
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, deferred	$	29	$	16
Rate CNP PPA	Other regulatory assets, deferred	93		84
Retail Energy Cost Recovery(*)	Other regulatory assets, current	60		—
	Other regulatory assets, deferred	191		126
Georgia Power
Fuel Cost Recovery	Deferred under recovered fuel clause revenues	$	948	$	410
Mississippi Power
Fuel Cost Recovery	Other customer accounts receivable	$	29	$	4
Ad Valorem Tax	Other regulatory assets, current	12		12
	Other regulatory assets, deferred	29		37
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	361	$	266
	Other regulatory assets, deferred	15		207

(*)In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.

Alabama Power

Certificate of Convenience and Necessity

On July 12, 2022, the Alabama PSC approved and, on July 15, 2022, issued its order regarding Alabama Power's petition for a certificate of convenience and necessity (CCN) which authorizes Alabama Power to complete the acquisition of the Calhoun Generating Station, which was approved by the FERC on March 25, 2022, and is expected to close by September 30, 2022. Alabama Power expects to recover all approved costs associated with the acquisition through existing rate mechanisms as outlined in Note 2 to the financial statements in Item 8 of the Form 10-K. The Alabama PSC's order is subject to any rehearing request or judicial appeal filed on or before August 15, 2022. The ultimate outcome of this matter cannot be determined at this time.

Rate ECR

On July 12, 2022, the Alabama PSC approved an adjustment to Rate ECR from 1.960 cents per KWH to 2.557 cents per KWH, or approximately $310 million annually, effective with August 2022 billings. The approved increase in the Rate ECR factor will have no significant effect on Alabama Power's net income, but will increase operating cash flows related to fuel cost recovery. The rate will adjust to 5.910 cents per KWH in January 2025 absent a further order from the Alabama PSC.

Rate NDR

On July 12, 2022, the Alabama PSC approved modifications to Rate NDR, which include an adjustment to the charges to establish and maintain the reserve and an adjustment to the recovery period for any existing deferred storm-related operations and maintenance costs and future reserve deficits from 24 months to 48 months. As modified, the maximum total Rate NDR charge to recover a deficit is limited to $5.00 per month per non-residential customer account and $2.50 per month per residential customer account.

At June 30, 2022, Alabama Power's NDR balance was $103 million. Beginning with August 2022 billings, the reserve establishment charge will be suspended and the reserve maintenance charge will be activated as a result of the NDR balance exceeding $75 million. Alabama Power expects to collect $6 million in the second half of 2022 and approximately $12 million annually beginning in 2023 under Rate NDR unless the NDR balance falls below $50 million. Alabama Power continues to have the authority to accrue additional amounts to the NDR as circumstances warrant.

Reliability Reserve Accounting Order

On July 12, 2022, the Alabama PSC approved an accounting order authorizing Alabama Power to create a reliability reserve separate from the NDR and transition the previous Rate NDR authority related to reliability expenditures to the reliability reserve. Alabama Power may make accruals to the reliability reserve if the NDR balance exceeds $35 million.

Renewable Generation Certificate

Through the issuance of a Renewable Generation Certificate (RGC), Alabama Power is authorized by the Alabama PSC to procure up to 500 MWs of renewable capacity and energy by September 16, 2027 and to market the related energy and environmental attributes to customers and other third parties. In April 2022, one of the existing solar projects which was expected to be served through a PPA commencing in first quarter 2024 was terminated, resulting in the restoration of 80 MWs of capacity under the RGC. The ultimate outcome of this matter cannot be determined at this time.

Georgia Power

Rate Plans

2022 Base Rate Case

On June 24, 2022, Georgia Power filed a base rate case (Georgia Power 2022 Base Rate Case) with the Georgia PSC. The filing proposes continuation of a three-year alternate rate plan with requested rate increases totaling $852 million, $107 million, and $45 million effective January 1, 2023, January 1, 2024, and January 1, 2025, respectively. These increases are based on a proposed retail ROE of 11.00% using the currently approved equity ratio of 56% and reflect levelized revenue requirements during the three-year period, with the exception of incremental compliance costs related to CCR AROs, Demand-Side Management (DSM) programs, and related adjustments to the Municipal Franchise Fee tariff.

Georgia Power has requested recovery of the proposed increases through its existing base rate tariffs as follows:

Tariff	2023		2024		2025
	(in millions)
Traditional base	$	739	$	—	$	—
ECCR
Traditional	(1)		—		—
CCR ARO(a)	64		78		47
DSM(a)	30		27		(2)
Municipal Franchise Fee	20		2		1
Total(b)	$	852	$	107	$	45

(a)As determined by the Georgia PSC through annual compliance filings.

(b)Totals may not add due to rounding.

Georgia Power's filing primarily reflects requests to (i) recover the costs of recent and future capital investments in the electric grid including the transmission and distribution systems and the continuation of its grid investment plan, all designed to support customer long-term reliability and resiliency needs, (ii) recover the cost of coal-fired generation units proposed for retirement, or made unavailable, as requested in the 2022 IRP, as Georgia Power continues the transition of the generation fleet to more economical and cleaner resources, (iii) make the necessary investments and recover costs to comply with federal and state environmental regulations, including costs associated with the CCR AROs related to ash pond and landfill closures and post-closure care, and (iv) reduce operating costs despite significant inflationary pressures. In addition, the filing includes the following provisions:

•Continuation of an allowed retail ROE range of 9.50% to 12.00%.

•Continuation of the process whereby 80% of any earnings above the top of the allowed ROE range are shared with Georgia Power's customers and the remaining 20% are retained by Georgia Power.

•Continuation of the option to file an Interim Cost Recovery tariff in the event earnings are projected to fall below the bottom of the allowed ROE range during the three-year term of the plan.

Georgia Power expects the Georgia PSC to render a final decision in this matter on December 20, 2022. The ultimate outcome of this matter cannot be determined at this time.

2019 ARP

In 2020, the Georgia PSC denied a motion for reconsideration filed by Sierra Club regarding the Georgia PSC's decision in the 2019 ARP allowing Georgia Power to recover compliance costs for CCR AROs. The Superior Court of Fulton County subsequently affirmed the Georgia PSC's decision and, in October 2021, the Georgia Court of Appeals affirmed the Superior Court of Fulton County's order. In December 2021, Sierra Club filed a petition for writ of certiorari to the Georgia Supreme Court, which was denied on July 14, 2022. This matter is now concluded. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information regarding Georgia Power's AROs.

Integrated Resource Plans

In response to supply chain challenges in the solar industry, the Georgia PSC approved Georgia Power's request to amend 970 MWs of utility-scale solar PPAs that were authorized by the Georgia PSC in Georgia Power's 2019 IRP. The amendments extended the required commercial operation dates for the PPAs from 2023 to 2024.

On July 21, 2022, the Georgia PSC approved the 2022 IRP, as modified by a stipulated agreement among Georgia Power, the staff of the Georgia PSC, and certain intervenors and as further modified by the Georgia PSC. In the 2022 IRP decision, the Georgia PSC approved the following requests:

•Decertification and retirement of Plant Wansley Units 1 and 2 (926 MWs based on 53.5% ownership) by August 31, 2022 and reclassification to regulatory asset accounts of the remaining net book values ($302 million and $279 million for Unit 1 and Unit 2, respectively, at June 30, 2022) and any remaining unusable materials and supplies inventories upon retirement. The regulatory asset accounts for the net book values of the units will be amortized at a rate equal to the unit depreciation rates authorized in the 2019 ARP through December 31, 2022. In the Georgia Power 2022 Base Rate Case, Georgia Power requested recovery of the remaining regulatory asset balances for the net book values of the units through 2030 and requested that the timing of recovery of the regulatory asset account for the unusable materials and supplies inventories be determined in a future base rate case.

•Decertification and retirement of Plant Scherer Unit 3 (614 MWs based on 75% ownership) by December 31, 2028 and reclassification to regulatory asset accounts of the remaining net book value (approximately $614 million at June 30, 2022) and any remaining unusable materials and supplies inventory to regulatory asset accounts upon retirement. The timing of recovery for these regulatory assets is expected to be determined in a future base rate case.

•Decertification and retirement of Plant Gaston Units 1 through 4 (500 MWs based on 50% ownership through SEGCO) by December 31, 2028. See Note 7 to the financial statements under "SEGCO" in Item 8 of the Form 10-K for additional information.

•Georgia Power's environmental compliance strategy, including approval of Georgia Power's plans to address CCR at its ash ponds and landfills. Recovery of the related costs is expected to be determined in future base rate cases. The Georgia PSC's approval included a change in the method of closure for one ash pond. Georgia Power is currently evaluating the related impact on its cost estimates and AROs; however, it is not expected to be material.

•Installation of environmental controls at Plants Bowen and Scherer for compliance with rules related to effluent limitations guidelines.

•Initiation of a license renewal application with the NRC for Plant Hatch.

•Investments related to the continued hydro operations of Plants Sinclair and Burton.

•Provisional authorization for development of a 265-MW battery energy storage facility with expected commercial operation in 2026.

•Issuance of requests for proposals (RFP) for 2,300 MWs of renewable resources, an additional 500 MWs of energy storage, and up to 140 MWs of biomass generation.

•Related transmission projects necessary to support the generation facilities plan.

•Certification of six PPAs (including five affiliate PPAs with Southern Power that are subject to approval by the FERC) with capacities of 1,567 MWs beginning in 2024, 380 MWs beginning in 2025, and 228 MWs beginning in 2028, procured through RFPs authorized in the 2019 IRP. See Note (F) under "Georgia Power Lease Modification" for additional information.

The Georgia PSC deferred a decision on the requested decertification and retirement of Plant Bowen Units 1 and 2 (1,400 MWs) to the 2025 IRP and rejected Georgia Power's request to certify approximately 88 MWs of wholesale capacity to be placed in retail rate base between January 1, 2024 and January 1, 2025. Georgia Power may offer such capacity in the wholesale market or to the retail jurisdiction in a future regulatory proceeding.

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

Nuclear Construction

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a 45.7% ownership interest. In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction of the two AP1000 nuclear units (with electric generating capacity of approximately 1,100 MWs each) and related facilities to begin. Until March 2017, construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement.

In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units. The Vogtle Services Agreement is terminable by the Vogtle Owners upon 30 days' written notice.

In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, under which Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, subject to adjustment based on Bechtel's performance against cost and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its proportionate share, based on its ownership interest, of all amounts owed to Bechtel under the Bechtel Agreement. The Vogtle Owners may terminate the Bechtel Agreement at any time for their convenience, provided that the Vogtle Owners will be required to pay amounts related to work performed prior to the termination (including the applicable portion of the base fee), certain termination-related costs, and, at certain stages of the work, the applicable portion of the at-risk fee. Bechtel may terminate the Bechtel Agreement under certain circumstances, including certain Vogtle Owner suspensions of work, certain breaches of the Bechtel Agreement by the Vogtle Owners, Vogtle Owner insolvency, and certain other events.

See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for information on the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, and mandatory prepayment events.

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,393
Construction contingency estimate	60
Total project capital cost forecast(a)(b)	10,453
Net investment at June 30, 2022(b)	(8,966)
Remaining estimate to complete	$	1,487

(a)Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $455 million of incremental costs under the cost-sharing and tender provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through AFUDC of approximately $385 million, of which $247 million had been accrued through June 30, 2022.

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

Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.4 billion, of which $3.0 billion had been incurred through June 30, 2022.

As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts on a regular basis to incorporate current information available, particularly in the areas of engineering support, commodity installation, system turnovers and related test results, and workforce statistics. Southern Nuclear establishes aggressive target values for monthly construction production and system turnover activities, which are reflected in the site work plans.

Since March 2020, the number of active COVID-19 cases at the site has fluctuated consistent with the surrounding area and impacted productivity levels and pace of activity completion, with the site experiencing peaks in the number of active cases in January 2021, August 2021, and January 2022. Georgia Power estimates the productivity impacts of the COVID-19 pandemic have consumed approximately three to four months of schedule margin previously embedded in the site work plan for Unit 3 and Unit 4. As of June 30, 2022, Georgia Power's proportionate share of the estimated incremental cost associated with COVID-19 mitigation actions and impacts on construction productivity is estimated to be between $160 million and $200 million and is included in the total project capital cost forecast. The continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing activities at Plant Vogtle Units 3 and 4.

Fuel load for Unit 3 is projected during the fourth quarter 2022 with an in-service date projected during the first quarter 2023. Unit 3's projected schedule primarily depends on the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on Unit 3 progress through fuel load, startup, and testing; overall construction productivity and production levels improving, particularly in electrical installation, including terminations; and appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates and cost increases.

During the first half of 2022, established construction contingency totaling $126 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, additional craft and support resources, and procurement for Units 3 and 4. Georgia Power also increased its total project capital cost forecast as of June 30, 2022 by adding $36 million to replenish construction contingency. After considering the significant level of uncertainty that exists regarding the future recoverability of these costs since the ultimate outcome of these matters is subject to the outcome of future assessments by management, as well as Georgia PSC decisions in future regulatory proceedings, Georgia Power recorded a pre-tax charge to income in the second quarter 2022 of $36 million ($27 million after tax) for the increase in the total project capital cost forecast. Georgia Power may request the Georgia PSC to evaluate those expenditures for rate recovery during the prudence review following the Unit 4 fuel load pursuant to the twenty-fourth VCM stipulation described below.

As Unit 3 completes system turnover from construction and moves to testing and transition to operations, ongoing and potential future challenges include construction productivity, completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, and final component and pre-operational tests. As Unit 4 progresses through construction and continues to transition into testing, ongoing and potential future challenges include the pace and quality of electrical installation; availability of craft and supervisory resources, including the temporary diversion of such resources to support Unit 3 construction efforts; the pace of work package closures and system turnovers; and the timeframe and duration of hot functional and other testing. As construction, including subcontract work, continues on both Units 3 and 4, ongoing or future challenges include management of contractors and vendors; subcontractor performance; supervision of craft labor and related productivity, particularly in the installation of electrical, mechanical, and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and procurement and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up, which may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale). The ongoing and potential future challenges described above may change the projected schedule and estimated cost.

There have been technical and procedural challenges to the construction and licensing of Plant Vogtle Units 3 and 4 at the federal and state level and additional challenges may arise. Additional license amendment requests also may be filed with the NRC. Processes are in place that are designed to ensure compliance with the requirements specified in the Westinghouse Design Control Document and the combined construction and operating licenses, including inspections by Southern Nuclear and the NRC that occur throughout construction. In connection with the additional construction remediation work described above, Southern Nuclear reviewed the project's construction quality programs and, where needed, is implementing improvement plans consistent with these processes. On March 25, 2022, the NRC completed its follow-up inspection related to the November 2021 final significance report on its special inspection to review the root cause of this additional construction remediation work and the corresponding corrective action plans. The NRC closed the two white findings identified in November 2021 and returned Vogtle Unit 3 to the NRC's baseline inspection program.

Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel, have arisen or may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues, including inspections and ITAACs, are not resolved in a timely manner, there may be delays in the project schedule that could result in increased costs.

The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described below, is estimated to result in additional base capital costs for Georgia Power of up to $35 million per month for Unit 3 and $45 million per month for Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. While Georgia Power is not precluded from seeking retail recovery of any future capital cost forecast increase other than the amounts related to the cost-sharing and tender provisions of the joint ownership agreements described below, management will ultimately determine whether or not to seek recovery. Any further changes to the capital cost forecast that are not expected to be recoverable through regulated rates will be required to be charged to income and such charges could be material.

Joint Owner Contracts

In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 to continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements). The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners' sole recourse against Georgia Power or Southern Nuclear for any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power and/or Southern Nuclear as agent, except in cases of willful misconduct.

Amendments to the Vogtle Joint Ownership Agreements

In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power's wholly-owned subsidiaries MEAG Power SPVJ, LLC (MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet) with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power's wholly-owned subsidiaries

MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership Agreements to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments).

Pursuant to the Global Amendments: (i) each Vogtle Owner must pay its proportionate share of qualifying construction costs for Plant Vogtle Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4 which formed the basis of Georgia Power's forecast of $8.4 billion in the nineteenth VCM plus $800 million; (ii) Georgia Power will be responsible for 55.7% of actual qualifying construction costs between $800 million and $1.6 billion over the EAC in the nineteenth VCM (resulting in $80 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata in accordance with their respective ownership interests; and (iii) Georgia Power will be responsible for 65.7% of qualifying construction costs between $1.6 billion and $2.1 billion over the EAC in the nineteenth VCM (resulting in a further $100 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective ownership interests. If the EAC is revised and exceeds the EAC in the nineteenth VCM by more than $2.1 billion, each of the other Vogtle Owners will have a one-time option at the time the project budget cost forecast is so revised to tender a portion of its ownership interest to Georgia Power in exchange for Georgia Power's agreement to pay 100% of such Vogtle Owner's remaining share of total construction costs in excess of the EAC in the nineteenth VCM plus $2.1 billion.

For purposes of the foregoing provisions, qualifying construction costs will not include costs (i) resulting from force majeure events, including epidemics and quarantines, governmental actions or inactions (or significant delays associated with issuance of such actions) that affect the licensing, completion, start-up, operations, or financing of Plant Vogtle Units 3 and 4, administrative proceedings or litigation regarding ITAAC or other regulatory challenges to commencement of operation of Plant Vogtle Units 3 and 4, and changes in laws or regulations governing Plant Vogtle Units 3 and 4, (ii) legal fees and legal expenses incurred due to litigation with contractors or subcontractors that are not subsidiaries or affiliates of Southern Company, and (iii) additional costs caused by requests from the Vogtle Owners other than Georgia Power, except for the exercise of a right to vote granted under the Vogtle Joint Ownership Agreements, that increase costs by $100,000 or more.

In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 must vote to continue construction if certain adverse events occur, including, among other events: (i) the bankruptcy of Toshiba; (ii) the termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel Agreement, or the agency agreement with Southern Nuclear; (iii) Georgia Power's public announcement of its intention not to submit for rate recovery any portion of its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power's costs relating to the construction of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts paid by Georgia Power on behalf of the other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of costs during any six-month VCM reporting period that are disallowed by the Georgia PSC for recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates; and (iv) an incremental extension of one year or more from the seventeenth VCM report estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in February 2022 triggered the requirement for a vote to continue construction. Effective February 25, 2022, all of the Vogtle Owners had voted to continue construction.

Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments or the extent to which COVID-19-related costs impact those provisions. Based on the definition in the Global Amendments, Georgia Power believes the starting dollar amount is $18.38 billion and the current project capital cost forecast exceeds the cost-sharing provision threshold, but not the tender provision threshold. The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. Georgia Power recorded pre-tax charges to income in the fourth quarter 2021 and the second quarter 2022 of approximately $440 million ($328 million after tax) and $16 million ($12 million after tax), respectively, associated with these cost-sharing and tender provisions, which are

included in the total project capital cost forecast. Georgia Power may be required to record further pre-tax charges to income of up to approximately $480 million associated with these provisions based on the current project capital cost forecast. Georgia Power's incremental charges associated with these provisions, which relate to the other Vogtle Owners' share of costs, will not be recovered from retail customers. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement, which was modified on June 3, 2022, to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 194 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022, and would require the other Vogtle Owners to notify Georgia Power of their intent to exercise their tender options by August 27, 2022. On June 17, 2022 and July 26, 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. On June 18, 2022, OPC and MEAG Power each filed a separate lawsuit against Georgia Power in the Superior Court of Fulton County, Georgia seeking a declaratory judgment that the starting dollar amount is $17.1 billion and that the cost-sharing and tender provisions have been triggered. The lawsuits also assert other claims, including breach of contract allegations, and seek, among other remedies, damages and injunctive relief requiring Georgia Power to track and allocate construction costs consistent with MEAG Power's and OPC's interpretations of the Global Amendments. On July 25, 2022, Georgia Power filed its answer in the lawsuit filed by MEAG Power and included counterclaims seeking a declaratory judgment that the starting dollar amount is $18.38 billion and that costs related to force majeure events are excluded prior to calculating the cost-sharing and tender provisions and when calculating Georgia Power's related financial obligations.

Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%; however, it could increase if one or more of the other Vogtle Owners effectively exercise the option to tender a portion of their ownership interest to Georgia Power and require Georgia Power to pay 100% of the remaining share of the costs necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest would be calculated and conveyed to Georgia Power after Plant Vogtle Units 3 and 4 are placed in service.

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

Regulatory Matters

In 2009, the Georgia PSC voted to certify construction of Plant Vogtle Units 3 and 4 with a certified capital cost of $4.418 billion. In addition, in 2009 the Georgia PSC approved inclusion of the Plant Vogtle Units 3 and 4 related CWIP accounts in rate base, and the State of Georgia enacted the Georgia Nuclear Energy Financing Act, which allows Georgia Power to recover financing costs for Plant Vogtle Units 3 and 4. Financing costs are recovered on all applicable certified costs through annual adjustments to the NCCR tariff up to the certified capital cost of $4.418 billion. At June 30, 2022, Georgia Power had recovered approximately $2.8 billion of financing costs. Financing costs related to capital costs above $4.418 billion are being recognized through AFUDC and are expected to be recovered through retail rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to any capital costs in excess of the total deemed reasonable by the Georgia PSC (currently $7.3 billion) and not requested for rate recovery. In November 2021, the Georgia PSC approved Georgia Power's request to decrease the NCCR tariff by $78 million annually, effective January 1, 2022.

Georgia Power is required to file semi-annual VCM reports with the Georgia PSC by February 28 and August 31 of each year. In 2013, in connection with the eighth VCM report, the Georgia PSC approved a stipulation between Georgia Power and the staff of the Georgia PSC to waive the requirement to amend the Plant Vogtle Units 3 and 4 certificate in accordance with the 2009 certification order until the completion of Plant Vogtle Unit 3, or earlier if deemed appropriate by the Georgia PSC and Georgia Power.

In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in connection with the fifteenth VCM report. In December 2017, the Georgia PSC voted to approve (and issued its related order on January 11, 2018) Georgia Power's seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 11, 2018 order, resolved the following regulatory matters related to Plant Vogtle Units 3 and 4: (i) none of the $3.3 billion of costs incurred through December 31, 2015 and reflected in the fourteenth VCM report should be disallowed from rate base on the basis of imprudence; (ii) the Contractor Settlement Agreement was reasonable and

prudent and none of the $0.3 billion paid pursuant to the Contractor Settlement Agreement should be disallowed from rate base on the basis of imprudence; (iii) (a) capital costs incurred up to $5.68 billion would be presumed to be reasonable and prudent with the burden of proof on any party challenging such costs, (b) Georgia Power would have the burden to show that any capital costs above $5.68 billion were prudent, and (c) a revised capital cost forecast of $7.3 billion (after reflecting the impact of payments received under the Guarantee Settlement Agreement and related customer refunds) was found reasonable; (iv) construction of Plant Vogtle Units 3 and 4 should be completed, with Southern Nuclear serving as project manager and Bechtel as primary contractor; (v) approved and deemed reasonable Georgia Power's revised schedule placing Plant Vogtle Units 3 and 4 in service in November 2021 and November 2022, respectively; (vi) confirmed that the revised cost forecast does not represent a cost cap and that a prudence proceeding on cost recovery will occur following Unit 4 fuel load, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 alternate rate plan) to 10.00% effective January 1, 2016, (b) from 10.00% to 8.30%, effective January 1, 2020, and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case will be less than Georgia Power's average cost of long-term debt); (viii) reduced the ROE used for AFUDC equity for Plant Vogtle Units 3 and 4 from 10.00% to Georgia Power's average cost of long-term debt, effective January 1, 2018; and (ix) agreed that effective the first month after Unit 3 reaches commercial operation, retail base rates would be adjusted to include the costs related to Unit 3 and common facilities deemed prudent in the Vogtle Cost Settlement Agreement (see Note 2 to the financial statements under "Georgia Power – Plant Vogtle Unit 3 and Common Facilities Rate Proceeding" in Item 8 of the Form 10-K for additional information). The January 11, 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by 10 basis points each month (but not lower than Georgia Power's average cost of long-term debt) until the respective Unit is commercially operational. The ROE reductions negatively impacted earnings by approximately $270 million in 2021 and are estimated to have negative earnings impacts of approximately $300 million and $250 million in 2022 and 2023, respectively. In its January 11, 2018 order, the Georgia PSC also stated if other conditions change and assumptions upon which Georgia Power's seventeenth VCM report are based do not materialize, the Georgia PSC reserved the right to reconsider the decision to continue construction.

In the August 2021 order approving the twenty-fourth VCM report, the Georgia PSC approved a stipulation addressing the following matters: (i) beginning with its twenty-fifth VCM report, Georgia Power will continue to report to the Georgia PSC all costs incurred during the period for review and will request for approval costs up to the $7.3 billion determined to be reasonable in the Georgia PSC's seventeenth VCM order and (ii) Georgia Power will not seek rate recovery of the $0.7 billion increase to the base capital cost forecast included in the nineteenth VCM report and charged to income by Georgia Power in the second quarter 2018. In addition, the stipulation confirms Georgia Power may request verification and approval of costs above $7.3 billion for inclusion in rate base at a later time, but no earlier than the prudence review contemplated by the seventeenth VCM order described previously.

The Georgia PSC has approved 25 VCM reports covering periods through June 30, 2021. These reports reflect total construction capital costs incurred of $7.9 billion (net of $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds), of which the Georgia PSC has verified and approved $7.3 billion as described above. The Georgia PSC has reviewed the twenty-sixth VCM report, which reflects $584 million of additional construction capital costs incurred through December 31, 2021. Georgia Power expects to file its twenty-seventh VCM report with the Georgia PSC by August 31, 2022, which will reflect the revised capital cost forecast discussed above and $522 million of construction capital costs incurred from January 1, 2022 through June 30, 2022.

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

Mississippi Power

Performance Evaluation Plan

On June 7, 2022, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2022, resulting in an annual increase in revenues of approximately $18 million, or 1.9%, primarily due to increases in rate base, operations and maintenance expenses, and depreciation and amortization. The rate increase became effective with the first billing cycle of April 2022 in accordance with the PEP rate schedule.

Ad Valorem Tax Adjustment

On June 7, 2022, the Mississippi PSC approved Mississippi Power's annual ad valorem tax adjustment filing for 2022, resulting in an annual increase in revenues of $5 million, effective with the first billing cycle of July 2022.

Municipal and Rural Associations Tariff

On May 26, 2022, Mississippi Power and Cooperative Energy executed an amended shared service agreement (SSA) under which Cooperative Energy will continue to decrease its use of Mississippi Power's generation services under the MRA tariff up to 2.5% annually through 2035. At June 30, 2022, Mississippi Power is serving approximately 400 MWs of Cooperative Energy's annual demand. Beginning in 2036, Cooperative Energy will provide 100% of its electricity requirements at the MRA delivery points under the tariff. Neither party has the option to cancel the amended SSA. On June 30, 2022, Mississippi Power filed a request with the FERC for approval of the amended SSA.

On July 15, 2022, Mississippi Power filed a request with the FERC for a $23 million increase in annual wholesale base revenues under the MRA tariff and requested an effective date of July 15, 2022.

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

Southern Company Gas

Infrastructure Replacement Programs and Capital Projects

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first six months of 2022 were as follows:

Utility	Program	Six Months Ended June 30, 2022
		(in millions)
Nicor Gas	Investing in Illinois	$	177
Virginia Natural Gas	Steps to Advance Virginia's Energy	33
Atlanta Gas Light	System Reinforcement Rider	28
Chattanooga Gas	Pipeline Replacement Program	2
Total		$	240

Rate Proceedings

Atlanta Gas Light

On July 1, 2022, Atlanta Gas Light filed its annual GRAM update with the Georgia PSC. The filing requests an annual base rate increase of $53 million based on the projected 12-month period beginning January 1, 2023. Resolution of the GRAM filing is expected by December 28, 2022, with the new rates effective January 1, 2023. The ultimate outcome of this matter cannot be determined at this time.

Virginia Natural Gas

On May 31, 2022, Virginia Natural Gas filed a notice of intent with the Virginia State Corporation Commission to file a base rate case later in the third quarter 2022. The ultimate outcome of this matter cannot be determined at this time.

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Contingencies

6 Months Ended

Jun. 30, 2022

Commitments and Contingencies Disclosure [Abstract]

Contingencies

CONTINGENCIESSee 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 believe the pending legal challenges discussed below have no merit; however, the ultimate outcome of these matters cannot be determined at this time.

Southern Company

In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits named as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of Georgia. The complaints alleged that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints alleged that the defendants were unjustly enriched and caused the waste of corporate assets and also alleged that the individual defendants violated their fiduciary duties.

In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that named as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. The complaint alleged that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleged that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. In August 2019, the court granted a motion filed by the plaintiff in July 2019 to substitute a new named plaintiff, Martin J. Kobuck, in place of Helen E. Piper Survivor's Trust.

The plaintiffs in each of these cases sought to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiffs also sought certain changes to Southern Company's corporate governance and internal processes. On January 21, 2022, the plaintiffs in the federal court action filed a motion for preliminary approval of settlement, together with an executed stipulation of settlement, which applied to both actions. On June 9, 2022, the U.S. District Court for the Northern District of Georgia granted final approval of the settlement and, on June 16, 2022, the Superior Court of Gwinnett County, Georgia entered an order awarding attorneys' fees and expenses related to the Martin J. Kobuck lawsuit. The settlement consists of an aggregate payment by Southern Company's insurers of approximately $4.5 million for attorneys' fees and expenses, as well as adoption of various corporate governance reforms by Southern Company. These matters are now concluded.

Georgia Power

In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state law claims. This case has been ruled upon and appealed numerous times over the last several years. In 2019, the Georgia PSC issued an order that found Georgia Power has appropriately implemented the municipal franchise fee schedule. In March 2021, the Superior Court of Fulton County granted class certification and Georgia Power's motion for summary judgment and the plaintiffs filed a notice of appeal. In April 2021, Georgia Power filed a notice of cross appeal on the issue of class certification. In December 2021, the Georgia Court of Appeals affirmed the Superior Court's ruling that granted summary judgment to Georgia Power and dismissed Georgia Power's cross appeal on the issue of class certification as moot. Also in December 2021, the plaintiffs filed a petition for writ of certiorari to the Georgia Supreme Court. The amount of any possible losses cannot be estimated at this time because, among other factors, it is unknown whether any losses would be subject to recovery from any municipalities.

In July 2020, a group of individual plaintiffs filed a complaint in the Superior Court of Fulton County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater, surface water, and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages, a medical monitoring fund, and injunctive relief. Georgia Power has filed multiple motions to dismiss the complaint. In October 2021, three additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages. In November 2021, Georgia Power filed a notice to remove the three cases pending in the Superior Court of Monroe County, Georgia to the U.S. District Court for the Middle District of Georgia. On February 7, 2022, four additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power seeking damages for alleged personal injuries or property damage. On March 9, 2022, Georgia Power filed a notice to remove the four cases pending in the Superior Court of Monroe County, Georgia to the U.S. District Court for the Middle District of Georgia. The amount of any possible losses from these matters cannot be estimated at this time.

Mississippi Power

In 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March 2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service. The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds. In November 2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power. In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. On March 21, 2022, the

U.S. Court of Appeals for the Fifth Circuit issued an opinion affirming the dismissal of the claims against the Mississippi PSC defendants but reversing the dismissal of the claims against Mississippi Power. The appellate court remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. On May 31, 2022, the U.S. Court of Appeals for the Fifth Circuit denied a petition by Mississippi Power for a rehearing en banc and the case was remanded back to the trial court for further proceedings. On June 17, 2022, Mississippi Power filed with the trial court a motion to dismiss the complaint. An adverse outcome in this proceeding could have a material impact on Mississippi Power's financial statements.

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 $16 million and $17 million at June 30, 2022 and December 31, 2021, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected.

Southern Company Gas' environmental remediation liability was $241 million and $249 million at June 30, 2022 and December 31, 2021, respectively, based on the estimated cost of environmental investigation and remediation associated with 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

In conjunction with Southern Company's 2019 sale of Gulf Power, NextEra Energy, Inc. held back $75 million of the purchase price pending Mississippi Power and Gulf Power negotiating a mutually acceptable revised operating agreement for Plant Daniel. On July 12, 2022, the co-owners executed a revised operating agreement and Southern Company subsequently received the remaining $75 million of the purchase price. The revised operating agreement contains dispatch procedures for the two jointly-owned coal units at Plant Daniel such that Mississippi Power will designate one of the two units as primary and the other as secondary in lieu of each company separately owning 100% of a single generating unit. Mississippi Power has the option to purchase its co-owner's ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior to that date. The revised operating agreement is not expected to have a material impact on Mississippi Power's financial statements. See Note 15 to the financial statements under "Southern Company" in Item 8 of the Form 10-K for additional information regarding the sale of Gulf Power.

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Revenue from Contracts with Customers and Lease Income

6 Months Ended

Jun. 30, 2022

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers and Lease Income

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. See Note 1 to the financial statements under "Revenues" in Item 8 of the Form 10-K for additional information on the revenue policies of the Registrants. See "Lease Income" herein and Note (J) for additional information on revenue accounted for under lease and derivative accounting guidance, respectively.

The following table disaggregates revenue from contracts with customers for the three and six months ended June 30, 2022 and 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2022
Operating revenues
Retail electric revenues
Residential	$	1,655	$	617	$	962	$	76	$	—	$	—
Commercial	1,387		410		900		77		—		—
Industrial	1,005		368		553		84		—		—
Other	25		3		20		2		—		—
Total retail electric revenues	4,072		1,398		2,435		239		—		—
Natural gas distribution revenues
Residential	474		—		—		—		—		474
Commercial	130		—		—		—		—		130
Transportation	276		—		—		—		—		276
Industrial	16		—		—		—		—		16
Other	67		—		—		—		—		67
Total natural gas distribution revenues	963		—		—		—		—		963
Wholesale electric revenues
PPA energy revenues	585		108		40		5		441		—
PPA capacity revenues	136		40		12		—		85		—
Non-PPA revenues	62		35		6		169		196		—
Total wholesale electric revenues	783		183		58		174		722		—
Other natural gas revenues
Gas marketing services	90		—		—		—		—		90
Other natural gas revenues	10		—		—		—		—		10
Total natural gas revenues	100		—		—		—		—		100
Other revenues	308		63		121		9		9		—
Total revenue from contracts with customers	6,226		1,644		2,614		422		731		1,063
Other revenue sources(a)	980		287		507		12		168		20
Total operating revenues	$	7,206	$	1,931	$	3,121	$	434	$	899	$	1,083

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Six Months Ended June 30, 2022
Operating revenues
Retail electric revenues
Residential	$	3,179	$	1,250	$	1,783	$	146	$	—	$	—
Commercial	2,567		786		1,638		143		—		—
Industrial	1,732		691		887		154		—		—
Other	51		7		40		4		—		—
Total retail electric revenues	7,529		2,734		4,348		447		—		—
Natural gas distribution revenues
Residential	1,490		—		—		—		—		1,490
Commercial	400		—		—		—		—		400
Transportation	613		—		—		—		—		613
Industrial	48		—		—		—		—		48
Other	195		—		—		—		—		195
Total natural gas distribution revenues	2,746		—		—		—		—		2,746
Wholesale electric revenues
PPA energy revenues	930		168		72		8		694		—
PPA capacity revenues	268		78		23		3		166		—
Non-PPA revenues	124		99		15		271		269		—
Total wholesale electric revenues	1,322		345		110		282		1,129		—
Other natural gas revenues
Gas marketing services	333		—		—		—		—		333
Other natural gas revenues	26		—		—		—		—		26
Total natural gas revenues	359		—		—		—		—		359
Other revenues	530		109		216		17		17		—
Total revenue from contracts with customers	12,486		3,188		4,674		746		1,146		3,105
Other revenue sources(a)	1,368		392		654		23		292		35
Total operating revenues	$	13,854	$	3,580	$	5,328	$	769	$	1,438	$	3,140

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2021
Operating revenues
Retail electric revenues
Residential	$	1,469	$	553	$	852	$	64	$	—	$	—
Commercial	1,176		386		724		66		—		—
Industrial	728		334		321		73		—		—
Other	23		4		17		2		—		—
Total retail electric revenues	3,396		1,277		1,914		205		—		—
Natural gas distribution revenues
Residential	311		—		—		—		—		311
Commercial	73		—		—		—		—		73
Transportation	247		—		—		—		—		247
Industrial	8		—		—		—		—		8
Other	59		—		—		—		—		59
Total natural gas distribution revenues	698		—		—		—		—		698
Wholesale electric revenues
PPA energy revenues	209		38		16		2		158		—
PPA capacity revenues	118		29		14		1		75		—
Non-PPA revenues	55		25		3		75		78		—
Total wholesale electric revenues	382		92		33		78		311		—
Other natural gas revenues
Wholesale gas services	578		—		—		—		—		578
Gas marketing services	63		—		—		—		—		63
Other natural gas revenues	10		—		—		—		—		10
Total natural gas revenues	651		—		—		—		—		651
Other revenues	295		52		137		7		5		—
Total revenue from contracts with customers	5,422		1,421		2,084		290		316		1,349
Other revenue sources(a)	1,179		135		141		13		174		731
Other adjustments(b)	(1,403)		—		—		—		—		(1,403)
Total operating revenues	$	5,198	$	1,556	$	2,225	$	303	$	490	$	677

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Six Months Ended June 30, 2021
Operating revenues
Retail electric revenues
Residential	$	2,936	$	1,181	$	1,627	$	128	$	—	$	—
Commercial	2,294		758		1,410		126		—		—
Industrial	1,397		654		606		137		—		—
Other	47		9		34		4		—		—
Total retail electric revenues	6,674		2,602		3,677		395		—		—
Natural gas distribution revenues
Residential	925		—		—		—		—		925
Commercial	243		—		—		—		—		243
Transportation	536		—		—		—		—		536
Industrial	24		—		—		—		—		24
Other	155		—		—		—		—		155
Total natural gas distribution revenues	1,883		—		—		—		—		1,883
Wholesale electric revenues
PPA energy revenues	422		81		30		7		313		—
PPA capacity revenues	237		58		27		4		150		—
Non-PPA revenues	119		57		12		162		139		—
Total wholesale electric revenues	778		196		69		173		602		—
Other natural gas revenues
Wholesale gas services	2,168		—		—		—		—		2,168
Gas marketing services	257		—		—		—		—		257
Other natural gas revenues	17		—		—		—		—		17
Total natural gas revenues	2,442		—		—		—		—		2,442
Other revenues	542		97		249		14		9		—
Total revenue from contracts with customers	12,319		2,895		3,995		582		611		4,325
Other revenue sources(a)	2,488		220		200		28		319		1,745
Other adjustments(b)	(3,699)		—		—		—		—		(3,699)
Total operating revenues	$	11,108	$	3,115	$	4,195	$	610	$	930	$	2,371

(a)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 that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies.

(b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (L) under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively.

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, 2022 and December 31, 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At June 30, 2022	$	3,021	$	773	$	1,217	$	95	$	278	$	504
At December 31, 2021	2,504		589		736		73		149		753
Contract Assets
At June 30, 2022	$	102	$	—	$	38	$	—	$	—	$	—
At December 31, 2021	117		2		63		—		1		—
Contract Liabilities
At June 30, 2022	$	70	$	3	$	25	$	4	$	1	$	—
At December 31, 2021	57		4		14		—		1		—

At June 30, 2022 and December 31, 2021, Georgia Power had contract assets primarily related to 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, and unregulated service agreements, where payment is contingent on project completion. Contract liabilities for Georgia Power relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern Company's unregulated distributed generation business had $63 million and $50 million of contract assets and $38 million and $39 million of contract liabilities at June 30, 2022 and December 31, 2021, respectively, for outstanding performance obligations.

Revenues recognized in the three and six months ended June 30, 2022, which were included in contract liabilities at December 31, 2021, were $10 million and $19 million, respectively, for Southern Company and immaterial for the other Registrants.

Remaining Performance Obligations

The Subsidiary Registrants have 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. For Southern Company Gas, these contracts involve energy infrastructure enhancement and upgrade projects for certain governmental customers. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at June 30, 2022 are expected to be recognized as follows:

	2022 (remaining)		2023		2024		2025		2026		Thereafter
	(in millions)
Southern Company	$	347	$	617	$	414	$	322	$	307	$	2,340
Alabama Power	15		24		7		5		—		—
Georgia Power	39		63		30		22		11		21
Southern Power	184		347		344		294		299		2,334
Southern Company Gas	16		29		29		—		—		—

Revenue expected to be recognized for performance obligations remaining at June 30, 2022 was immaterial for Mississippi Power.

Lease Income

Lease income for the three and six months ended June 30, 2022 and 2021 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended June 30, 2022
Lease income - interest income on sales-type leases	$	7	$	—	$	—	$	4	$	3	$	—
Lease income - operating leases	52		19		8		—		21		9
Variable lease income	129		—		—		—		138		—
Total lease income	$	188	$	19	$	8	$	4	$	162	$	9
For the Six Months Ended June 30, 2022
Lease income - interest income on sales-type leases	$	13	$	—	$	—	$	8	$	5	$	—
Lease income - operating leases	105		39		16		1		42		18
Variable lease income	211		—		—		—		227		—
Total lease income	$	329	$	39	$	16	$	9	$	274	$	18
For the Three Months Ended June 30, 2021
Lease income - interest income on sales-type leases	$	4	$	—	$	—	$	4	$	—	$	—
Lease income - operating leases	56		21		10		—		21		9
Variable lease income	128		(1)		—		—		138		—
Total lease income	$	188	$	20	$	10	$	4	$	159	$	9
For the Six Months Ended June 30, 2021
Lease income - interest income on sales-type leases	$	7	$	—	$	—	$	7	$	—	$	—
Lease income - operating leases	112		41		21		1		42		17
Variable lease income	212		—		—		—		228		—
Total lease income	$	331	$	41	$	21	$	8	$	270	$	17

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 for Alabama Power and Southern Power is included in wholesale revenues.

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Consolidated Entities and Equity Method Investments

6 Months Ended

Jun. 30, 2022

Regulated Operations [Abstract]

Consolidated Entities and Equity Method Investments

CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTSSee Note 7 to the financial statements in Item 8 of the Form 10-K for additional information.

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, 2022 and December 31, 2021, SP Solar had total assets of $6.0 billion and $6.1 billion, respectively, total liabilities of $386 million and $408 million, respectively, and noncontrolling interests of $1.1 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic 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, 2022 and December 31, 2021, SP Wind had total assets of $2.3 billion, total liabilities of $212 million and $130 million, respectively, and noncontrolling interests of $40 million and $41 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.

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, 2022 and December 31, 2021, the other VIEs had total assets of $1.8 billion and $1.9 billion, respectively, total liabilities of $253 million and $263 million, respectively, and noncontrolling interests of $858 million and $886 million, respectively. Under the terms of the partnership agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent.

Equity Method Investments

At June 30, 2022 and December 31, 2021, Southern Power had equity method investments in wind and battery energy storage projects totaling $49 million and $86 million, respectively. Earnings (loss) from these investments were immaterial for both periods presented. During the six months ended June 30, 2022, Southern Power sold equity method investments in wind projects and received proceeds totaling $38 million. The gains associated with the sales were immaterial.

Southern Company Gas

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at June 30, 2022 and December 31, 2021 and related earnings (loss) from those investments for the three and six months ended June 30, 2022 and 2021 were as follows:

Investment Balance	June 30, 2022		December 31, 2021
	(in millions)
SNG	$	1,099	$	1,129
Other(*)	35		44
Total	$	1,134	$	1,173

(*)Balance at June 30, 2022 reflects a $9 million distribution from PennEast Pipeline.

	Three Months Ended June 30,				Six Months Ended June 30,
Earnings (Loss) from Equity Method Investments	2022		2021		2022		2021
	(in millions)
SNG	$	31	$	28	$	70	$	66
PennEast Pipeline(*)	—		(81)		—		(79)
Other	—		1		1		2
Total	$	31	$	(52)	$	71	$	(11)

(*)Includes a pre-tax impairment charge of $82 million ($58 million after tax) for the three and six months ended June 30, 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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Financing and Leases

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

Financing and Leases

FINANCING AND LEASES

Bank Credit Arrangements

See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K for additional information.

At June 30, 2022, committed credit arrangements with banks were as follows:

	Expires
Company	2023		2024		2025		2026		Total		Unused		Expires within One Year
	(in millions)
Southern Company parent	$	—	$	—	$	—	$	2,000	$	2,000	$	1,998	$	—
Alabama Power	—		550		—		700		1,250		1,250		—
Georgia Power	—		—		—		1,750		1,750		1,726		—
Mississippi Power	—		150		125		—		275		275		—
Southern Power(a)	—		—		—		600		600		568		—
Southern Company Gas(b)	250		—		—		1,500		1,750		1,748		250
SEGCO	30		—		—		—		30		30		30
Southern Company	$	280	$	700	$	125	$	6,550	$	7,655	$	7,595	$	280

(a)Does not include Southern Power Company's two $75 million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $11 million and $5 million, respectively, was unused at June 30, 2022. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)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 2026. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $700 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 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. Nicor Gas is also the borrower of a new $250 million credit arrangement expiring in 2023.

As reflected in the table above, in March 2022, Mississippi Power amended and restated its $125 million revolving credit arrangement, which among other things, extended the maturity date from 2023 to 2025 and allows for borrowing based on term SOFR.

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 or, in the case of Southern Power, cross-default provisions to other indebtedness (including guarantee obligations) that are restricted only to the indebtedness

of the individual company. Such cross-default provisions to other indebtedness would trigger an event of default if Southern Power defaulted on indebtedness or guarantee obligations over a specified threshold. Such 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, 2022, 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 the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at June 30, 2022 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi Power). In addition, at June 30, 2022, Georgia Power had approximately $445 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

Equity Units

In May 2022, Southern Company remarketed $862.5 million aggregate principal amount of its Series 2019A Remarketable Junior Subordinated Notes due August 1, 2024 (2019A RSNs) and $862.5 million aggregate principal amount of its Series 2019B Remarketable Junior Subordinated Notes due August 1, 2027 (2019B RSNs), pursuant to the terms of its 2019 Series A Equity Units (Equity Units). In connection with the remarketing, the interest rates on the 2019A RSNs and the 2019B RSNs were reset to 4.475% and 5.113%, respectively, payable on a semi-annual basis, and Southern Company ceased to have the ability to redeem these securities prior to maturity or to defer interest payments. Southern Company did not receive any proceeds from the remarketing, which were used to purchase a portfolio of treasury securities maturing on July 28, 2022. On August 1, 2022, the proceeds from this maturing portfolio will be used to settle the purchase contracts entered into as a part of the Equity Units and Southern Company expects to issue approximately 25.2 million shares of common stock. At June 30, 2022 and December 31, 2021, the 2019A RSNs and the 2019B RSNs are included in long-term debt on Southern Company's consolidated balance sheets.

Earnings per Share

For Southern Company, the only differences in computing basic and diluted earnings per share are attributable to awards outstanding under stock-based compensation plans and the Equity Units issued in 2019. Earnings per share dilution resulting from stock-based compensation plans and the Equity Units issuance is determined using the treasury stock method. See Note 8 to the financial statements under "Equity Units" in Item 8 of the Form 10-K and "Equity Units" herein for information on the equity units and Note 12 to the financial statements in Item 8 of the Form 10-K for information on stock-based compensation plans. Shares used to compute diluted earnings per share were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2022	2021	2022	2021
	(in millions)
As reported shares	1,065	1,061	1,064	1,060
Effect of stock-based compensation	5	6	5	6
Effect of equity units	2	—	1	—
Diluted shares	1,072	1,067	1,070	1,066

For all periods presented, an immaterial number of stock-based compensation awards was not included in the diluted earnings per share calculation because the awards were anti-dilutive.

Southern Company Leveraged Lease

See Note 9 to the financial statements in Item 8 of the Form 10-K for information on a leveraged lease agreement related to energy generation. On June 30, 2022, the Southern Holdings subsidiary operating the generating plant for the lessee provided notice to the lessee to terminate the related operating and maintenance agreement effective June 30, 2023. The parties to the lease agreement are currently negotiating a potential restructuring, which could result in rescission of the termination notice. The ultimate outcome of this matter cannot be determined at this time but is not expected to have a material impact on Southern Company's financial statements.

Georgia Power Lease Modification

See Note 9 to the financial statements in Item 8 of the Form 10-K for information on Georgia Power's leases. Subsequent to June 30, 2022, Georgia Power recognized a lease modification related to an existing non-affiliate PPA which converted from an operating lease to a finance lease upon its approval in the 2022 IRP. As a result, Georgia Power will remove operating lease right-of-use assets, net of amortization of $17 million and lease obligations of $18 million maturing through 2024 and will record finance lease right-of-use assets of $110 million and lease obligations of $111 million maturing through 2039.

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Income Taxes

6 Months Ended

Jun. 30, 2022

Income Tax Disclosure [Abstract]

Income Taxes

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

Tax Credit and Net Operating Loss Carryforwards

Southern Company had federal ITC and PTC carryforwards (primarily related to Southern Power) totaling $0.9 billion at June 30, 2022 compared to $1.2 billion at December 31, 2021.

The federal PTC and ITC carryforwards begin expiring in 2032, but are expected to be fully utilized by 2025. The utilization of each Registrant's estimated tax credit and state net operating loss carryforwards and related valuation allowances could be impacted by numerous factors, including the acquisition of additional renewable projects, the purchase of rights to additional PTCs of Plant Vogtle Units 3 and 4 pursuant to certain joint ownership agreements, an increase in Georgia Power's ownership interest percentage in Plant Vogtle Units 3 and 4, changes in taxable income projections, and potential income tax rate changes. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4.

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 primarily at Southern Power.

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 18.7% for the six months ended June 30, 2022 compared to 10.7% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings and an adjustment related to a prior year state tax credit carryforward at Georgia Power in 2022.

Georgia Power

Georgia Power's effective tax rate was 16.4% for the six months ended June 30, 2022 compared to a tax benefit rate of (6.9)% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings and an adjustment related to a prior year state tax credit carryforward in 2022.

Mississippi Power

Mississippi Power's effective tax rate was 18.8% for the six months ended June 30, 2022 compared to 12.6% for the corresponding period in 2021. The effective tax rate increase was primarily due to a decrease in the flowback of excess deferred income taxes in 2022.

Southern Power

Southern Power's effective tax rate was 11.2% for the six months ended June 30, 2022 compared to a tax benefit rate of (12.8)% for the corresponding period in 2021. The effective tax rate increase was primarily due to higher pre-tax earnings in 2022 and a change in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in the first quarter 2021, partially offset by higher wind PTCs in 2022.

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Retirement Benefits

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Retirement Benefits

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 (ERISA). No mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2022. The Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas has a separate unfunded supplemental retirement health care plan that provides medical care and life insurance benefits to employees of discontinued businesses.

During the first quarter 2022, the qualified pension plan achieved the predetermined funding threshold whereby the asset allocation was adjusted to invest a larger portion of the portfolio in fixed rate debt securities.

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, 2022 and 2021 are presented in the following tables.

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2022
Pension Plans
Service cost	$	103	$	24	$	26	$	4	$	3	$	8
Interest cost	102		24		30		4		1		7
Expected return on plan assets	(317)		(75)		(100)		(14)		(4)		(24)
Amortization:
Prior service costs	—		—		1		—		—		—
Regulatory asset	—		—		—		—		—		4
Net loss	60		15		19		4		—		1
Net periodic pension cost (income)	$	(52)	$	(12)	$	(24)	$	(2)	$	—	$	(4)
Postretirement Benefits
Service cost	$	5	$	2	$	1	$	—	$	—	$	—
Interest cost	11		2		3		1		—		1
Expected return on plan assets	(20)		(8)		(6)		(1)		—		(1)
Amortization:
Regulatory asset	—		—		—		—		—		1
Net loss	—		—		1		—		—		—
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1
Six Months Ended June 30, 2022
Pension Plans
Service cost	$	206	$	49	$	52	$	8	$	5	$	17
Interest cost	204		48		61		9		3		14
Expected return on plan assets	(633)		(152)		(199)		(29)		(8)		(46)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		8
Net loss	120		31		37		7		1		3
Net periodic pension cost (income)	$	(103)	$	(24)	$	(48)	$	(5)	$	1	$	(5)
Postretirement Benefits
Service cost	$	11	$	3	$	3	$	—	$	—	$	1
Interest cost	21		5		7		1		—		2
Expected return on plan assets	(40)		(16)		(13)		(1)		—		(3)
Amortization:
Regulatory asset	—		—		—		—		—		3
Net (gain)/loss	—		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(8)	$	(8)	$	(2)	$	—	$	—	$	2

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2021
Pension Plans
Service cost	$	108	$	25	$	28	$	5	$	3	$	9
Interest cost	86		21		26		4		1		6
Expected return on plan assets	(297)		(71)		(94)		(13)		(4)		(22)
Amortization:
Prior service costs	—		—		1		—		—		—
Regulatory asset	—		—		—		—		—		4
Net loss	79		20		25		3		1		3
Net periodic pension cost (income)	$	(24)	$	(5)	$	(14)	$	(1)	$	1	$	—
Postretirement Benefits
Service cost	$	6	$	2	$	1	$	—	$	—	$	1
Interest cost	9		2		3		1		—		1
Expected return on plan assets	(19)		(7)		(6)		(1)		—		(2)
Amortization:
Prior service costs	(1)		—		—		—		—		—
Regulatory asset	—		—		—		—		—		1
Net loss	1		—		—		—		—		—
Net periodic postretirement benefit cost (income)	$	(4)	$	(3)	$	(2)	$	—	$	—	$	1
Six Months Ended June 30, 2021
Pension Plans
Service cost	$	217	$	51	$	56	$	9	$	5	$	18
Interest cost	173		41		52		8		2		12
Expected return on plan assets	(595)		(143)		(188)		(27)		(7)		(43)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		8
Net loss	157		41		50		7		2		6
Net periodic pension cost (income)	$	(48)	$	(10)	$	(29)	$	(3)	$	2	$	—
Postretirement Benefits
Service cost	$	12	$	3	$	3	$	—	$	—	$	1
Interest cost	17		4		6		1		—		2
Expected return on plan assets	(38)		(14)		(13)		(1)		—		(4)
Amortization:
Prior service costs	(1)		—		—		—		—		—
Regulatory asset	—		—		—		—		—		3
Net (gain)/loss	2		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(8)	$	(7)	$	(3)	$	—	$	—	$	1

XML

Fair Value Measurements

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS

At June 30, 2022, 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, 2022	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)	$	43	$	408	$	—	$	—	$	451
Investments in trusts:(b)(c)
Domestic equity	643		168		—		—		811
Foreign equity	122		144		—		—		266
U.S. Treasury and government agency securities	—		273		—		—		273
Municipal bonds	—		56		—		—		56
Pooled funds – fixed income	—		9		—		—		9
Corporate bonds	1		445		—		—		446
Mortgage and asset backed securities	—		89		—		—		89
Private equity	—		—		—		164		164
Cash and cash equivalents	3		—		—		—		3
Other	36		17		—		—		53
Cash equivalents	1,058		10		—		—		1,068
Other investments	9		27		—		—		36
Total	$	1,915	$	1,646	$	—	$	164	$	3,725
Liabilities:
Energy-related derivatives(a)	$	16	$	88	$	—	$	—	$	104
Interest rate derivatives	—		214		—		—		214
Foreign currency derivatives	—		228		—		—		228
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	16	$	543	$	14	$	—	$	573

	Fair Value Measurements Using:
At June 30, 2022	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	$	—	$	131	$	—	$	—	$	131
Nuclear decommissioning trusts:(b)
Domestic equity	391		159		—		—		550
Foreign equity	122		—		—		—		122
U.S. Treasury and government agency securities	—		17		—		—		17
Municipal bonds	—		2		—		—		2
Corporate bonds	1		227		—		—		228
Mortgage and asset backed securities	—		20		—		—		20
Private equity	—		—		—		164		164
Other	20		—		—		—		20
Cash equivalents	677		10		—		—		687
Other investments	—		27		—		—		27
Total	$	1,211	$	593	$	—	$	164	$	1,968
Liabilities:
Energy-related derivatives	$	—	$	23	$	—	$	—	$	23
Georgia Power
Assets:
Energy-related derivatives	$	—	$	137	$	—	$	—	$	137
Nuclear decommissioning trusts:(b)(c)
Domestic equity	252		1		—		—		253
Foreign equity	—		142		—		—		142
U.S. Treasury and government agency securities	—		256		—		—		256
Municipal bonds	—		54		—		—		54
Corporate bonds	—		218		—		—		218
Mortgage and asset backed securities	—		69		—		—		69
Other	16		17		—		—		33
Cash equivalents	98		—		—		—		98
Total	$	366	$	894	$	—	$	—	$	1,260
Liabilities:
Energy-related derivatives	$	—	$	29	$	—	$	—	$	29

	Fair Value Measurements Using:
At June 30, 2022	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	$	—	$	121	$	—	$	—	$	121
Liabilities:
Energy-related derivatives	$	—	$	14	$	—	$	—	$	14
Southern Power
Assets:
Energy-related derivatives	$	—	$	6	$	—	$	—	$	6
Liabilities:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1
Foreign currency derivatives	—		45		—		—		45
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	—	$	59	$	14	$	—	$	73
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	43	$	13	$	—	$	—	$	56
Non-qualified deferred compensation trusts:
Domestic equity	—		8		—		—		8
Foreign equity	—		2		—		—		2
Pooled funds – fixed income	—		9		—		—		9
Cash equivalents	3		—		—		—		3
Cash equivalents and restricted cash	192		—		—		—		192
Total	$	238	$	32	$	—	$	—	$	270
Liabilities:
Energy-related derivatives(a)	$	16	$	20	$	—	$	—	$	36
Interest rate derivatives	—		62		—		—		62
Total	$	16	$	82	$	—	$	—	$	98

(a)Excludes cash collateral of $13 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 in Item 8 of the Form 10-K for additional information.

(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. At June 30, 2022, approximately $65 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements 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 the three and six months ended June 30, 2022 and 2021. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

Fair value increases (decreases)	Three Months Ended June 30, 2022		Three Months Ended June 30, 2021		Six Months Ended June 30, 2022		Six Months Ended June 30, 2021
	(in millions)
Southern Company	$	(230)	$	125	$	(380)	$	164
Alabama Power	(125)		77		(192)		118
Georgia Power	(105)		48		(188)		46

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 Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility 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

contingent consideration 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" include 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, 2022, the fair value measurements of private equity 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 $164 million and unfunded commitments related to the private equity investments totaled $91 million. Private equity investments include high-quality private equity funds across several market sectors and funds that invest in real estate assets. Private equity 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, 2022, 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	$	52.0	$	9.8	$	14.6	$	1.5	$	3.0	$	6.8
Fair value	48.0		9.0		13.7		1.3		2.9		6.2

(*)The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at 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.

XML

Derivatives

6 Months Ended

Jun. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

DERIVATIVESThe 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. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' wholesale gas operations used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, 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. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information regarding the sale of Sequent.

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 operating 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 operating 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.

At June 30, 2022, 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(*)	273	2030	2025
Alabama Power	65	2026	—
Georgia Power	75	2025	—
Mississippi Power	71	2026	—
Southern Power	4	2030	—
Southern Company Gas(*)	58	2024	2025

(*)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 long natural gas positions of 64.4 million mmBtu and short natural gas positions of 6.4 million mmBtu at June 30, 2022, which is also included in Southern Company's total volume.

In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is 15 million mmBtu for Southern Company, which includes 4 million mmBtu for Alabama Power, 5 million mmBtu for Georgia Power, 2 million mmBtu for Mississippi Power, and 4 million mmBtu for Southern Power.

For cash flow hedges of energy-related derivatives, the estimated pre-tax gains expected to be reclassified from accumulated OCI to earnings for the 12-month period ending June 30, 2023 total $12 million for both Southern Company and Southern Company Gas and are immaterial for the other Registrants.

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.

At June 30, 2022, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at June 30, 2022
	(in millions)					(in millions)
Cash Flow Hedges of Existing Debt
Alabama Power	$	50	—	3.18%	August 2027	$	—
Southern Company Gas	250		—	3.26%	August 2032	(5)
Fair Value Hedges of Existing Debt
Southern Company parent	400		1.75%	1-month LIBOR + 0.68%	March 2028	(39)
Southern Company parent	1,000		3.70%	1-month LIBOR + 2.36%	April 2030	(113)
Southern Company Gas	500		1.75%	1-month LIBOR + 0.38%	January 2031	(57)
Southern Company	$	2,200				$	(214)

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, 2023 total $(16) million for Southern Company and are immaterial for the other Registrants. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2052 for Southern Company, Alabama Power, and Georgia Power, 2028 for Mississippi 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.

At June 30, 2022, 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, 2022
	(in millions)			(in millions)				(in millions)
Fair Value Hedges of Existing Debt
Southern Company parent	$	1,476	3.39%	€	1,250	1.88%	September 2027	$	(183)
Cash Flow Hedges of Existing Debt
Southern Power	564		3.78%	500		1.85%	June 2026	(45)
Southern Company	$	2,040		€	1,750			$	(228)

For cash flow hedges of foreign currency derivatives, the estimated pre-tax losses expected to be reclassified from accumulated OCI to earnings for the 12-month period ending June 30, 2023 are $11 million for Southern Company and 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.

The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	267	$	49	$	129	$	30
Other deferred charges and assets/Other deferred credits and liabilities	144		37		72		6
Total derivatives designated as hedging instruments for regulatory purposes	$	411	$	86	$	201	$	36
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	17	$	5	$	7	$	5
Other deferred charges and assets/Other deferred credits and liabilities	6		—		1		—
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	—		19		19		—
Other deferred charges and assets/Other deferred credits and liabilities	—		195		—		29
Foreign currency derivatives:
Assets from risk management activities/Other current liabilities	—		36		—		39
Other deferred charges and assets/Other deferred credits and liabilities	—		192		—		40
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	23	$	447	$	27	$	113
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	15	$	12	$	9	$	4
Other deferred charges and assets/Other deferred credits and liabilities	2		1		1		—
Total derivatives not designated as hedging instruments	$	17	$	13	$	10	$	4
Gross amounts recognized	$	451	$	546	$	238	$	153
Gross amounts offset(a)	(87)		(74)		(25)		(28)
Net amounts recognized in the Balance Sheets(b)	$	364	$	472	$	213	$	125

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	76	$	6	$	30	$	9
Other deferred charges and assets/Other deferred credits and liabilities	55		17		25		2
Total derivatives designated as hedging instruments for regulatory purposes	$	131	$	23	$	55	$	11
Gross amounts offset	(20)		(20)		(5)		(5)
Net amounts recognized in the Balance Sheets	$	111	$	3	$	50	$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	102	$	15	$	54	$	6
Other deferred charges and assets/Other deferred credits and liabilities	35		14		21		2
Total derivatives designated as hedging instruments for regulatory purposes	$	137	$	29	$	75	$	8
Gross amounts offset	(21)		(21)		(8)		(8)
Net amounts recognized in the Balance Sheets	$	116	$	8	$	67	$	—
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	67	$	8	$	30	$	3
Other deferred charges and assets/Other deferred credits and liabilities	54		6		26		2
Total derivatives designated as hedging instruments for regulatory purposes	$	121	$	14	$	56	$	5
Gross amounts offset	(11)		(11)		(4)		(4)
Net amounts recognized in the Balance Sheets	$	110	$	3	$	52	$	1

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	—	$	—	$	2	$	—
Other deferred charges and assets/Other deferred credits and liabilities	4		—		1		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		11		—		16
Other deferred charges and assets/Other deferred credits and liabilities	—		34		—		—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	4	$	45	$	3	$	16
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	1	$	1	$	1	$	—
Other deferred charges and assets/Other deferred credits and liabilities	1		—		—		—
Total derivatives not designated as hedging instruments	$	2	$	1	$	1	$	—
Gross amounts recognized	$	6	$	46	$	4	$	16
Gross amounts offset	(1)		(1)		—		—
Net amounts recognized in the Balance Sheets	$	5	$	45	$	4	$	16

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	23	$	19	$	15	$	12
Total derivatives designated as hedging instruments for regulatory purposes	$	23	$	19	$	15	$	12
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	17	$	5	$	5	$	5
Other deferred charges and assets/Other deferred credits and liabilities	2		—		—		—
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	—		—		6		—
Other deferred charges and assets/Other deferred credits and liabilities	—		62		—		6
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	19	$	67	$	11	$	11
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	13	$	11	$	8	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		1		1		—
Total derivatives not designated as hedging instruments	$	14	$	12	$	9	$	4
Gross amounts recognized	$	56	$	98	$	35	$	27
Gross amounts offset(a)	(34)		(21)		(8)		(11)
Net amounts recognized in the Balance Sheets(b)	$	22	$	77	$	27	$	16

(a)Gross amounts offset include cash collateral held on deposit in broker margin accounts of $13 million and $3 million at June 30, 2022 and December 31, 2021, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives at December 31, 2021. There were no such amounts at June 30, 2022.

Energy-related derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies at June 30, 2022. There were no such instruments for the traditional electric operating companies at December 31, 2021.

At June 30, 2022 and December 31, 2021, 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, 2022:
Energy-related derivatives:
Other regulatory assets, current	$	(26)	$	(2)	$	(6)	$	(3)	$	(15)
Other regulatory assets, deferred	(3)		(1)		(1)		(1)		—
Other regulatory liabilities, current	234		72		93		62		7
Other regulatory liabilities, deferred	110		39		22		49		—
Total energy-related derivative gains (losses)	$	315	$	108	$	108	$	107	$	(8)
At December 31, 2021:
Energy-related derivatives:
Other regulatory assets, current	$	(17)	$	(6)	$	—	$	—	$	(11)
Other regulatory liabilities, current	107		28		48		27		4
Other regulatory liabilities, deferred	65		22		19		24		—
Total energy-related derivative gains (losses)	$	155	$	44	$	67	$	51	$	(7)

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	(1)	$	16	$	41	$	20
Interest rate derivatives	21		(1)		30		2
Foreign currency derivatives	(74)		4		(102)		(43)
Fair value hedges(*):
Foreign currency derivatives	(7)		—		(3)		—
Total	$	(61)	$	19	$	(34)	$	(21)
Georgia Power
Interest rate derivatives	$	19	$	—	$	31	$	—
Southern Power
Cash flow hedges:
Energy-related derivatives	$	2	$	5	$	7	$	8
Foreign currency derivatives	(74)		4		(102)		(43)
Total	$	(72)	$	9	$	(95)	$	(35)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	(2)	$	11	$	35	$	12
Interest rate derivatives	(5)		—		(5)		—
Total	$	(7)	$	11	$	30	$	12

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

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other Registrants.

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows:

Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Southern Company
Total cost of natural gas	$	452	$	231	$	1,546	$	814
Gain (loss) on energy-related cash flow hedges(a)	10		1		18		(2)
Total depreciation and amortization	913		891		1,805		1,762
Gain (loss) on energy-related cash flow hedges(a)	4		1		6		4
Total interest expense, net of amounts capitalized	(488)		(450)		(950)		(901)
Gain (loss) on interest rate cash flow hedges(a)	(6)		(7)		(13)		(14)
Gain (loss) on foreign currency cash flow hedges(a)	(7)		(6)		(13)		(12)
Gain (loss) on interest rate fair value hedges(b)	(76)		(3)		(198)		(12)
Total other income (expense), net	139		101		283		160
Gain (loss) on foreign currency cash flow hedges(a)(c)	(73)		17		(97)		(43)
Gain (loss) on foreign currency fair value hedges	(96)		—		(121)		—
Amount excluded from effectiveness testing recognized in earnings	7		—		3		—
Southern Power
Total depreciation and amortization	$	131	$	132	$	251	$	251
Gain (loss) on energy-related cash flow hedges(a)	4		1		6		4
Total interest expense, net of amounts capitalized	(36)		(37)		(73)		(75)
Gain (loss) on foreign currency cash flow hedges(a)	(7)		(6)		(13)		(12)
Total other income (expense), net	1		1		3		8
Gain (loss) on foreign currency cash flow hedges(a)(c)	(73)		17		(97)		(43)
Southern Company Gas
Total cost of natural gas	$	452	$	231	$	1,546	$	814
Gain (loss) on energy-related cash flow hedges(a)	10		—		18		(2)
Total interest expense, net of amounts capitalized	(61)		(59)		(122)		(118)
Gain (loss) on interest rate cash flow hedges(a)	(1)		(1)		(1)		(1)
Gain (loss) on interest rate fair value hedges(b)	(22)		4		(57)		4

(a)Reclassified from accumulated OCI into earnings.

(b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income.

(c)The reclassification from accumulated OCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes.

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income for energy-related derivatives and interest rate derivatives were immaterial for the traditional electric operating companies.

At June 30, 2022 and December 31, 2021, 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, 2022		At December 31, 2021		At June 30, 2022		At December 31, 2021
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(2,981)	$	(3,280)	$	192	$	9
Southern Company Gas
Long-term debt	$	(437)	$	(493)	$	59	$	2

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas were as follows:

		Gain (Loss)
		Three Months Ended June 30,				Six Months Ended June 30,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location	2022		2021		2022		2021
		(in millions)				(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	(15)	$	(103)	$	(13)	$	(120)
	Cost of natural gas	(25)		9		(5)		16
Total derivatives in non-designated hedging relationships		$	(40)	$	(94)	$	(18)	$	(104)

(*)Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for the other Registrants.

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. At June 30, 2022, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For the applicable Registrants, the fair value of interest rate and 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, 2022. 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. Following the sale of Gulf Power to NextEra Energy, Inc., Gulf Power continued participating in the Southern Company power pool through July 13, 2022.

Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. If collateral is required, fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against fair value amounts recognized for derivatives executed with the same counterparty.

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, 2022, cash collateral posted in these accounts was immaterial. 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. At June 30, 2022, cash collateral held on deposit in broker margin accounts was $13 million.

The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants only enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's and S&P 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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Acquisitions and Dispositions

6 Months Ended

Jun. 30, 2022

Business Combination and Asset Acquisition [Abstract]

Acquisitions and Dispositions

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

Southern Power

Construction Projects

During the six months ended June 30, 2022, Southern Power completed construction of and placed in service the remaining 40 MWs of the Tranquillity battery energy storage facility and the remaining 15 MWs of the Garland battery energy storage facility.

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	COD	PPA Contract Period
Projects Completed During the Six Months Ended June 30, 2022
Garland Solar Storage(a)	Battery energy storage system	88	Kern County, CA	September 2021 through February 2022(b)	20 years
Tranquillity Solar Storage(a)	Battery energy storage system	72	Fresno County, CA	November 2021 through March 2022(c)	20 years

(a)Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest.

(b)The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in February 2022.

(c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in March 2022.

Southern Company Gas

On May 20, 2022, Southern Company Gas received the final $5 million contingent payment from Dominion Modular LNG Holdings, Inc. in connection with its 2020 sale of Pivotal LNG, Inc.

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Segment and Related Information

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Segment and Related Information

SEGMENT AND RELATED 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, 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. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' other businesses also included wholesale gas 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. Revenues from sales by Southern Power to the traditional electric operating companies were $232 million and $337 million for the three and six months ended June 30, 2022, respectively, and $112 million and $193 million for the three and six months ended June 30, 2021, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for all periods presented. Revenues from sales of natural gas from Southern Company Gas (prior to its sale of Sequent) to Southern Power were $6 million and $18 million for the three and six months ended June 30, 2021, respectively. 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 and, for the three and six months ended June 30, 2021, leveraged lease projects. All other inter-segment revenues are not material.

Financial data for business segments and products and services for the three and six months ended June 30, 2022 and 2021 was as follows:

	Electric Utilities
	Traditional Electric Operating Companies		Southern Power		Eliminations		Total		Southern Company Gas		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended June 30, 2022
Operating revenues	$	5,563	$	899	$	(456)	$	6,006	$	1,083	$	159	$	(42)	$	7,206
Segment net income (loss)(a)(b)	1,036		98		—		1,134		115		(137)		(5)		1,107
Six Months Ended June 30, 2022
Operating revenues	$	9,778	$	1,438	$	(700)	$	10,516	$	3,140	$	283	$	(85)	$	13,854
Segment net income (loss)(a)(b)	1,811		170		—		1,981		433		(263)		(12)		2,139
At June 30, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	92,742		13,402		(787)		105,357		23,618		2,457		(663)		130,769
Three Months Ended June 30, 2021
Operating revenues	$	4,031	$	490	$	(114)	$	4,407	$	677	$	154	$	(40)	$	5,198
Segment net income (loss)(a)(b)(c)	511		36		—		547		(65)		(108)		(2)		372
Six Months Ended June 30, 2021
Operating revenues	$	7,795	$	930	$	(201)	$	8,524	$	2,371	$	288	$	(75)	$	11,108
Segment net income (loss)(a)(b)(c)(d)	1,267		133		—		1,400		333		(216)		(9)		1,508
At December 31, 2021
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	89,051		13,390		(667)		101,774		23,560		2,975		(775)		127,534

(a)Attributable to Southern Company.

(b)For the traditional electric operating companies, includes pre-tax charges at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4 of $52 million ($39 million after tax) for the three and six months ended June 30, 2022 and $460 million ($343 million after tax) and $508 million ($379 million after tax) for the three and six months ended June 30, 2021, respectively. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

(c)For Southern Company Gas, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to its equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

(d)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended June 30, 2022	$	4,789	$	937	$	280	$	6,006
Three Months Ended June 30, 2021	3,599		546		262		4,407
Six Months Ended June 30, 2022	$	8,402	$	1,601	$	513	$	10,516
Six Months Ended June 30, 2021	6,941		1,091		492		8,524

	Southern Company Gas' Revenues
	Gas Distribution Operations		Wholesale Gas Services(*)		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended June 30, 2022	$	975	$	—	$	92	$	16	$	1,083
Three Months Ended June 30, 2021	706		(110)		64		17		677
Six Months Ended June 30, 2022	$	2,765	$	—	$	335	$	40	$	3,140
Six Months Ended June 30, 2021	1,898		188		259		26		2,371

(*)Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. See "Southern Company Gas" herein and Note 15 to the financial statements under "Southern Company Gas" 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. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information on the sale of Sequent.

Gas distribution operations 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.

Gas pipeline investments 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. Gas pipeline investments also includes a 20% ownership interest in the PennEast Pipeline project, which was cancelled in September 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Through July 1, 2021, wholesale gas services provided natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engaged in natural gas storage and gas pipeline arbitrage and related activities.

Gas marketing services 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.

Business segment financial data for the three and six months ended June 30, 2022 and 2021 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Wholesale Gas Services(a)		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended June 30, 2022
Operating revenues	$	980	$	8	$	—	$	92	$	1,080	$	10	$	(7)	$	1,083
Segment net income (loss)	92		23		—		1		116		(1)		—		115
Six Months Ended June 30, 2022
Operating revenues	$	2,782	$	16	$	—	$	335	$	3,133	$	26	$	(19)	$	3,140
Segment net income (loss)	306		52		—		67		425		8		—		433
Total assets at June 30, 2022	21,183		1,433		—		1,554		24,170		11,999		(12,551)		23,618
Three Months Ended June 30, 2021
Operating revenues	$	710	$	8	$	(110)	$	64	$	672	$	11	$	(6)	$	677
Segment net income (loss)(b)	80		(36)		(112)		6		(62)		(3)		—		(65)
Six Months Ended June 30, 2021
Operating revenues	$	1,910	$	16	$	188	$	259	$	2,373	$	18	$	(20)	$	2,371
Segment net income (loss)(b)	263		(7)		14		62		332		1		—		333
Total assets at December 31, 2021	20,917		1,467		31		1,556		23,971		12,114		(12,525)		23,560

(a)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three and six months ended June 30, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended June 30, 2021	$	1,292	$	27	$	1,319	$	1,429	$	(110)
Six Months Ended June 30, 2021	3,881		90		3,971		3,783		188

(b)For gas pipeline investments, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to the equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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Introduction (Policies)

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Accounting

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, 2021 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, 2022 and 2021. Certain information and footnote 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.

Reclassifications

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

Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if impairment indicators arise.

Natural Gas for Sale

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 other than 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.

Valuation Methodologies

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 Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate.

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. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' wholesale gas operations used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, 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. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information regarding the sale of Sequent.

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 operating 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 operating 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.

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.

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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Introduction (Tables)

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Goodwill

Goodwill at June 30, 2022 and December 31, 2021 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,280
Southern Company Gas:
Gas distribution operations	$	4,034
Gas marketing services	981
Southern Company Gas total	$	5,015

Schedule of Other Intangible Assets, Indefinite-Lived

Other intangible assets were as follows:

	At June 30, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(157)	$	55	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(119)		271		390		(109)		281
Other	10		(9)		1		11		(10)		1
Total other intangible assets subject to amortization	$	676	$	(326)	$	350	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	751	$	(326)	$	425	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(119)	$	271	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(135)	$	21	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(151)	$	31	$	182	$	(145)	$	37

Schedule of Other Intangible Assets, Finite-Lived

Other intangible assets were as follows:

	At June 30, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(157)	$	55	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(119)		271		390		(109)		281
Other	10		(9)		1		11		(10)		1
Total other intangible assets subject to amortization	$	676	$	(326)	$	350	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	751	$	(326)	$	425	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(119)	$	271	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(135)	$	21	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(151)	$	31	$	182	$	(145)	$	37

Schedule of Amortization of Other Intangible Assets

Amortization associated with other intangible assets was as follows:

	Three Months Ended		Six Months Ended
	June 30, 2022
	(in millions)
Southern Company(a)	$	9	$	19
Southern Power(b)	5		10
Southern Company Gas	2		5

(a)Includes $5 million and $10 million for the three and six months ended June 30, 2022, respectively, recorded as a reduction to operating revenues.

(b)Recorded as a reduction to operating revenues.

Schedule of Restrictions on Cash and Cash Equivalents

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,724	$	1,798	$	202	$	107	$	217	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,735	$	1,829	$	211	$	135	$	218	$	48

(a)For Southern Power, reflects $9 million and $10 million at June 30, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

Schedule of Cash and Cash Equivalents

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,724	$	1,798	$	202	$	107	$	217	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,735	$	1,829	$	211	$	135	$	218	$	48

(a)For Southern Power, reflects $9 million and $10 million at June 30, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

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Regulatory Matters (Tables)

6 Months Ended

Jun. 30, 2022

Regulated Operations [Abstract]

Schedule of Cost Recovery Clauses

The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at June 30, 2022 and December 31, 2021 were as follows:

Regulatory Clause	Balance Sheet Line Item	June 30, 2022		December 31, 2021
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, deferred	$	29	$	16
Rate CNP PPA	Other regulatory assets, deferred	93		84
Retail Energy Cost Recovery(*)	Other regulatory assets, current	60		—
	Other regulatory assets, deferred	191		126
Georgia Power
Fuel Cost Recovery	Deferred under recovered fuel clause revenues	$	948	$	410
Mississippi Power
Fuel Cost Recovery	Other customer accounts receivable	$	29	$	4
Ad Valorem Tax	Other regulatory assets, current	12		12
	Other regulatory assets, deferred	29		37
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	361	$	266
	Other regulatory assets, deferred	15		207

(*)In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.

Nuclear Construction Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,393
Construction contingency estimate	60
Total project capital cost forecast(a)(b)	10,453
Net investment at June 30, 2022(b)	(8,966)
Remaining estimate to complete	$	1,487

(a)Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $455 million of incremental costs under the cost-sharing and tender provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through AFUDC of approximately $385 million, of which $247 million had been accrued through June 30, 2022.

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

Schedule of Infrastructure Replacement Programs and Capital Projects

Georgia Power has requested recovery of the proposed increases through its existing base rate tariffs as follows:

Tariff	2023		2024		2025
	(in millions)
Traditional base	$	739	$	—	$	—
ECCR
Traditional	(1)		—		—
CCR ARO(a)	64		78		47
DSM(a)	30		27		(2)
Municipal Franchise Fee	20		2		1
Total(b)	$	852	$	107	$	45

(a)As determined by the Georgia PSC through annual compliance filings.

(b)Totals may not add due to rounding.

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first six months of 2022 were as follows:

Utility	Program	Six Months Ended June 30, 2022
		(in millions)
Nicor Gas	Investing in Illinois	$	177
Virginia Natural Gas	Steps to Advance Virginia's Energy	33
Atlanta Gas Light	System Reinforcement Rider	28
Chattanooga Gas	Pipeline Replacement Program	2
Total		$	240

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Revenue from Contracts with Customers and Lease Income (Tables)

6 Months Ended

Jun. 30, 2022

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue

The following table disaggregates revenue from contracts with customers for the three and six months ended June 30, 2022 and 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2022
Operating revenues
Retail electric revenues
Residential	$	1,655	$	617	$	962	$	76	$	—	$	—
Commercial	1,387		410		900		77		—		—
Industrial	1,005		368		553		84		—		—
Other	25		3		20		2		—		—
Total retail electric revenues	4,072		1,398		2,435		239		—		—
Natural gas distribution revenues
Residential	474		—		—		—		—		474
Commercial	130		—		—		—		—		130
Transportation	276		—		—		—		—		276
Industrial	16		—		—		—		—		16
Other	67		—		—		—		—		67
Total natural gas distribution revenues	963		—		—		—		—		963
Wholesale electric revenues
PPA energy revenues	585		108		40		5		441		—
PPA capacity revenues	136		40		12		—		85		—
Non-PPA revenues	62		35		6		169		196		—
Total wholesale electric revenues	783		183		58		174		722		—
Other natural gas revenues
Gas marketing services	90		—		—		—		—		90
Other natural gas revenues	10		—		—		—		—		10
Total natural gas revenues	100		—		—		—		—		100
Other revenues	308		63		121		9		9		—
Total revenue from contracts with customers	6,226		1,644		2,614		422		731		1,063
Other revenue sources(a)	980		287		507		12		168		20
Total operating revenues	$	7,206	$	1,931	$	3,121	$	434	$	899	$	1,083

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Six Months Ended June 30, 2022
Operating revenues
Retail electric revenues
Residential	$	3,179	$	1,250	$	1,783	$	146	$	—	$	—
Commercial	2,567		786		1,638		143		—		—
Industrial	1,732		691		887		154		—		—
Other	51		7		40		4		—		—
Total retail electric revenues	7,529		2,734		4,348		447		—		—
Natural gas distribution revenues
Residential	1,490		—		—		—		—		1,490
Commercial	400		—		—		—		—		400
Transportation	613		—		—		—		—		613
Industrial	48		—		—		—		—		48
Other	195		—		—		—		—		195
Total natural gas distribution revenues	2,746		—		—		—		—		2,746
Wholesale electric revenues
PPA energy revenues	930		168		72		8		694		—
PPA capacity revenues	268		78		23		3		166		—
Non-PPA revenues	124		99		15		271		269		—
Total wholesale electric revenues	1,322		345		110		282		1,129		—
Other natural gas revenues
Gas marketing services	333		—		—		—		—		333
Other natural gas revenues	26		—		—		—		—		26
Total natural gas revenues	359		—		—		—		—		359
Other revenues	530		109		216		17		17		—
Total revenue from contracts with customers	12,486		3,188		4,674		746		1,146		3,105
Other revenue sources(a)	1,368		392		654		23		292		35
Total operating revenues	$	13,854	$	3,580	$	5,328	$	769	$	1,438	$	3,140

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2021
Operating revenues
Retail electric revenues
Residential	$	1,469	$	553	$	852	$	64	$	—	$	—
Commercial	1,176		386		724		66		—		—
Industrial	728		334		321		73		—		—
Other	23		4		17		2		—		—
Total retail electric revenues	3,396		1,277		1,914		205		—		—
Natural gas distribution revenues
Residential	311		—		—		—		—		311
Commercial	73		—		—		—		—		73
Transportation	247		—		—		—		—		247
Industrial	8		—		—		—		—		8
Other	59		—		—		—		—		59
Total natural gas distribution revenues	698		—		—		—		—		698
Wholesale electric revenues
PPA energy revenues	209		38		16		2		158		—
PPA capacity revenues	118		29		14		1		75		—
Non-PPA revenues	55		25		3		75		78		—
Total wholesale electric revenues	382		92		33		78		311		—
Other natural gas revenues
Wholesale gas services	578		—		—		—		—		578
Gas marketing services	63		—		—		—		—		63
Other natural gas revenues	10		—		—		—		—		10
Total natural gas revenues	651		—		—		—		—		651
Other revenues	295		52		137		7		5		—
Total revenue from contracts with customers	5,422		1,421		2,084		290		316		1,349
Other revenue sources(a)	1,179		135		141		13		174		731
Other adjustments(b)	(1,403)		—		—		—		—		(1,403)
Total operating revenues	$	5,198	$	1,556	$	2,225	$	303	$	490	$	677

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Six Months Ended June 30, 2021
Operating revenues
Retail electric revenues
Residential	$	2,936	$	1,181	$	1,627	$	128	$	—	$	—
Commercial	2,294		758		1,410		126		—		—
Industrial	1,397		654		606		137		—		—
Other	47		9		34		4		—		—
Total retail electric revenues	6,674		2,602		3,677		395		—		—
Natural gas distribution revenues
Residential	925		—		—		—		—		925
Commercial	243		—		—		—		—		243
Transportation	536		—		—		—		—		536
Industrial	24		—		—		—		—		24
Other	155		—		—		—		—		155
Total natural gas distribution revenues	1,883		—		—		—		—		1,883
Wholesale electric revenues
PPA energy revenues	422		81		30		7		313		—
PPA capacity revenues	237		58		27		4		150		—
Non-PPA revenues	119		57		12		162		139		—
Total wholesale electric revenues	778		196		69		173		602		—
Other natural gas revenues
Wholesale gas services	2,168		—		—		—		—		2,168
Gas marketing services	257		—		—		—		—		257
Other natural gas revenues	17		—		—		—		—		17
Total natural gas revenues	2,442		—		—		—		—		2,442
Other revenues	542		97		249		14		9		—
Total revenue from contracts with customers	12,319		2,895		3,995		582		611		4,325
Other revenue sources(a)	2,488		220		200		28		319		1,745
Other adjustments(b)	(3,699)		—		—		—		—		(3,699)
Total operating revenues	$	11,108	$	3,115	$	4,195	$	610	$	930	$	2,371

(a)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 that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies.

(b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (L) under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively.

Schedule of 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, 2022 and December 31, 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At June 30, 2022	$	3,021	$	773	$	1,217	$	95	$	278	$	504
At December 31, 2021	2,504		589		736		73		149		753
Contract Assets
At June 30, 2022	$	102	$	—	$	38	$	—	$	—	$	—
At December 31, 2021	117		2		63		—		1		—
Contract Liabilities
At June 30, 2022	$	70	$	3	$	25	$	4	$	1	$	—
At December 31, 2021	57		4		14		—		1		—

Schedule of Remaining Performance Obligations

Revenues from contracts with customers related to these performance obligations remaining at June 30, 2022 are expected to be recognized as follows:

	2022 (remaining)		2023		2024		2025		2026		Thereafter
	(in millions)
Southern Company	$	347	$	617	$	414	$	322	$	307	$	2,340
Alabama Power	15		24		7		5		—		—
Georgia Power	39		63		30		22		11		21
Southern Power	184		347		344		294		299		2,334
Southern Company Gas	16		29		29		—		—		—

Schedule of Lease Income

Lease income for the three and six months ended June 30, 2022 and 2021 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended June 30, 2022
Lease income - interest income on sales-type leases	$	7	$	—	$	—	$	4	$	3	$	—
Lease income - operating leases	52		19		8		—		21		9
Variable lease income	129		—		—		—		138		—
Total lease income	$	188	$	19	$	8	$	4	$	162	$	9
For the Six Months Ended June 30, 2022
Lease income - interest income on sales-type leases	$	13	$	—	$	—	$	8	$	5	$	—
Lease income - operating leases	105		39		16		1		42		18
Variable lease income	211		—		—		—		227		—
Total lease income	$	329	$	39	$	16	$	9	$	274	$	18
For the Three Months Ended June 30, 2021
Lease income - interest income on sales-type leases	$	4	$	—	$	—	$	4	$	—	$	—
Lease income - operating leases	56		21		10		—		21		9
Variable lease income	128		(1)		—		—		138		—
Total lease income	$	188	$	20	$	10	$	4	$	159	$	9
For the Six Months Ended June 30, 2021
Lease income - interest income on sales-type leases	$	7	$	—	$	—	$	7	$	—	$	—
Lease income - operating leases	112		41		21		1		42		17
Variable lease income	212		—		—		—		228		—
Total lease income	$	331	$	41	$	21	$	8	$	270	$	17

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Consolidated Entities and Equity Method Investments (Tables)

6 Months Ended

Jun. 30, 2022

Regulated Operations [Abstract]

Schedule of Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at June 30, 2022 and December 31, 2021 and related earnings (loss) from those investments for the three and six months ended June 30, 2022 and 2021 were as follows:

Investment Balance	June 30, 2022		December 31, 2021
	(in millions)
SNG	$	1,099	$	1,129
Other(*)	35		44
Total	$	1,134	$	1,173

(*)Balance at June 30, 2022 reflects a $9 million distribution from PennEast Pipeline.

Schedule of Earnings (Loss) from Equity Method Investments

	Three Months Ended June 30,				Six Months Ended June 30,
Earnings (Loss) from Equity Method Investments	2022		2021		2022		2021
	(in millions)
SNG	$	31	$	28	$	70	$	66
PennEast Pipeline(*)	—		(81)		—		(79)
Other	—		1		1		2
Total	$	31	$	(52)	$	71	$	(11)

(*)Includes a pre-tax impairment charge of $82 million ($58 million after tax) for the three and six months ended June 30, 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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Financing and Leases (Tables)

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

Schedule of Credit Arrangements

At June 30, 2022, committed credit arrangements with banks were as follows:

	Expires
Company	2023		2024		2025		2026		Total		Unused		Expires within One Year
	(in millions)
Southern Company parent	$	—	$	—	$	—	$	2,000	$	2,000	$	1,998	$	—
Alabama Power	—		550		—		700		1,250		1,250		—
Georgia Power	—		—		—		1,750		1,750		1,726		—
Mississippi Power	—		150		125		—		275		275		—
Southern Power(a)	—		—		—		600		600		568		—
Southern Company Gas(b)	250		—		—		1,500		1,750		1,748		250
SEGCO	30		—		—		—		30		30		30
Southern Company	$	280	$	700	$	125	$	6,550	$	7,655	$	7,595	$	280

(a)Does not include Southern Power Company's two $75 million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $11 million and $5 million, respectively, was unused at June 30, 2022. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)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 2026. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $700 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 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. Nicor Gas is also the borrower of a new $250 million credit arrangement expiring in 2023.

Schedule of Shares Used to Compute Diluted Earnings Per Share

Shares used to compute diluted earnings per share were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2022	2021	2022	2021
	(in millions)
As reported shares	1,065	1,061	1,064	1,060
Effect of stock-based compensation	5	6	5	6
Effect of equity units	2	—	1	—
Diluted shares	1,072	1,067	1,070	1,066

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Retirement Benefits (Tables)

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Schedule of Pension Plans and Postretirement Plans

Components of the net periodic benefit costs for the three and six months ended June 30, 2022 and 2021 are presented in the following tables.

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2022
Pension Plans
Service cost	$	103	$	24	$	26	$	4	$	3	$	8
Interest cost	102		24		30		4		1		7
Expected return on plan assets	(317)		(75)		(100)		(14)		(4)		(24)
Amortization:
Prior service costs	—		—		1		—		—		—
Regulatory asset	—		—		—		—		—		4
Net loss	60		15		19		4		—		1
Net periodic pension cost (income)	$	(52)	$	(12)	$	(24)	$	(2)	$	—	$	(4)
Postretirement Benefits
Service cost	$	5	$	2	$	1	$	—	$	—	$	—
Interest cost	11		2		3		1		—		1
Expected return on plan assets	(20)		(8)		(6)		(1)		—		(1)
Amortization:
Regulatory asset	—		—		—		—		—		1
Net loss	—		—		1		—		—		—
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1
Six Months Ended June 30, 2022
Pension Plans
Service cost	$	206	$	49	$	52	$	8	$	5	$	17
Interest cost	204		48		61		9		3		14
Expected return on plan assets	(633)		(152)		(199)		(29)		(8)		(46)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		8
Net loss	120		31		37		7		1		3
Net periodic pension cost (income)	$	(103)	$	(24)	$	(48)	$	(5)	$	1	$	(5)
Postretirement Benefits
Service cost	$	11	$	3	$	3	$	—	$	—	$	1
Interest cost	21		5		7		1		—		2
Expected return on plan assets	(40)		(16)		(13)		(1)		—		(3)
Amortization:
Regulatory asset	—		—		—		—		—		3
Net (gain)/loss	—		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(8)	$	(8)	$	(2)	$	—	$	—	$	2

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended June 30, 2021
Pension Plans
Service cost	$	108	$	25	$	28	$	5	$	3	$	9
Interest cost	86		21		26		4		1		6
Expected return on plan assets	(297)		(71)		(94)		(13)		(4)		(22)
Amortization:
Prior service costs	—		—		1		—		—		—
Regulatory asset	—		—		—		—		—		4
Net loss	79		20		25		3		1		3
Net periodic pension cost (income)	$	(24)	$	(5)	$	(14)	$	(1)	$	1	$	—
Postretirement Benefits
Service cost	$	6	$	2	$	1	$	—	$	—	$	1
Interest cost	9		2		3		1		—		1
Expected return on plan assets	(19)		(7)		(6)		(1)		—		(2)
Amortization:
Prior service costs	(1)		—		—		—		—		—
Regulatory asset	—		—		—		—		—		1
Net loss	1		—		—		—		—		—
Net periodic postretirement benefit cost (income)	$	(4)	$	(3)	$	(2)	$	—	$	—	$	1
Six Months Ended June 30, 2021
Pension Plans
Service cost	$	217	$	51	$	56	$	9	$	5	$	18
Interest cost	173		41		52		8		2		12
Expected return on plan assets	(595)		(143)		(188)		(27)		(7)		(43)
Amortization:
Prior service costs	—		—		1		—		—		(1)
Regulatory asset	—		—		—		—		—		8
Net loss	157		41		50		7		2		6
Net periodic pension cost (income)	$	(48)	$	(10)	$	(29)	$	(3)	$	2	$	—
Postretirement Benefits
Service cost	$	12	$	3	$	3	$	—	$	—	$	1
Interest cost	17		4		6		1		—		2
Expected return on plan assets	(38)		(14)		(13)		(1)		—		(4)
Amortization:
Prior service costs	(1)		—		—		—		—		—
Regulatory asset	—		—		—		—		—		3
Net (gain)/loss	2		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(8)	$	(7)	$	(3)	$	—	$	—	$	1

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Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Schedule of Assets and Liabilities Measured at Fair Value

At June 30, 2022, 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, 2022	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)	$	43	$	408	$	—	$	—	$	451
Investments in trusts:(b)(c)
Domestic equity	643		168		—		—		811
Foreign equity	122		144		—		—		266
U.S. Treasury and government agency securities	—		273		—		—		273
Municipal bonds	—		56		—		—		56
Pooled funds – fixed income	—		9		—		—		9
Corporate bonds	1		445		—		—		446
Mortgage and asset backed securities	—		89		—		—		89
Private equity	—		—		—		164		164
Cash and cash equivalents	3		—		—		—		3
Other	36		17		—		—		53
Cash equivalents	1,058		10		—		—		1,068
Other investments	9		27		—		—		36
Total	$	1,915	$	1,646	$	—	$	164	$	3,725
Liabilities:
Energy-related derivatives(a)	$	16	$	88	$	—	$	—	$	104
Interest rate derivatives	—		214		—		—		214
Foreign currency derivatives	—		228		—		—		228
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	16	$	543	$	14	$	—	$	573

	Fair Value Measurements Using:
At June 30, 2022	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	$	—	$	131	$	—	$	—	$	131
Nuclear decommissioning trusts:(b)
Domestic equity	391		159		—		—		550
Foreign equity	122		—		—		—		122
U.S. Treasury and government agency securities	—		17		—		—		17
Municipal bonds	—		2		—		—		2
Corporate bonds	1		227		—		—		228
Mortgage and asset backed securities	—		20		—		—		20
Private equity	—		—		—		164		164
Other	20		—		—		—		20
Cash equivalents	677		10		—		—		687
Other investments	—		27		—		—		27
Total	$	1,211	$	593	$	—	$	164	$	1,968
Liabilities:
Energy-related derivatives	$	—	$	23	$	—	$	—	$	23
Georgia Power
Assets:
Energy-related derivatives	$	—	$	137	$	—	$	—	$	137
Nuclear decommissioning trusts:(b)(c)
Domestic equity	252		1		—		—		253
Foreign equity	—		142		—		—		142
U.S. Treasury and government agency securities	—		256		—		—		256
Municipal bonds	—		54		—		—		54
Corporate bonds	—		218		—		—		218
Mortgage and asset backed securities	—		69		—		—		69
Other	16		17		—		—		33
Cash equivalents	98		—		—		—		98
Total	$	366	$	894	$	—	$	—	$	1,260
Liabilities:
Energy-related derivatives	$	—	$	29	$	—	$	—	$	29

	Fair Value Measurements Using:
At June 30, 2022	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	$	—	$	121	$	—	$	—	$	121
Liabilities:
Energy-related derivatives	$	—	$	14	$	—	$	—	$	14
Southern Power
Assets:
Energy-related derivatives	$	—	$	6	$	—	$	—	$	6
Liabilities:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1
Foreign currency derivatives	—		45		—		—		45
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	—	$	59	$	14	$	—	$	73
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	43	$	13	$	—	$	—	$	56
Non-qualified deferred compensation trusts:
Domestic equity	—		8		—		—		8
Foreign equity	—		2		—		—		2
Pooled funds – fixed income	—		9		—		—		9
Cash equivalents	3		—		—		—		3
Cash equivalents and restricted cash	192		—		—		—		192
Total	$	238	$	32	$	—	$	—	$	270
Liabilities:
Energy-related derivatives(a)	$	16	$	20	$	—	$	—	$	36
Interest rate derivatives	—		62		—		—		62
Total	$	16	$	82	$	—	$	—	$	98

(a)Excludes cash collateral of $13 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 in Item 8 of the Form 10-K for additional information.

(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. At June 30, 2022, approximately $65 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

Schedule of Increase (Decrease) In Fair Value Of 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 the three and six months ended June 30, 2022 and 2021. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

Fair value increases (decreases)	Three Months Ended June 30, 2022		Three Months Ended June 30, 2021		Six Months Ended June 30, 2022		Six Months Ended June 30, 2021
	(in millions)
Southern Company	$	(230)	$	125	$	(380)	$	164
Alabama Power	(125)		77		(192)		118
Georgia Power	(105)		48		(188)		46

Schedule of Financial Instruments for which Carrying Amount Did Not Equal Fair Value

At June 30, 2022, 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	$	52.0	$	9.8	$	14.6	$	1.5	$	3.0	$	6.8
Fair value	48.0		9.0		13.7		1.3		2.9		6.2

(*)The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at 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.

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Derivatives (Tables)

6 Months Ended

Jun. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Energy-Related Derivatives

At June 30, 2022, 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(*)	273	2030	2025
Alabama Power	65	2026	—
Georgia Power	75	2025	—
Mississippi Power	71	2026	—
Southern Power	4	2030	—
Southern Company Gas(*)	58	2024	2025

(*)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 long natural gas positions of 64.4 million mmBtu and short natural gas positions of 6.4 million mmBtu at June 30, 2022, which is also included in Southern Company's total volume.

Schedule of Interest Rate Derivatives

At June 30, 2022, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at June 30, 2022
	(in millions)					(in millions)
Cash Flow Hedges of Existing Debt
Alabama Power	$	50	—	3.18%	August 2027	$	—
Southern Company Gas	250		—	3.26%	August 2032	(5)
Fair Value Hedges of Existing Debt
Southern Company parent	400		1.75%	1-month LIBOR + 0.68%	March 2028	(39)
Southern Company parent	1,000		3.70%	1-month LIBOR + 2.36%	April 2030	(113)
Southern Company Gas	500		1.75%	1-month LIBOR + 0.38%	January 2031	(57)
Southern Company	$	2,200				$	(214)

Schedule of Foreign Currency Derivatives

At June 30, 2022, 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, 2022
	(in millions)			(in millions)				(in millions)
Fair Value Hedges of Existing Debt
Southern Company parent	$	1,476	3.39%	€	1,250	1.88%	September 2027	$	(183)
Cash Flow Hedges of Existing Debt
Southern Power	564		3.78%	500		1.85%	June 2026	(45)
Southern Company	$	2,040		€	1,750			$	(228)

Schedule of Derivative Category and Balance Sheet Location

The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	267	$	49	$	129	$	30
Other deferred charges and assets/Other deferred credits and liabilities	144		37		72		6
Total derivatives designated as hedging instruments for regulatory purposes	$	411	$	86	$	201	$	36
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	17	$	5	$	7	$	5
Other deferred charges and assets/Other deferred credits and liabilities	6		—		1		—
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	—		19		19		—
Other deferred charges and assets/Other deferred credits and liabilities	—		195		—		29
Foreign currency derivatives:
Assets from risk management activities/Other current liabilities	—		36		—		39
Other deferred charges and assets/Other deferred credits and liabilities	—		192		—		40
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	23	$	447	$	27	$	113
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	15	$	12	$	9	$	4
Other deferred charges and assets/Other deferred credits and liabilities	2		1		1		—
Total derivatives not designated as hedging instruments	$	17	$	13	$	10	$	4
Gross amounts recognized	$	451	$	546	$	238	$	153
Gross amounts offset(a)	(87)		(74)		(25)		(28)
Net amounts recognized in the Balance Sheets(b)	$	364	$	472	$	213	$	125

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	76	$	6	$	30	$	9
Other deferred charges and assets/Other deferred credits and liabilities	55		17		25		2
Total derivatives designated as hedging instruments for regulatory purposes	$	131	$	23	$	55	$	11
Gross amounts offset	(20)		(20)		(5)		(5)
Net amounts recognized in the Balance Sheets	$	111	$	3	$	50	$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	102	$	15	$	54	$	6
Other deferred charges and assets/Other deferred credits and liabilities	35		14		21		2
Total derivatives designated as hedging instruments for regulatory purposes	$	137	$	29	$	75	$	8
Gross amounts offset	(21)		(21)		(8)		(8)
Net amounts recognized in the Balance Sheets	$	116	$	8	$	67	$	—
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	67	$	8	$	30	$	3
Other deferred charges and assets/Other deferred credits and liabilities	54		6		26		2
Total derivatives designated as hedging instruments for regulatory purposes	$	121	$	14	$	56	$	5
Gross amounts offset	(11)		(11)		(4)		(4)
Net amounts recognized in the Balance Sheets	$	110	$	3	$	52	$	1

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	—	$	—	$	2	$	—
Other deferred charges and assets/Other deferred credits and liabilities	4		—		1		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		11		—		16
Other deferred charges and assets/Other deferred credits and liabilities	—		34		—		—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	4	$	45	$	3	$	16
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	1	$	1	$	1	$	—
Other deferred charges and assets/Other deferred credits and liabilities	1		—		—		—
Total derivatives not designated as hedging instruments	$	2	$	1	$	1	$	—
Gross amounts recognized	$	6	$	46	$	4	$	16
Gross amounts offset	(1)		(1)		—		—
Net amounts recognized in the Balance Sheets	$	5	$	45	$	4	$	16

	At June 30, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	23	$	19	$	15	$	12
Total derivatives designated as hedging instruments for regulatory purposes	$	23	$	19	$	15	$	12
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	17	$	5	$	5	$	5
Other deferred charges and assets/Other deferred credits and liabilities	2		—		—		—
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	—		—		6		—
Other deferred charges and assets/Other deferred credits and liabilities	—		62		—		6
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	19	$	67	$	11	$	11
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	13	$	11	$	8	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		1		1		—
Total derivatives not designated as hedging instruments	$	14	$	12	$	9	$	4
Gross amounts recognized	$	56	$	98	$	35	$	27
Gross amounts offset(a)	(34)		(21)		(8)		(11)
Net amounts recognized in the Balance Sheets(b)	$	22	$	77	$	27	$	16

(a)Gross amounts offset include cash collateral held on deposit in broker margin accounts of $13 million and $3 million at June 30, 2022 and December 31, 2021, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives at December 31, 2021. There were no such amounts at June 30, 2022.

Schedule of Pre-tax Effects of Unrealized Derivative Gains (Losses)

At June 30, 2022 and December 31, 2021, 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, 2022:
Energy-related derivatives:
Other regulatory assets, current	$	(26)	$	(2)	$	(6)	$	(3)	$	(15)
Other regulatory assets, deferred	(3)		(1)		(1)		(1)		—
Other regulatory liabilities, current	234		72		93		62		7
Other regulatory liabilities, deferred	110		39		22		49		—
Total energy-related derivative gains (losses)	$	315	$	108	$	108	$	107	$	(8)
At December 31, 2021:
Energy-related derivatives:
Other regulatory assets, current	$	(17)	$	(6)	$	—	$	—	$	(11)
Other regulatory liabilities, current	107		28		48		27		4
Other regulatory liabilities, deferred	65		22		19		24		—
Total energy-related derivative gains (losses)	$	155	$	44	$	67	$	51	$	(7)

Schedule of Pre-Tax Effects of Hedging on AOCI

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	(1)	$	16	$	41	$	20
Interest rate derivatives	21		(1)		30		2
Foreign currency derivatives	(74)		4		(102)		(43)
Fair value hedges(*):
Foreign currency derivatives	(7)		—		(3)		—
Total	$	(61)	$	19	$	(34)	$	(21)
Georgia Power
Interest rate derivatives	$	19	$	—	$	31	$	—
Southern Power
Cash flow hedges:
Energy-related derivatives	$	2	$	5	$	7	$	8
Foreign currency derivatives	(74)		4		(102)		(43)
Total	$	(72)	$	9	$	(95)	$	(35)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	(2)	$	11	$	35	$	12
Interest rate derivatives	(5)		—		(5)		—
Total	$	(7)	$	11	$	30	$	12

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

Schedule of Pre-Tax Effects of Cash Flow and Fair Value Hedging on Income

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows:

Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships	For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2022		2021		2022		2021
	(in millions)				(in millions)
Southern Company
Total cost of natural gas	$	452	$	231	$	1,546	$	814
Gain (loss) on energy-related cash flow hedges(a)	10		1		18		(2)
Total depreciation and amortization	913		891		1,805		1,762
Gain (loss) on energy-related cash flow hedges(a)	4		1		6		4
Total interest expense, net of amounts capitalized	(488)		(450)		(950)		(901)
Gain (loss) on interest rate cash flow hedges(a)	(6)		(7)		(13)		(14)
Gain (loss) on foreign currency cash flow hedges(a)	(7)		(6)		(13)		(12)
Gain (loss) on interest rate fair value hedges(b)	(76)		(3)		(198)		(12)
Total other income (expense), net	139		101		283		160
Gain (loss) on foreign currency cash flow hedges(a)(c)	(73)		17		(97)		(43)
Gain (loss) on foreign currency fair value hedges	(96)		—		(121)		—
Amount excluded from effectiveness testing recognized in earnings	7		—		3		—
Southern Power
Total depreciation and amortization	$	131	$	132	$	251	$	251
Gain (loss) on energy-related cash flow hedges(a)	4		1		6		4
Total interest expense, net of amounts capitalized	(36)		(37)		(73)		(75)
Gain (loss) on foreign currency cash flow hedges(a)	(7)		(6)		(13)		(12)
Total other income (expense), net	1		1		3		8
Gain (loss) on foreign currency cash flow hedges(a)(c)	(73)		17		(97)		(43)
Southern Company Gas
Total cost of natural gas	$	452	$	231	$	1,546	$	814
Gain (loss) on energy-related cash flow hedges(a)	10		—		18		(2)
Total interest expense, net of amounts capitalized	(61)		(59)		(122)		(118)
Gain (loss) on interest rate cash flow hedges(a)	(1)		(1)		(1)		(1)
Gain (loss) on interest rate fair value hedges(b)	(22)		4		(57)		4

(a)Reclassified from accumulated OCI into earnings.

(b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income.

(c)The reclassification from accumulated OCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes.

Schedule of Cumulative Basis Adjustments for Fair Value Hedges

At June 30, 2022 and December 31, 2021, 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, 2022		At December 31, 2021		At June 30, 2022		At December 31, 2021
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(2,981)	$	(3,280)	$	192	$	9
Southern Company Gas
Long-term debt	$	(437)	$	(493)	$	59	$	2

Schedule of Pre-tax Effect of Interest Rate and Energy Related Derivatives on Income

For the three and six months ended June 30, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas were as follows:

		Gain (Loss)
		Three Months Ended June 30,				Six Months Ended June 30,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location	2022		2021		2022		2021
		(in millions)				(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	(15)	$	(103)	$	(13)	$	(120)
	Cost of natural gas	(25)		9		(5)		16
Total derivatives in non-designated hedging relationships		$	(40)	$	(94)	$	(18)	$	(104)

(*)Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.

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Acquisitions and Dispositions (Tables)

6 Months Ended

Jun. 30, 2022

Business Combination and Asset Acquisition [Abstract]

Schedule of Construction Projects

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	COD	PPA Contract Period
Projects Completed During the Six Months Ended June 30, 2022
Garland Solar Storage(a)	Battery energy storage system	88	Kern County, CA	September 2021 through February 2022(b)	20 years
Tranquillity Solar Storage(a)	Battery energy storage system	72	Fresno County, CA	November 2021 through March 2022(c)	20 years

(a)Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest.

(b)The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in February 2022.

(c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in March 2022.

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Segment and Related Information (Tables)

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Schedule of Financial Data for Business Segments

Financial data for business segments and products and services for the three and six months ended June 30, 2022 and 2021 was as follows:

	Electric Utilities
	Traditional Electric Operating Companies		Southern Power		Eliminations		Total		Southern Company Gas		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended June 30, 2022
Operating revenues	$	5,563	$	899	$	(456)	$	6,006	$	1,083	$	159	$	(42)	$	7,206
Segment net income (loss)(a)(b)	1,036		98		—		1,134		115		(137)		(5)		1,107
Six Months Ended June 30, 2022
Operating revenues	$	9,778	$	1,438	$	(700)	$	10,516	$	3,140	$	283	$	(85)	$	13,854
Segment net income (loss)(a)(b)	1,811		170		—		1,981		433		(263)		(12)		2,139
At June 30, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	92,742		13,402		(787)		105,357		23,618		2,457		(663)		130,769
Three Months Ended June 30, 2021
Operating revenues	$	4,031	$	490	$	(114)	$	4,407	$	677	$	154	$	(40)	$	5,198
Segment net income (loss)(a)(b)(c)	511		36		—		547		(65)		(108)		(2)		372
Six Months Ended June 30, 2021
Operating revenues	$	7,795	$	930	$	(201)	$	8,524	$	2,371	$	288	$	(75)	$	11,108
Segment net income (loss)(a)(b)(c)(d)	1,267		133		—		1,400		333		(216)		(9)		1,508
At December 31, 2021
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	89,051		13,390		(667)		101,774		23,560		2,975		(775)		127,534

(a)Attributable to Southern Company.

(b)For the traditional electric operating companies, includes pre-tax charges at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4 of $52 million ($39 million after tax) for the three and six months ended June 30, 2022 and $460 million ($343 million after tax) and $508 million ($379 million after tax) for the three and six months ended June 30, 2021, respectively. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

(c)For Southern Company Gas, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to its equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

(d)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Business segment financial data for the three and six months ended June 30, 2022 and 2021 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Wholesale Gas Services(a)		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended June 30, 2022
Operating revenues	$	980	$	8	$	—	$	92	$	1,080	$	10	$	(7)	$	1,083
Segment net income (loss)	92		23		—		1		116		(1)		—		115
Six Months Ended June 30, 2022
Operating revenues	$	2,782	$	16	$	—	$	335	$	3,133	$	26	$	(19)	$	3,140
Segment net income (loss)	306		52		—		67		425		8		—		433
Total assets at June 30, 2022	21,183		1,433		—		1,554		24,170		11,999		(12,551)		23,618
Three Months Ended June 30, 2021
Operating revenues	$	710	$	8	$	(110)	$	64	$	672	$	11	$	(6)	$	677
Segment net income (loss)(b)	80		(36)		(112)		6		(62)		(3)		—		(65)
Six Months Ended June 30, 2021
Operating revenues	$	1,910	$	16	$	188	$	259	$	2,373	$	18	$	(20)	$	2,371
Segment net income (loss)(b)	263		(7)		14		62		332		1		—		333
Total assets at December 31, 2021	20,917		1,467		31		1,556		23,971		12,114		(12,525)		23,560

(a)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three and six months ended June 30, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended June 30, 2021	$	1,292	$	27	$	1,319	$	1,429	$	(110)
Six Months Ended June 30, 2021	3,881		90		3,971		3,783		188

(b)For gas pipeline investments, includes a pre-tax impairment charge of $82 million ($58 million after tax) related to the equity method investment in the PennEast Pipeline project. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Schedule of Financial Data for Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended June 30, 2022	$	4,789	$	937	$	280	$	6,006
Three Months Ended June 30, 2021	3,599		546		262		4,407
Six Months Ended June 30, 2022	$	8,402	$	1,601	$	513	$	10,516
Six Months Ended June 30, 2021	6,941		1,091		492		8,524

	Southern Company Gas' Revenues
	Gas Distribution Operations		Wholesale Gas Services(*)		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended June 30, 2022	$	975	$	—	$	92	$	16	$	1,083
Three Months Ended June 30, 2021	706		(110)		64		17		677
Six Months Ended June 30, 2022	$	2,765	$	—	$	335	$	40	$	3,140
Six Months Ended June 30, 2021	1,898		188		259		26		2,371

(*)Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. See "Southern Company Gas" herein and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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Introduction - Schedule of Goodwill (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Goodwill [Line Items]
Goodwill	$ 5,280	$ 5,280
SOUTHERN Co GAS
Goodwill [Line Items]
Goodwill	5,015	5,015
SOUTHERN Co GAS | Gas distribution operations
Goodwill [Line Items]
Goodwill	4,034	4,034
SOUTHERN Co GAS | Gas marketing services
Goodwill [Line Items]
Goodwill	$ 981	$ 981

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Introduction - Schedule of Other Intangible Assets (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Other intangible assets subject to amortization:
Gross Carrying Amount	$ 676	$ 677
Accumulated Amortization	(326)	(307)
Other Intangible Assets, Net	350	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75	75
Total other intangible assets
Gross Carrying Amount	751	752
Accumulated Amortization	(326)	(307)
Other Intangible Assets, Net	425	445
Customer relationships
Other intangible assets subject to amortization:
Gross Carrying Amount	212	212
Accumulated Amortization	(157)	(150)
Other Intangible Assets, Net	55	62
Total other intangible assets
Accumulated Amortization	(157)	(150)
Trade names
Other intangible assets subject to amortization:
Gross Carrying Amount	64	64
Accumulated Amortization	(41)	(38)
Other Intangible Assets, Net	23	26
Total other intangible assets
Accumulated Amortization	(41)	(38)
PPA fair value adjustments
Other intangible assets subject to amortization:
Gross Carrying Amount	390	390
Accumulated Amortization	(119)	(109)
Other Intangible Assets, Net	271	281
Total other intangible assets
Accumulated Amortization	(119)	(109)
Other
Other intangible assets subject to amortization:
Gross Carrying Amount	10	11
Accumulated Amortization	(9)	(10)
Other Intangible Assets, Net	1	1
Total other intangible assets
Accumulated Amortization	(9)	(10)
SOUTHERN POWER CO
Other intangible assets subject to amortization:
Accumulated Amortization	(119)	(109)
Total other intangible assets
Accumulated Amortization	(119)	(109)
SOUTHERN POWER CO | PPA fair value adjustments
Other intangible assets subject to amortization:
Gross Carrying Amount	390	390
Accumulated Amortization	(119)	(109)
Other Intangible Assets, Net	271	281
Total other intangible assets
Accumulated Amortization	(119)	(109)
SOUTHERN Co GAS
Other intangible assets subject to amortization:
Gross Carrying Amount	182	182
Accumulated Amortization	(151)	(145)
Other Intangible Assets, Net	31	37
Total other intangible assets
Accumulated Amortization	(151)	(145)
Other Intangible Assets, Net	31	37
SOUTHERN Co GAS | Customer relationships
Other intangible assets subject to amortization:
Gross Carrying Amount	156	156
Accumulated Amortization	(135)	(130)
Other Intangible Assets, Net	21	26
Total other intangible assets
Accumulated Amortization	(135)	(130)
SOUTHERN Co GAS | Trade names
Other intangible assets subject to amortization:
Gross Carrying Amount	26	26
Accumulated Amortization	(16)	(15)
Other Intangible Assets, Net	10	11
Total other intangible assets
Accumulated Amortization	$ (16)	$ (15)

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Introduction - Schedule of Amortization of Other Intangible Assets (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2022
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 9	$ 19
Decrease in operating revenues	5	10
SOUTHERN POWER CO
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	5	10
SOUTHERN Co GAS
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 2	$ 5

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Introduction - Schedule of Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2021	Dec. 31, 2020
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	$ 1,724	$ 1,798
Restricted cash:
Total cash, cash equivalents, and restricted cash	1,735	1,829	$ 1,617	$ 1,068
Other current assets
Restricted cash:
Restricted cash	2	2
Other deferred charges and assets
Restricted cash:
Restricted cash	9	29
SOUTHERN POWER CO
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	202	107
Restricted cash:
Total cash, cash equivalents, and restricted cash	211	135	189	183
SOUTHERN POWER CO | Other current assets
Restricted cash:
Restricted cash	0	0
SOUTHERN POWER CO | Other deferred charges and assets
Restricted cash:
Restricted cash	9	29
SOUTHERN POWER CO | Tax Equity Contributions | Garland
Restricted cash:
Restricted cash		19
SOUTHERN POWER CO | Estimated Construction Completion Costs | Deuel Harvest
Restricted cash:
Restricted cash	9	10
SOUTHERN Co GAS
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	217	45
Restricted cash:
Total cash, cash equivalents, and restricted cash	218	48	$ 48	$ 19
SOUTHERN Co GAS | Other current assets
Restricted cash:
Restricted cash	2	2
SOUTHERN Co GAS | Other deferred charges and assets
Restricted cash:
Restricted cash	$ 0	$ 0

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Introduction - Depreciation and Amortization (Details)		12 Months Ended
	Jan. 01, 2022	Dec. 31, 2021
Maximum | Wind Generating Facility | SOUTHERN POWER CO
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	35 years	30 years

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Regulatory Matters - Schedule of Cost Recovery Clauses (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Loss Contingencies [Line Items]
Natural gas cost under recovery	$ 361	$ 266
ALABAMA POWER CO | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Rate CNP Compliance	29	16
Rate CNP PPA	93	84
Retail Energy Cost Recovery	191	126
ALABAMA POWER CO | Other regulatory assets, current
Loss Contingencies [Line Items]
Retail Energy Cost Recovery	60	0
GEORGIA POWER CO | Other deferred charges and assets
Loss Contingencies [Line Items]
Fuel Cost Recovery	948	410
MISSISSIPPI POWER CO | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Ad Valorem Tax	29	37
MISSISSIPPI POWER CO | Other customer accounts receivable
Loss Contingencies [Line Items]
Fuel Cost Recovery	29	4
MISSISSIPPI POWER CO | Other regulatory assets, current
Loss Contingencies [Line Items]
Ad Valorem Tax	12	12
SOUTHERN Co GAS
Loss Contingencies [Line Items]
Natural gas cost under recovery	361	266
SOUTHERN Co GAS | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Natural gas cost under recovery	15	207
SOUTHERN Co GAS | Other regulatory assets, current
Loss Contingencies [Line Items]
Natural gas cost under recovery	$ 361	$ 266

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Regulatory Matters - APC Rate ECR (Details) - Alabama Power $ in Millions			1 Months Ended
	Jul. 12, 2022 USD ($) $ / KWH_Kilowatt_hour	Jul. 11, 2022 $ / KWH_Kilowatt_hour	Jan. 31, 2025 $ / KWH_Kilowatt_hour
Subsequent Event
Schedule of Regulatory Assets and Liabilities [Line Items]
Current billing rates under rate ECR (usd per KWH)	2.557	1.96
Current billing rates under rate ECR, amount | $	$ 310
Scenario, Forecast
Schedule of Regulatory Assets and Liabilities [Line Items]
Current billing rates under rate ECR (usd per KWH)			5.91

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Regulatory Matters - APC Rate NDR and Reliability Reserve Accounting Order (Details) - Alabama Power - USD ($)		6 Months Ended	12 Months Ended
	Jul. 12, 2022	Dec. 31, 2022	Dec. 31, 2023	Jun. 30, 2022
Public Utilities, General Disclosures [Line Items]
Natural disaster reserve balance				$ 103,000,000
Natural disaster reserve authorized limit				75,000,000
Minimum natural disaster reserve balance, triggering establishment charge				$ 50,000,000
Subsequent Event
Public Utilities, General Disclosures [Line Items]
Maximum rate NDR charge per month, monthly nonresidential customer account	$ 5.00
Maximum rate NDR charge per month, monthly residential customer account	2.50
Natural disaster reserve authorized limit	$ 35,000,000
Minimum | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Maximum period for recovery deferred stock related operations and maintenance costs and any future reserve deficits	24 months
Maximum | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Maximum period for recovery deferred stock related operations and maintenance costs and any future reserve deficits	48 months
Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Natural disaster reserve, expected recovery amount		$ 6,000,000	$ 12,000,000

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Regulatory Matters - APC Renewable Generation Certificate (Details) - ALABAMA POWER CO	1 Months Ended
	Apr. 30, 2022 project MW	Jun. 30, 2022 MW
Public Utilities, General Disclosures [Line Items]
Renewable generation certificate, authorized generating capacity (in MWs)		500
Renewable generation certificate, number of projects terminated | project	1
Renewable generation certificate, capacity restored (in MWs)	80

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Regulatory Matters - GPC Base Rate Case (Details) $ in Millions	Jun. 24, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Proposed alternate rate plan	3 years
GEORGIA POWER CO
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount, due in next fiscal year	$ 852
Requested rate increase (decrease), amount, due in 2024	107
Requested rate increase (decrease), amount, due in 2025	$ 45
Base rate case filing, measurement input, return on investment	11.00%
Base rate case filing, measurement input, maximum equity ratio	56.00%
Portion of actual earnings above approved ROE band refunded to customers	80.00%
Portion of actual earnings above approved ROE band retained by subsidiary company	20.00%
GEORGIA POWER CO | Minimum
Public Utilities, General Disclosures [Line Items]
Retail rate of return on common equity	9.50%
GEORGIA POWER CO | Maximum
Public Utilities, General Disclosures [Line Items]
Retail rate of return on common equity	12.00%

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Regulatory Matters - GPC Tariffs (Details) - GEORGIA POWER CO $ in Millions	Jun. 24, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount, due in next fiscal year	$ 852
Requested rate increase (decrease), amount, due in 2024	107
Requested rate increase (decrease), amount, due in 2025	45
Traditional base
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount, due in next fiscal year	739
Requested rate increase (decrease), amount, due in 2024	0
Requested rate increase (decrease), amount, due in 2025	0
Traditional
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount, due in next fiscal year	(1)
Requested rate increase (decrease), amount, due in 2024	0
Requested rate increase (decrease), amount, due in 2025	0
CCR ARO
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount, due in next fiscal year	64
Requested rate increase (decrease), amount, due in 2024	78
Requested rate increase (decrease), amount, due in 2025	47
DSM
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount, due in next fiscal year	30
Requested rate increase (decrease), amount, due in 2024	27
Requested rate increase (decrease), amount, due in 2025	(2)
Municipal Franchise Fee
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease), amount, due in next fiscal year	20
Requested rate increase (decrease), amount, due in 2024	2
Requested rate increase (decrease), amount, due in 2025	$ 1

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Regulatory Matters - GPC Integrated Resource Plan (Details) - GEORGIA POWER CO $ in Millions					6 Months Ended	12 Months Ended
	Jan. 01, 2028 MW	Jan. 01, 2025 MW	Jan. 01, 2024 MW	Jul. 21, 2022 agreement ashPond MW	Jun. 30, 2022 USD ($) MW	Dec. 31, 2026 MW
Public Utilities, General Disclosures [Line Items]
Approved capacity increase (in MWs)					970
Subsequent Event
Public Utilities, General Disclosures [Line Items]
Approved change in closure method, number of ash ponds | ashPond				1
Number of approved Power Purchase Agreements | agreement				6
Number of approved Approved Power Purchase Agreements | agreement				5
Subsequent Event | Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Approved capacity increase (in MWs)	228	380	1,567			265
Rejected additional generating capacity				88
Subsequent Event | Scenario, Forecast | Renewable Resources
Public Utilities, General Disclosures [Line Items]
Requested additional generating capacity				2,300
Subsequent Event | Scenario, Forecast | Energy Storage
Public Utilities, General Disclosures [Line Items]
Requested additional generating capacity				500
Subsequent Event | Scenario, Forecast | Biomass Generation
Public Utilities, General Disclosures [Line Items]
Requested additional generating capacity				140
Plant Wansley Units 1 and 2 | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Capacity of units approved for decertification and retirement of units				926
Approved amounts for decertification and retirement of units, percentage				53.50%
Plant Wansley Unit 1
Public Utilities, General Disclosures [Line Items]
Remaining net book value | $					$ 302
Plant Wansley Unit 2
Public Utilities, General Disclosures [Line Items]
Remaining net book value | $					279
Plant Scherer Unit 3
Public Utilities, General Disclosures [Line Items]
Remaining net book value | $					$ 614
Plant Scherer Unit 3 | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Capacity of units approved for decertification and retirement of units				614
Approved amounts for decertification and retirement of units, percentage				75.00%
Plant Gaston Units 1 through 4 | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Capacity of units approved for decertification and retirement of units				500
Approved amounts for decertification and retirement of units, percentage				50.00%
Plant Bowen Units 1 and 2 | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Capacity of units included in request for decertification of units				1,400

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Regulatory Matters - GPC Nuclear Construction (Details) - GEORGIA POWER CO $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2012 utility MW	Aug. 31, 2018
Loss Contingencies [Line Items]
Estimated cost to complete, pre-tax charge to income	$ 36
Estimated cost to complete, pre-tax charge to income, net of tax	$ 27
Plant Vogtle Units 3 And 4
Loss Contingencies [Line Items]
Proportionate ownership share	45.70%	45.70%
Number of construction units approved | utility			2
Electric generating capacity in mega watts under consortium agreement | MW			1,100
Estimated cost to complete, construction contingency estimate, financing costs	$ 3,400	$ 3,400
Estimated cost to complete, construction contingency estimate, financing costs, incurred to date	3,000	3,000
Construction contingency estimate	126	126
Estimated cost to complete, additional construction contingency estimate	36	36
Base project capital cost forecast, monthly		35
Monthly AFUDC		$ 45
Percentage of ownership interest required for voting for continuing construction				90.00%
Plant Vogtle Units 3 And 4 | Vogtle Owners
Loss Contingencies [Line Items]
Period of notice required in the event letters of credit are not renewed		30 days
Minimum | Plant Vogtle Units 3 And 4 | COVID-19
Loss Contingencies [Line Items]
Loss contingency, estimate of possible loss, loss of productivity, term		3 months
Estimate of possible loss	160	$ 160
Maximum | Plant Vogtle Units 3 And 4 | COVID-19
Loss Contingencies [Line Items]
Loss contingency, estimate of possible loss, loss of productivity, term		4 months
Estimate of possible loss	$ 200	$ 200

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Regulatory Matters - GPC Nuclear Construction Cost and Schedule (Details) - GEORGIA POWER CO - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2022	Jun. 30, 2021
Loss Contingencies [Line Items]
Pre-tax charge to income	$ 16	$ 440	$ 455
Plant Vogtle Units 3 And 4
Loss Contingencies [Line Items]
Base project capital cost forecast	10,393		10,393
Construction contingency estimate	60		60
Total project capital cost forecast	10,453		10,453
Net investment as of end of the period	(8,966)		(8,966)
Remaining estimate to complete	1,487		1,487
Estimated cost to complete, costs not shared with other owners	590		590
Expected capitalized costs			385
Capitalized interest accrued	$ 247		$ 247
Plant Vogtle Units 3 And 4 | Twenty Fifth Vogtle Construction Monitoring Report
Loss Contingencies [Line Items]
Guarantor obligations				$ 1,700
Customer refund				$ 188

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Regulatory Matters - GPC Amendments to the Vogtle Joint Ownership Agreements (Details) - GEORGIA POWER CO - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
	Jan. 11, 2018	Jun. 30, 2022	Dec. 31, 2021	Jun. 30, 2022	Jul. 25, 2022	Jun. 18, 2022	Aug. 31, 2018
Public Utilities, General Disclosures [Line Items]
Pre-tax charge to income		$ 16,000	$ 440,000	$ 455,000
After tax charge to income		12,000	$ 328,000
Plant Vogtle Units 3 And 4
Public Utilities, General Disclosures [Line Items]
Production tax credits, aggregate purchase price, maximum				300,000
Preliminary estimated cost to complete		$ 10,453,000		10,453,000
Additional construction capital costs	$ 3,300,000			$ 480,000
Remaining share of construction costs, agreement to pay, percentage				100.00%
Percentage of ownership interest required for voting for continuing construction							90.00%
Percentage of costs, disallowed for recovery				6.00%
Costs disallowed for recovery, period				6 months
Public utilities, extension project schedule, term				1 year
Proportionate ownership share		45.70%		45.70%
Plant Vogtle Units 3 And 4 | Vogtle Owners
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs				$ 100
Plant Vogtle Units 3 And 4 | Vogtle Owners | Tender Provision Dispute
Public Utilities, General Disclosures [Line Items]
Estimated cost to complete, starting dollar amount						$ 17,100,000
Plant Vogtle Units 3 And 4 | Vogtle Owners | Counterclaim Seeking Declaratory Judgement | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Estimated cost to complete, starting dollar amount					$ 18,380,000
Plant Vogtle Units 3 And 4 | Minimum
Public Utilities, General Disclosures [Line Items]
Global amendments, tender provision, decision period after tender option triggered				120 days
Plant Vogtle Units 3 And 4 | Maximum
Public Utilities, General Disclosures [Line Items]
Global amendments, tender provision, decision period after tender option triggered				194 days
Plant Vogtle Units 3 And 4 | Category I
Public Utilities, General Disclosures [Line Items]
Preliminary estimated cost to complete		$ 8,400,000		$ 8,400,000
Additional construction capital costs, threshold				$ 800,000
Plant Vogtle Units 3 And 4 | Category II
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay				55.70%
Additional construction capital costs				$ 80,000
Plant Vogtle Units 3 And 4 | Category II | Vogtle Owners
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay				44.30%
Plant Vogtle Units 3 And 4 | Category II | Minimum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold				$ 800,000
Plant Vogtle Units 3 And 4 | Category II | Maximum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold				$ 1,600,000
Plant Vogtle Units 3 And 4 | Category III
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay				65.70%
Additional construction capital costs				$ 100,000
Plant Vogtle Units 3 And 4 | Category III | Vogtle Owners
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay				34.30%
Plant Vogtle Units 3 And 4 | Category III | Minimum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold				$ 1,600,000
Plant Vogtle Units 3 And 4 | Category III | Maximum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold				$ 2,100,000

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Regulatory Matters - GPC Nuclear Construction Regulatory Matters (Details) - Plant Vogtle Units 3 And 4 - GEORGIA POWER CO $ in Millions						6 Months Ended		12 Months Ended
	Jan. 01, 2022 USD ($)	Jan. 01, 2021	Jan. 01, 2020	Jan. 11, 2018 USD ($)	Jan. 01, 2016	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($) report	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2009 USD ($)	Jun. 30, 2018 USD ($)	Dec. 31, 2013
Public Utilities, General Disclosures [Line Items]
Estimated in-service capital cost											$ 4,418
Financing costs collected, net of tax						$ 2,800
Requested decrease in tariff	$ 78
Additional construction capital costs				$ 3,300		$ 480
Payments for contractor settlement agreement				300
Amendment to estimated in-service capital cost				$ 5,680
Retail rate of return on common equity													10.95%
Public utilities, approved return on equity percentage		5.30%	8.30%		10.00%
Public utilities, approved return on equity, monthly percentage decrease						0.10%
Return on equity reduction, negative impact on earnings										$ 270
Increase to base capital cost forecast not seeking recovery												$ 700
Twenty Fourth Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Cost settlement agreement revised forecast, net of payments						$ 7,300	$ 7,300
Twenty Fifth Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Number of approved construction management reports | report							25
Requested capital construction costs							$ 7,900
Guarantor obligations							1,700
Customer refund							$ 188
Twenty Sixth Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Requested capital construction costs										$ 584
Twenty Seventh Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Requested capital construction costs						$ 522
Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Return on equity reduction, negative impact on earnings								$ 250	$ 300

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Regulatory Matters - MPC (Details) - MISSISSIPPI POWER CO $ in Millions	Jul. 15, 2022 USD ($)	Jun. 07, 2022 USD ($)	Jun. 30, 2022 MW	May 26, 2022
Performance Evaluation Plan
Loss Contingencies [Line Items]
Approved rate increase (decrease)		$ 18
Approved rate increase, percentage		1.90%
Ad Valorem Tax Adjustment
Loss Contingencies [Line Items]
Approved rate increase (decrease)		$ 5
Subsequent Event | Municipal and Rural Associations Tariff
Loss Contingencies [Line Items]
Requested rate increase (decrease) amount	$ 23
Cooperative Energy
Loss Contingencies [Line Items]
Counterparty's option to decrease services, percentage				2.50%
Counterparty's electricity requirement at MRA delivery points				100.00%
Power being supplied to counterparty | MW			400

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Regulatory Matters - GAS Schedule of Infrastructure Replacement Programs and Capital Projects (Details) - SOUTHERN Co GAS $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Capital expenditures	$ 240
Investing in Illinois
Public Utilities, General Disclosures [Line Items]
Capital expenditures	177
Steps to Advance Virginia's Energy
Public Utilities, General Disclosures [Line Items]
Capital expenditures	33
System Reinforcement Rider
Public Utilities, General Disclosures [Line Items]
Capital expenditures	28
Pipeline Replacement Program
Public Utilities, General Disclosures [Line Items]
Capital expenditures	$ 2

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Regulatory Matters - GAS Atlanta Gas Light (Details) $ in Millions	Jul. 01, 2022 USD ($)
SOUTHERN Co GAS | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease) amount	$ 53

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Contingencies - General Litigation Matters (Details) $ in Millions			1 Months Ended		12 Months Ended
	Jun. 09, 2022 USD ($)	Feb. 07, 2022 claim	Oct. 31, 2021 claim	Mar. 31, 2019 plaintiff	Dec. 31, 2018 USD ($) plaintiff defendant	Mar. 09, 2022 claim	Dec. 31, 2017 claim
Pending Litigation | Shareholder Derivative Lawsuits
Loss Contingencies [Line Items]
Pending number of claims							2
Settled Litigation | Shareholder Derivative Lawsuits
Loss Contingencies [Line Items]
Settlement expense | $	$ 4.5
GEORGIA POWER CO | Pending Litigation | Class Action Lawsuit
Loss Contingencies [Line Items]
Pending number of claims						4
Complaints filed		4	3
MISSISSIPPI POWER CO | Pending Litigation | Purported Violations of Mississippi Consumer Protection Act
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff					10
Number of defendants | defendant					3
Number of additional plaintiffs | plaintiff				4
Underpayment of refunds | $					$ 23.5

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Contingencies - Environmental Remediation (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
GEORGIA POWER CO
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 16	$ 17
SOUTHERN Co GAS
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 241	$ 249

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Contingencies - Other Matters (Details)		12 Months Ended	60 Months Ended
	Jul. 12, 2022 USD ($) claim	Dec. 31, 2019 USD ($)	Jan. 15, 2024 USD ($)
Plant Daniel Unit, Primary | MISSISSIPPI POWER CO | Subsequent Event
Loss Contingencies [Line Items]
Plant units | claim	1
Plant Daniel Units 1 And 2 | GULF POWER CO | Subsequent Event
Loss Contingencies [Line Items]
Percent ownership in individual unit	100.00%
Plant Daniel Units 1 And 2 | MISSISSIPPI POWER CO | Subsequent Event
Loss Contingencies [Line Items]
Plant units | claim	2
Scenario, Forecast | Plant Daniel Units 1 And 2 | MISSISSIPPI POWER CO
Loss Contingencies [Line Items]
Payments to acquire businesses			$ 1
Business combination, option to purchase, period			120 days
Disposal Group, Disposed of by Sale | GULF POWER CO
Loss Contingencies [Line Items]
Proceeds from divestiture of businesses, amount held back		$ 75,000,000
Disposal Group, Disposed of by Sale | GULF POWER CO | Subsequent Event
Loss Contingencies [Line Items]
Proceeds from divestiture of businesses, amount held back	$ 75,000,000

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Revenue from Contracts with Customers and Lease Income - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 6,226	$ 5,422	$ 12,486	$ 12,319
Total operating revenues	7,206	5,198	13,854	11,108
Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	4,789	3,599	8,402	6,941
Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4,072	3,396	7,529	6,674
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,655	1,469	3,179	2,936
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,387	1,176	2,567	2,294
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,005	728	1,732	1,397
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	25	23	51	47
Natural Gas
Disaggregation of Revenue [Line Items]
Total operating revenues	1,083	677	3,140	2,371
Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	963	698	2,746	1,883
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	474	311	1,490	925
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	130	73	400	243
Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	276	247	613	536
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	16	8	48	24
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	67	59	195	155
Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	100	651	359	2,442
Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		578		2,168
Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	90	63	333	257
Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	10	10	26	17
Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	980	1,179	1,368	2,488
Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		(1,403)		(3,699)
Wholesale Electric
Disaggregation of Revenue [Line Items]
Total operating revenues	937	546	1,601	1,091
Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	783	382	1,322	778
PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	585	209	930	422
PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	136	118	268	237
Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	62	55	124	119
Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	308	295	530	542
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,644	1,421	3,188	2,895
Total operating revenues	1,931	1,556	3,580	3,115
ALABAMA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,629	1,354	3,008	2,706
ALABAMA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,398	1,277	2,734	2,602
ALABAMA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	617	553	1,250	1,181
ALABAMA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	410	386	786	758
ALABAMA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	368	334	691	654
ALABAMA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3	4	7	9
ALABAMA POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0		0
ALABAMA POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ALABAMA POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	287	135	392	220
ALABAMA POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0		0
ALABAMA POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	183	92	345	196
ALABAMA POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	108	38	168	81
ALABAMA POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	40	29	78	58
ALABAMA POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	35	25	99	57
ALABAMA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	63	52	109	97
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2,614	2,084	4,674	3,995
Total operating revenues	3,121	2,225	5,328	4,195
GEORGIA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	2,908	2,026	4,926	3,813
GEORGIA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2,435	1,914	4,348	3,677
GEORGIA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	962	852	1,783	1,627
GEORGIA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	900	724	1,638	1,410
GEORGIA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	553	321	887	606
GEORGIA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	20	17	40	34
GEORGIA POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0		0
GEORGIA POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
GEORGIA POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	507	141	654	200
GEORGIA POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0		0
GEORGIA POWER CO | Wholesale Electric
Disaggregation of Revenue [Line Items]
Total operating revenues	64	36	130	80
GEORGIA POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	58	33	110	69
GEORGIA POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	40	16	72	30
GEORGIA POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	12	14	23	27
GEORGIA POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	6	3	15	12
GEORGIA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	121	137	216	249
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	422	290	746	582
Total operating revenues	434	303	769	610
MISSISSIPPI POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	252	219	469	422
MISSISSIPPI POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	239	205	447	395
MISSISSIPPI POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	76	64	146	128
MISSISSIPPI POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	77	66	143	126
MISSISSIPPI POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	84	73	154	137
MISSISSIPPI POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2	2	4	4
MISSISSIPPI POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0		0
MISSISSIPPI POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISSISSIPPI POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	12	13	23	28
MISSISSIPPI POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0		0
MISSISSIPPI POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	174	78	282	173
MISSISSIPPI POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	5	2	8	7
MISSISSIPPI POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	1	3	4
MISSISSIPPI POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	169	75	271	162
MISSISSIPPI POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	9	7	17	14
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	731	316	1,146	611
Total operating revenues	899	490	1,438	930
SOUTHERN POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0		0
SOUTHERN POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	168	174	292	319
SOUTHERN POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0		0
SOUTHERN POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	722	311	1,129	602
SOUTHERN POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	441	158	694	313
SOUTHERN POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	85	75	166	150
SOUTHERN POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	196	78	269	139
SOUTHERN POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	9	5	17	9
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,063	1,349	3,105	4,325
Total operating revenues	1,083	677	3,140	2,371
SOUTHERN Co GAS | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	963	698	2,746	1,883
SOUTHERN Co GAS | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	474	311	1,490	925
SOUTHERN Co GAS | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	130	73	400	243
SOUTHERN Co GAS | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	276	247	613	536
SOUTHERN Co GAS | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	16	8	48	24
SOUTHERN Co GAS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	67	59	195	155
SOUTHERN Co GAS | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	100	651	359	2,442
SOUTHERN Co GAS | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		578		2,168
SOUTHERN Co GAS | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	90	63	333	257
SOUTHERN Co GAS | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	10	10	26	17
SOUTHERN Co GAS | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	20	731	35	1,745
SOUTHERN Co GAS | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		(1,403)		(3,699)
SOUTHERN Co GAS | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
SOUTHERN Co GAS | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 0	$ 0	$ 0	$ 0

XML

Revenue from Contracts with Customers and Lease Income - Schedule of Contract Balances (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Accounts Receivable	$ 3,021	$ 2,504
Contract Assets	102	117
Contract Liabilities	70	57
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	773	589
Contract Assets	0	2
Contract Liabilities	3	4
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	1,217	736
Contract Assets	38	63
Contract Liabilities	25	14
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	95	73
Contract Assets	0	0
Contract Liabilities	4	0
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	278	149
Contract Assets	0	1
Contract Liabilities	1	1
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Accounts Receivable	504	753
Contract Assets	0	0
Contract Liabilities	$ 0	$ 0

XML

Revenue from Contracts with Customers and Lease Income - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Contract assets	$ 102	$ 102	$ 117
Contract liabilities	70	70	57
Revenue from contracts with customers recognized	10	19
Unregulated Distributed Generation
Disaggregation of Revenue [Line Items]
Contract assets	63	63	50
Contract liabilities	$ 38	$ 38	$ 39

XML

Revenue from Contracts with Customers and Lease Income - Schedule of Remaining Performance Obligations (Details) $ in Millions	Jun. 30, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 347
Performance obligation, expected timing of satisfaction	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 617
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 414
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 322
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 307
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,340
Performance obligation, expected timing of satisfaction
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 15
Performance obligation, expected timing of satisfaction	6 months
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 24
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 7
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 5
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 39
Performance obligation, expected timing of satisfaction	6 months
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 63
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 30
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 22
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 11
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 21
Performance obligation, expected timing of satisfaction
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 184
Performance obligation, expected timing of satisfaction	6 months
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 347
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 344
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 294
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 299
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,334
Performance obligation, expected timing of satisfaction
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 16
Performance obligation, expected timing of satisfaction	6 months
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 29
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 29
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction

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Revenue from Contracts with Customers and Lease Income - Schedule of Lease Income (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	$ 7	$ 4	$ 13	$ 7
Lease income - operating leases	52	56	105	112
Variable lease income	129	128	211	212
Total lease income	188	188	329	331
ALABAMA POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0	0	0
Lease income - operating leases	19	21	39	41
Variable lease income	0	(1)	0	0
Total lease income	19	20	39	41
GEORGIA POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0	0	0
Lease income - operating leases	8	10	16	21
Variable lease income	0	0	0	0
Total lease income	8	10	16	21
MISSISSIPPI POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	4	4	8	7
Lease income - operating leases	0	0	1	1
Variable lease income	0	0	0	0
Total lease income	4	4	9	8
SOUTHERN POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	3	0	5	0
Lease income - operating leases	21	21	42	42
Variable lease income	138	138	227	228
Total lease income	162	159	274	270
SOUTHERN Co GAS
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0	0	0
Lease income - operating leases	9	9	18	17
Variable lease income	0	0	0	0
Total lease income	$ 9	$ 9	$ 18	$ 17

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Consolidated Entities and Equity Method Investments - Narrative (Details) $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) investor	Dec. 31, 2021 USD ($)
Schedule of Equity Method Investments [Line Items]
Assets	$ 130,769	$ 127,534
Liabilities	97,514	94,967
Equity investments in unconsolidated subsidiaries	1,305	1,282
SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Assets	13,402	13,390
Liabilities	6,523	6,792
Equity investments in unconsolidated subsidiaries	49	86
Proceeds from sale of equity method investments	$ 38
SP Solar Holdings I, LP | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	67.00%
SP Solar Holdings I, LP | Global Atlantic
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	33.00%
Variable Interest Entity, Primary Beneficiary | SP Solar Holdings I, LP | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Assets	$ 6,000	6,100
Liabilities	386	408
Noncontrolling interests related to other partners' interests	1,100	1,100
Variable Interest Entity, Primary Beneficiary | SP Wind | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Assets	2,300	2,300
Liabilities	212	130
Noncontrolling interests related to other partners' interests	$ 40	41
Distribution made to limited partner, cash distributions paid, percentage	60.00%
Number of financial investors | investor	3
Variable Interest Entity, Primary Beneficiary | SP Wind | Financial Investors
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	40.00%
Variable Interest Entity, Primary Beneficiary | Other Variable Interest Entities | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Assets	$ 1,800	1,900
Liabilities	253	263
Noncontrolling interests related to other partners' interests	$ 858	$ 886

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Consolidated Entities and Equity Method Investments - Schedule of Equity Method Investments (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Investment Balance	$ 1,305	$ 1,282
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,134	1,173
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,099	1,129
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Investment Balance	35	$ 44
SOUTHERN Co GAS | PennEast Pipeline
Schedule of Equity Method Investments [Line Items]
Distribution	$ 9

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Consolidated Entities and Equity Method Investments - Schedule of Earnings (Loss) from Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Schedule of Equity Method Investments [Line Items]
Earnings (Loss) from Equity Method Investments	$ 34	$ (40)	$ 80	$ 5
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Earnings (Loss) from Equity Method Investments	31	(52)	71	(11)
Impairment of PennEast Pipeline investment			0	82
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Earnings (Loss) from Equity Method Investments	31	28	70	66
SOUTHERN Co GAS | PennEast Pipeline
Schedule of Equity Method Investments [Line Items]
Earnings (Loss) from Equity Method Investments	0	(81)	0	(79)
Impairment of PennEast Pipeline investment		82		82
Asset impairment charges, net of tax		58		58
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Earnings (Loss) from Equity Method Investments	$ 0	$ 1	$ 1	$ 2

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Financing and Leases - Schedule of Credit Arrangements (Details)	6 Months Ended
	Jun. 30, 2022 USD ($) letter_of_credit
Line of Credit Facility [Line Items]
Expires, 2023	$ 280,000,000
Expires, 2024	700,000,000
Expires, 2025	125,000,000
Expires, 2026	6,550,000,000
Total	7,655,000,000
Unused	7,595,000,000
Expires within One Year	280,000,000
Southern Company parent
Line of Credit Facility [Line Items]
Expires, 2023	0
Expires, 2024	0
Expires, 2025	0
Expires, 2026	2,000,000,000
Total	2,000,000,000
Unused	1,998,000,000
Expires within One Year	0
ALABAMA POWER CO
Line of Credit Facility [Line Items]
Expires, 2023	0
Expires, 2024	550,000,000
Expires, 2025	0
Expires, 2026	700,000,000
Total	1,250,000,000
Unused	1,250,000,000
Expires within One Year	0
GEORGIA POWER CO
Line of Credit Facility [Line Items]
Expires, 2023	0
Expires, 2024	0
Expires, 2025	0
Expires, 2026	1,750,000,000
Total	1,750,000,000
Unused	1,726,000,000
Expires within One Year	0
MISSISSIPPI POWER CO
Line of Credit Facility [Line Items]
Expires, 2023	0
Expires, 2024	150,000,000
Expires, 2025	125,000,000
Expires, 2026	0
Total	275,000,000
Unused	275,000,000
Expires within One Year	0
SOUTHERN POWER CO
Line of Credit Facility [Line Items]
Expires, 2023	0
Expires, 2024	0
Expires, 2025	0
Expires, 2026	600,000,000
Total	600,000,000
Unused	568,000,000
Expires within One Year	$ 0
Letter of credits not included | letter_of_credit	2
SOUTHERN POWER CO | Continuing Letter of Credit Facility A
Line of Credit Facility [Line Items]
Expires, 2023	$ 75,000,000
Expires, 2025	75,000,000
Unused	11,000,000
SOUTHERN POWER CO | Continuing Letter of Credit Facility B
Line of Credit Facility [Line Items]
Unused	5,000,000
SOUTHERN Co GAS
Line of Credit Facility [Line Items]
Expires, 2023	250,000,000
Expires, 2024	0
Expires, 2025	0
Expires, 2026	1,500,000,000
Total	1,750,000,000
Unused	1,748,000,000
Expires within One Year	250,000,000
SEGCO
Line of Credit Facility [Line Items]
Expires, 2023	30,000,000
Expires, 2024	0
Expires, 2025	0
Expires, 2026	0
Total	30,000,000
Unused	30,000,000
Expires within One Year	30,000,000
Southern Company Gas Capital
Line of Credit Facility [Line Items]
Expires, 2026	800,000,000
Nicor Gas
Line of Credit Facility [Line Items]
Expires, 2026	$ 700,000,000

XML

Financing and Leases - Narrative (Details) - USD ($)	Jun. 30, 2022	Mar. 31, 2022
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 7,655,000,000
Variable rate pollution control revenue bonds outstanding	1,500,000,000
MISSISSIPPI POWER CO
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	275,000,000
Variable rate pollution control revenue bonds outstanding	34,000,000
MISSISSIPPI POWER CO | Line of Credit | Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity		$ 125,000,000
ALABAMA POWER CO
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	1,250,000,000
Variable rate pollution control revenue bonds outstanding	789,000,000
GEORGIA POWER CO
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	1,750,000,000
Variable rate pollution control revenue bonds outstanding	672,000,000
Fixed rate pollution control revenue bonds outstanding	$ 445,000,000

XML

Financing and Leases - Equity Units (Details) - Junior Subordinated Debt - USD ($) $ in Millions	Aug. 01, 2022	May 31, 2022
Series 2019A Remarketable Junior Subordinated Notes
Debt Instrument [Line Items]
Remarketed principal amount		$ 862.5
Interest rate		4.475%
Series 2019B Remarketable Junior Subordinated Notes
Debt Instrument [Line Items]
Remarketed principal amount		$ 862.5
Interest rate		5.113%
2019 Series A Equity Units | Scenario, Forecast
Debt Instrument [Line Items]
Common stock issued to settle purchase contracts (in shares)	25,200,000

XML

Financing and Leases - Schedule of Shares Used to Compute Diluted Earnings Per Share (Details) - shares shares in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Debt Disclosure [Abstract]
As reported shares (in shares)	1,065	1,061	1,064	1,060
Effect of stock-based compensation (in shares)	5	6	5	6
Effect of equity units (in shares)	2	0	1	0
Diluted (in shares)	1,072	1,067	1,070	1,066

XML

Financing and Leases - Georgia Power Lease Modification (Details) - USD ($) $ in Millions	Jul. 27, 2022	Jun. 30, 2022	Dec. 31, 2021
Lessor, Lease, Description [Line Items]
Operating lease right-of-use assets, net of amortization		$ 1,623	$ 1,701
Revision of Prior Period, Adjustment | Subsequent Event
Lessor, Lease, Description [Line Items]
Operating lease right-of-use assets, net of amortization	$ (17)
Lease obligations	(18)
Finance lease ROU assets, net	110
Finance lease obligations	$ 111

XML

Income Taxes - Narrative (Details) - USD ($) $ in Billions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	18.70%	10.70%
ITC and PTC carryforwards
Income Tax Contingency [Line Items]
Deferred tax assets	$ 0.9		$ 1.2
GEORGIA POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	16.40%	(6.90%)
MISSISSIPPI POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	18.80%	12.60%
SOUTHERN POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	11.20%	(12.80%)

XML

Retirement Benefits (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, expected future employer contributions, remainder of fiscal year	$ 0		$ 0
Pension Plans and Postretirement Plans
Service cost	103,000,000	$ 108,000,000	206,000,000	$ 217,000,000
Interest cost	102,000,000	86,000,000	204,000,000	173,000,000
Expected return on plan assets	(317,000,000)	(297,000,000)	(633,000,000)	(595,000,000)
Amortization:
Prior service costs	0	0	0	0
Regulatory asset	0	0	0	0
Net loss	60,000,000	79,000,000	120,000,000	157,000,000
Net periodic pension cost (income)	(52,000,000)	(24,000,000)	(103,000,000)	(48,000,000)
Pension Plans | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	24,000,000	25,000,000	49,000,000	51,000,000
Interest cost	24,000,000	21,000,000	48,000,000	41,000,000
Expected return on plan assets	(75,000,000)	(71,000,000)	(152,000,000)	(143,000,000)
Amortization:
Prior service costs	0	0	0	0
Regulatory asset	0	0	0	0
Net loss	15,000,000	20,000,000	31,000,000	41,000,000
Net periodic pension cost (income)	(12,000,000)	(5,000,000)	(24,000,000)	(10,000,000)
Pension Plans | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	26,000,000	28,000,000	52,000,000	56,000,000
Interest cost	30,000,000	26,000,000	61,000,000	52,000,000
Expected return on plan assets	(100,000,000)	(94,000,000)	(199,000,000)	(188,000,000)
Amortization:
Prior service costs	1,000,000	1,000,000	1,000,000	1,000,000
Regulatory asset	0	0	0	0
Net loss	19,000,000	25,000,000	37,000,000	50,000,000
Net periodic pension cost (income)	(24,000,000)	(14,000,000)	(48,000,000)	(29,000,000)
Pension Plans | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	4,000,000	5,000,000	8,000,000	9,000,000
Interest cost	4,000,000	4,000,000	9,000,000	8,000,000
Expected return on plan assets	(14,000,000)	(13,000,000)	(29,000,000)	(27,000,000)
Amortization:
Prior service costs	0	0	0	0
Regulatory asset	0	0	0	0
Net loss	4,000,000	3,000,000	7,000,000	7,000,000
Net periodic pension cost (income)	(2,000,000)	(1,000,000)	(5,000,000)	(3,000,000)
Pension Plans | SOUTHERN POWER CO
Pension Plans and Postretirement Plans
Service cost	3,000,000	3,000,000	5,000,000	5,000,000
Interest cost	1,000,000	1,000,000	3,000,000	2,000,000
Expected return on plan assets	(4,000,000)	(4,000,000)	(8,000,000)	(7,000,000)
Amortization:
Prior service costs	0	0	0	0
Regulatory asset	0	0	0	0
Net loss	0	1,000,000	1,000,000	2,000,000
Net periodic pension cost (income)	0	1,000,000	1,000,000	2,000,000
Pension Plans | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	8,000,000	9,000,000	17,000,000	18,000,000
Interest cost	7,000,000	6,000,000	14,000,000	12,000,000
Expected return on plan assets	(24,000,000)	(22,000,000)	(46,000,000)	(43,000,000)
Amortization:
Prior service costs	0	0	(1,000,000)	(1,000,000)
Regulatory asset	4,000,000	4,000,000	8,000,000	8,000,000
Net loss	1,000,000	3,000,000	3,000,000	6,000,000
Net periodic pension cost (income)	(4,000,000)	0	(5,000,000)	0
Postretirement Benefits
Pension Plans and Postretirement Plans
Service cost	5,000,000	6,000,000	11,000,000	12,000,000
Interest cost	11,000,000	9,000,000	21,000,000	17,000,000
Expected return on plan assets	(20,000,000)	(19,000,000)	(40,000,000)	(38,000,000)
Amortization:
Prior service costs		(1,000,000)		(1,000,000)
Regulatory asset	0	0	0	0
Net loss	0	1,000,000	0	2,000,000
Net periodic pension cost (income)	(4,000,000)	(4,000,000)	(8,000,000)	(8,000,000)
Postretirement Benefits | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	2,000,000	2,000,000	3,000,000	3,000,000
Interest cost	2,000,000	2,000,000	5,000,000	4,000,000
Expected return on plan assets	(8,000,000)	(7,000,000)	(16,000,000)	(14,000,000)
Amortization:
Prior service costs		0		0
Regulatory asset	0	0	0	0
Net loss	0	0	0	0
Net periodic pension cost (income)	(4,000,000)	(3,000,000)	(8,000,000)	(7,000,000)
Postretirement Benefits | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	1,000,000	1,000,000	3,000,000	3,000,000
Interest cost	3,000,000	3,000,000	7,000,000	6,000,000
Expected return on plan assets	(6,000,000)	(6,000,000)	(13,000,000)	(13,000,000)
Amortization:
Prior service costs		0		0
Regulatory asset	0	0	0	0
Net loss	1,000,000	0	1,000,000	1,000,000
Net periodic pension cost (income)	(1,000,000)	(2,000,000)	(2,000,000)	(3,000,000)
Postretirement Benefits | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	0	0	0	0
Interest cost	1,000,000	1,000,000	1,000,000	1,000,000
Expected return on plan assets	(1,000,000)	(1,000,000)	(1,000,000)	(1,000,000)
Amortization:
Prior service costs		0		0
Regulatory asset	0	0	0	0
Net loss	0	0	0	0
Net periodic pension cost (income)	0	0	0	0
Postretirement Benefits | SOUTHERN POWER CO
Pension Plans and Postretirement Plans
Service cost	0	0	0	0
Interest cost	0	0	0	0
Expected return on plan assets	0	0	0	0
Amortization:
Prior service costs		0		0
Regulatory asset	0	0	0	0
Net loss	0	0	0	0
Net periodic pension cost (income)	0	0	0	0
Postretirement Benefits | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	0	1,000,000	1,000,000	1,000,000
Interest cost	1,000,000	1,000,000	2,000,000	2,000,000
Expected return on plan assets	(1,000,000)	(2,000,000)	(3,000,000)	(4,000,000)
Amortization:
Prior service costs		0		0
Regulatory asset	1,000,000	1,000,000	3,000,000	3,000,000
Net loss	0	0	(1,000,000)	(1,000,000)
Net periodic pension cost (income)	$ 1,000,000	$ 1,000,000	$ 2,000,000	$ 1,000,000

XML

Fair Value Measurements - Schedule of Assets and Liabilities Measured at Fair Value (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Assets:
Derivatives	$ 364	$ 213
Liabilities:
Derivatives	472	125
Other	13
Collateral already posted, assets, aggregate fair value	13
Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Other	0
Significant Other Observable Inputs (Level 2)
Liabilities:
Other	13
Significant Unobservable Inputs (Level 3)
Liabilities:
Other	0
ALABAMA POWER CO
Assets:
Derivatives	111	50
Liabilities:
Derivatives	3	6
GEORGIA POWER CO
Assets:
Derivatives	116	67
Investments in trusts	65
Liabilities:
Derivatives	8	0
MISSISSIPPI POWER CO
Assets:
Derivatives	110	52
Liabilities:
Derivatives	3	1
SOUTHERN POWER CO
Assets:
Derivatives	5	4
Liabilities:
Derivatives	45	16
Other	13
SOUTHERN POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Other	0
SOUTHERN POWER CO | Significant Other Observable Inputs (Level 2)
Liabilities:
Other	13
SOUTHERN POWER CO | Significant Unobservable Inputs (Level 3)
Liabilities:
Other	0
SOUTHERN Co GAS
Assets:
Derivatives	22	27
Liabilities:
Derivatives	77	16
Total
Collateral already posted, assets, aggregate fair value	13	$ 3
Fair Value, Measurements, Recurring
Assets:
Cash equivalents	1,068
Other investments	36
Total	3,725
Liabilities:
Contingent consideration	14
Total	573
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	1,058
Other investments	9
Total	1,915
Liabilities:
Contingent consideration	0
Total	16
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	10
Other investments	27
Total	1,646
Liabilities:
Contingent consideration	0
Total	543
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Other investments	0
Total	0
Liabilities:
Contingent consideration	14
Total	14
Fair Value, Measurements, Recurring | Net Asset Value as a Practical Expedient (NAV)
Assets:
Total	164
Fair Value, Measurements, Recurring | Energy-related derivatives
Assets:
Derivatives	451
Liabilities:
Derivatives	104
Fair Value, Measurements, Recurring | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	43
Liabilities:
Derivatives	16
Fair Value, Measurements, Recurring | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	408
Liabilities:
Derivatives	88
Fair Value, Measurements, Recurring | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Interest rate derivatives
Liabilities:
Derivatives	214
Fair Value, Measurements, Recurring | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	214
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Domestic equity
Assets:
Investments in trusts	811
Fair Value, Measurements, Recurring | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	643
Fair Value, Measurements, Recurring | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	168
Fair Value, Measurements, Recurring | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Foreign equity
Assets:
Investments in trusts	266
Fair Value, Measurements, Recurring | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	122
Fair Value, Measurements, Recurring | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	144
Fair Value, Measurements, Recurring | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities
Assets:
Investments in trusts	273
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	273
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Municipal bonds
Assets:
Investments in trusts	56
Fair Value, Measurements, Recurring | Municipal bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Municipal bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	56
Fair Value, Measurements, Recurring | Municipal bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Pooled funds – fixed income
Assets:
Investments in trusts	9
Fair Value, Measurements, Recurring | Pooled funds – fixed income | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Pooled funds – fixed income | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	9
Fair Value, Measurements, Recurring | Pooled funds – fixed income | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Corporate bonds
Assets:
Investments in trusts	446
Fair Value, Measurements, Recurring | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	1
Fair Value, Measurements, Recurring | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	445
Fair Value, Measurements, Recurring | Corporate bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Mortgage and asset backed securities
Assets:
Investments in trusts	89
Fair Value, Measurements, Recurring | Mortgage and asset backed securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Mortgage and asset backed securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	89
Fair Value, Measurements, Recurring | Mortgage and asset backed securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity
Assets:
Investments in trusts	164
Fair Value, Measurements, Recurring | Private equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity | Net Asset Value as a Practical Expedient (NAV)
Assets:
Investments in trusts	164
Fair Value, Measurements, Recurring | Cash and cash equivalents
Assets:
Investments in trusts	3
Fair Value, Measurements, Recurring | Cash and cash equivalents | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	3
Fair Value, Measurements, Recurring | Cash and cash equivalents | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Cash and cash equivalents | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Other
Assets:
Investments in trusts	53
Fair Value, Measurements, Recurring | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	36
Fair Value, Measurements, Recurring | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	17
Fair Value, Measurements, Recurring | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Foreign currency derivatives
Liabilities:
Derivatives	228
Fair Value, Measurements, Recurring | Foreign currency derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Foreign currency derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	228
Fair Value, Measurements, Recurring | Foreign currency derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO
Assets:
Cash equivalents	687
Other investments	27
Total	1,968
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	677
Other investments	0
Total	1,211
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	10
Other investments	27
Total	593
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Other investments	0
Total	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Net Asset Value as a Practical Expedient (NAV)
Assets:
Total	164
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives
Assets:
Derivatives	131
Liabilities:
Derivatives	23
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	131
Liabilities:
Derivatives	23
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity
Assets:
Investments in trusts	550
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	391
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	159
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity
Assets:
Investments in trusts	122
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	122
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities
Assets:
Investments in trusts	17
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	17
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds
Assets:
Investments in trusts	2
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	2
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds
Assets:
Investments in trusts	228
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	1
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	227
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities
Assets:
Investments in trusts	20
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	20
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity
Assets:
Investments in trusts	164
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Net Asset Value as a Practical Expedient (NAV)
Assets:
Investments in trusts	164
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other
Assets:
Investments in trusts	20
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	20
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO
Assets:
Cash equivalents	98
Total	1,260
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	98
Total	366
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	894
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Total	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives
Assets:
Derivatives	137
Liabilities:
Derivatives	29
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	137
Liabilities:
Derivatives	29
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity
Assets:
Investments in trusts	253
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	252
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	1
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity
Assets:
Investments in trusts	142
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	142
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities
Assets:
Investments in trusts	256
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	256
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds
Assets:
Investments in trusts	54
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	54
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds
Assets:
Investments in trusts	218
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	218
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities
Assets:
Investments in trusts	69
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	69
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other
Assets:
Investments in trusts	33
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	16
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	17
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives
Assets:
Derivatives	121
Liabilities:
Derivatives	14
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	121
Liabilities:
Derivatives	14
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO
Liabilities:
Contingent consideration	14
Total	73
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Contingent consideration	0
Total	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Other Observable Inputs (Level 2)
Liabilities:
Contingent consideration	0
Total	59
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Unobservable Inputs (Level 3)
Liabilities:
Contingent consideration	14
Total	14
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives
Assets:
Derivatives	6
Liabilities:
Derivatives	1
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	6
Liabilities:
Derivatives	1
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives
Liabilities:
Derivatives	45
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	45
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS
Assets:
Cash equivalents	192
Total	270
Liabilities:
Total	98
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	192
Total	238
Liabilities:
Total	16
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	32
Liabilities:
Total	82
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Total	0
Liabilities:
Total	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives
Assets:
Derivatives	56
Liabilities:
Derivatives	36
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	43
Liabilities:
Derivatives	16
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	13
Liabilities:
Derivatives	20
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives
Liabilities:
Derivatives	62
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	62
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity
Assets:
Non-qualified deferred compensation trusts	8
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	8
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity
Assets:
Non-qualified deferred compensation trusts	2
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	2
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income
Assets:
Non-qualified deferred compensation trusts	9
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	9
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents
Assets:
Non-qualified deferred compensation trusts	3
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	3
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	$ 0

XML

Fair Value Measurements - Schedule of Increase (Decrease) In Fair Value Of Funds (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ (230)	$ 125	$ (380)	$ 164
ALABAMA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	(125)	77	(192)	118
GEORGIA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ (105)	$ 48	$ (188)	$ 46

XML

Fair Value Measurements - Narrative (Details) - ALABAMA POWER CO - Private equity $ in Millions	Jun. 30, 2022 USD ($)
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Fair value	$ 164
Unfunded commitments	$ 91

XML

Fair Value Measurements - Schedule of Financial Instruments for which Carrying Amount did not Equal Fair Value (Details) $ in Millions	Jun. 30, 2022 USD ($)
Long-term debt, including securities due within one year:
Carrying amount	$ 52,000.0
Fair value	48,000.0
ALABAMA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	9,800.0
Fair value	9,000.0
GEORGIA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	14,600.0
Fair value	13,700.0
MISSISSIPPI POWER CO
Long-term debt, including securities due within one year:
Carrying amount	1,500.0
Fair value	1,300.0
SOUTHERN POWER CO
Long-term debt, including securities due within one year:
Carrying amount	3,000.0
Fair value	2,900.0
SOUTHERN Co GAS
Long-term debt, including securities due within one year:
Carrying amount	6,800.0
Fair value	$ 6,200.0

XML

Derivatives - Schedule of Energy-Related Derivatives (Details) - Energy-related, Natural Gas MMBTU in Millions	Jun. 30, 2022 MMBTU
Energy-related derivative contracts
Net Purchased mmBtu	273.0
ALABAMA POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	65.0
GEORGIA POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	75.0
MISSISSIPPI POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	71.0
SOUTHERN POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	4.0
SOUTHERN Co GAS
Energy-related derivative contracts
Net Purchased mmBtu	58.0
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Long
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume	64.4
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Short
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume	6.4

XML

Derivatives - Narrative (Details) MMBTU in Millions	6 Months Ended
	Jun. 30, 2022 USD ($) MMBTU	Dec. 31, 2021 USD ($)
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	15
Energy-related derivative hedge gain (loss) to be reclassified within twelve months	$ 12,000,000
Collateral already posted, assets, aggregate fair value	13,000,000
Interest rate derivatives
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	$ (16,000,000)
ALABAMA POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	4
GEORGIA POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	5
MISSISSIPPI POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	2
SOUTHERN POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	4
Foreign currency cash flow hedge gain (loss) to be reclassified during next 12 months	$ 11,000,000
Registrants | Derivative Counterparties
Derivative [Line Items]
Collateral already posted, assets, aggregate fair value	0
SOUTHERN Co GAS
Derivative [Line Items]
Collateral already posted, assets, aggregate fair value	$ 13,000,000	$ 3,000,000

XML

Derivatives - Schedule of Interest Rate Derivatives (Details) - Interest rate derivatives $ in Millions	6 Months Ended
	Jun. 30, 2022 USD ($)
Derivative [Line Items]
Notional Amount	$ 2,200
Fair Value Gain (Loss)	(214)
ALABAMA POWER CO | Cash Flow Hedges of Existing Debt
Derivative [Line Items]
Notional Amount	$ 50
Interest Rate Received	0.00%
Weighted Average Interest Rate Paid	3.18%
Fair Value Gain (Loss)	$ 0
SOUTHERN Co GAS | Cash Flow Hedges of Existing Debt
Derivative [Line Items]
Notional Amount	$ 250
Interest Rate Received	0.00%
Weighted Average Interest Rate Paid	3.26%
Fair Value Gain (Loss)	$ (5)
SOUTHERN Co GAS | Fair Value Hedges of Existing Debt
Derivative [Line Items]
Notional Amount	$ 500
Interest Rate Received	1.75%
Fair Value Gain (Loss)	$ (57)
Southern Company parent | Fair Value Hedges of Existing Debt | March 2028
Derivative [Line Items]
Notional Amount	$ 400
Interest Rate Received	1.75%
Fair Value Gain (Loss)	$ (39)
Southern Company parent | Fair Value Hedges of Existing Debt | April 2030
Derivative [Line Items]
Notional Amount	$ 1,000
Interest Rate Received	3.70%
Fair Value Gain (Loss)	$ (113)
London Interbank Offered Rate (LIBOR) | SOUTHERN Co GAS | Fair Value Hedges of Existing Debt
Derivative [Line Items]
Weighted Average Interest Rate Paid	0.38%
London Interbank Offered Rate (LIBOR) | Southern Company parent | Fair Value Hedges of Existing Debt | March 2028
Derivative [Line Items]
Weighted Average Interest Rate Paid	0.68%
London Interbank Offered Rate (LIBOR) | Southern Company parent | Fair Value Hedges of Existing Debt | April 2030
Derivative [Line Items]
Weighted Average Interest Rate Paid	2.36%

XML

Derivatives - Schedule of Foreign Currency Derivatives (Details) - 6 months ended Jun. 30, 2022 - Foreign currency derivatives € in Millions, $ in Millions	USD ($)	EUR (€)
Derivative [Line Items]
Pay Notional	$ 2,040
Receive Notional | €		€ 1,750
Fair Value Gain (Loss)	(228)
Fair Value Hedges of Existing Debt | Southern Company parent
Derivative [Line Items]
Pay Notional	$ 1,476
Pay Rate	3.39%
Receive Notional | €		1,250
Receive Rate	1.88%
Fair Value Gain (Loss)	$ (183)
Cash Flow Hedges of Existing Debt | SOUTHERN POWER CO | April 2030
Derivative [Line Items]
Pay Notional	$ 564
Pay Rate	3.78%
Receive Notional | €		€ 500
Receive Rate	1.85%
Fair Value Gain (Loss)	$ (45)

XML

Derivatives - Schedule of Derivative Category and Balance Sheet Location (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	$ 451	$ 238
Derivative asset, Gross amounts offset	(87)	(25)
Derivative asset, net amounts recognized in the balance sheets	364	213
Derivative liability, gross amount recognized	546	153
Derivative liability, Gross amounts offset	(74)	(28)
Derivative liability, net amounts recognized in the balance sheets	472	125
Collateral already posted, assets, aggregate fair value	13
Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	17	10
Derivative liability, gross amount recognized	13	4
Derivatives not designated as hedging instruments | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	15	9
Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	12	4
Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	2	1
Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	0
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	411	201
Derivative liability, gross amount recognized	86	36
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	267	129
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	49	30
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	144	72
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	37	6
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	23	27
Derivative liability, gross amount recognized	447	113
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	17	7
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	5	5
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	6	1
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	19
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	19	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	195	29
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	36	39
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	192	40
ALABAMA POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, Gross amounts offset	(20)	(5)
Derivative asset, net amounts recognized in the balance sheets	111	50
Derivative liability, Gross amounts offset	(20)	(5)
Derivative liability, net amounts recognized in the balance sheets	3	6
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	131	55
Derivative liability, gross amount recognized	23	11
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	76	30
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	6	9
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	55	25
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	17	2
GEORGIA POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, Gross amounts offset	(21)	(8)
Derivative asset, net amounts recognized in the balance sheets	116	67
Derivative liability, Gross amounts offset	(21)	(8)
Derivative liability, net amounts recognized in the balance sheets	8	0
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	137	75
Derivative liability, gross amount recognized	29	8
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	102	54
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	15	6
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	35	21
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	14	2
MISSISSIPPI POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, Gross amounts offset	(11)	(4)
Derivative asset, net amounts recognized in the balance sheets	110	52
Derivative liability, Gross amounts offset	(11)	(4)
Derivative liability, net amounts recognized in the balance sheets	3	1
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	121	56
Derivative liability, gross amount recognized	14	5
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	67	30
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	8	3
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	54	26
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	6	2
SOUTHERN POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	6	4
Derivative asset, Gross amounts offset	(1)	0
Derivative asset, net amounts recognized in the balance sheets	5	4
Derivative liability, gross amount recognized	46	16
Derivative liability, Gross amounts offset	(1)	0
Derivative liability, net amounts recognized in the balance sheets	45	16
SOUTHERN POWER CO | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	2	1
Derivative liability, gross amount recognized	1	0
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	1
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	0
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	0
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	4	3
Derivative liability, gross amount recognized	45	16
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	2
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	4	1
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	11	16
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	34	0
SOUTHERN Co GAS
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	56	35
Derivative asset, Gross amounts offset	(34)	(8)
Derivative asset, net amounts recognized in the balance sheets	22	27
Derivative liability, gross amount recognized	98	27
Derivative liability, Gross amounts offset	(21)	(11)
Derivative liability, net amounts recognized in the balance sheets	77	16
Collateral already posted, assets, aggregate fair value	13	3
SOUTHERN Co GAS | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	14	9
Derivative liability, gross amount recognized	12	4
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	13	8
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	11	4
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	1
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	23	15
Derivative liability, gross amount recognized	19	12
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	23	15
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	19	12
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	19	11
Derivative liability, gross amount recognized	67	11
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	17	5
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	5	5
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	2	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	6
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	62	6
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	$ 0	$ 0

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Derivatives - Schedule of Pre-tax Effects of Unrealized Derivative Gains (Losses) (Details) - Energy-related derivatives - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	$ 315	$ 155
Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(26)	(17)
Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(3)
Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	234	107
Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	110	65
ALABAMA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	108	44
ALABAMA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(2)	(6)
ALABAMA POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(1)
ALABAMA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	72	28
ALABAMA POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	39	22
GEORGIA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	108	67
GEORGIA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(6)	0
GEORGIA POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(1)
GEORGIA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	93	48
GEORGIA POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	22	19
MISSISSIPPI POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	107	51
MISSISSIPPI POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(3)	0
MISSISSIPPI POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(1)
MISSISSIPPI POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	62	27
MISSISSIPPI POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	49	24
SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(8)	(7)
SOUTHERN Co GAS | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(15)	(11)
SOUTHERN Co GAS | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	0
SOUTHERN Co GAS | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	7	4
SOUTHERN Co GAS | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	$ 0	$ 0

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Derivatives - Schedule of Pre-Tax Effects of Hedging on AOCI (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	$ (61)	$ 19	$ (34)	$ (21)
Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(1)	16	41	20
Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	21	(1)	30	2
Cash Flow Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(74)	4	(102)	(43)
Fair Value Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(7)	0	(3)	0
GEORGIA POWER CO | Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	19	0	31	0
SOUTHERN POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(72)	9	(95)	(35)
SOUTHERN POWER CO | Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	2	5	7	8
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(74)	4	(102)	(43)
SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(7)	11	30	12
SOUTHERN Co GAS | Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(2)	11	35	12
SOUTHERN Co GAS | Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	$ (5)	$ 0	$ (5)	$ 0

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Derivatives - Schedule of Pre-Tax Effects of Cash Flow and Fair Value Hedging on Income (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivative [Line Items]
Depreciation and amortization	$ 913	$ 891	$ 1,805	$ 1,762
Total interest expense, net of amounts capitalized	(488)	(450)	(950)	(901)
Total other income (expense), net	139	101	283	160
Natural gas
Derivative [Line Items]
Total cost of sales	452	231	1,546	814
Other Income (Expense)
Derivative [Line Items]
Amount excluded from effectiveness testing recognized in earnings	7	0	3	0
Cash Flow Hedging | Energy-related derivatives | Cost of Sales
Derivative [Line Items]
Gain (loss) on hedges	10	1	18	(2)
Cash Flow Hedging | Energy-related derivatives | Depreciation and Amortization
Derivative [Line Items]
Gain (loss) on hedges	4	1	6	4
Cash Flow Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(6)	(7)	(13)	(14)
Cash Flow Hedging | Foreign currency derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(7)	(6)	(13)	(12)
Cash Flow Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	(73)	17	(97)	(43)
Fair Value Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(76)	(3)	(198)	(12)
Fair Value Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	(96)	0	(121)	0
SOUTHERN POWER CO
Derivative [Line Items]
Depreciation and amortization	131	132	251	251
Total interest expense, net of amounts capitalized	(36)	(37)	(73)	(75)
Total other income (expense), net	1	1	3	8
SOUTHERN POWER CO | Cash Flow Hedging | Energy-related derivatives | Depreciation and Amortization
Derivative [Line Items]
Gain (loss) on hedges	4	1	6	4
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(7)	(6)	(13)	(12)
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	(73)	17	(97)	(43)
SOUTHERN Co GAS
Derivative [Line Items]
Depreciation and amortization	138	133	275	263
Total interest expense, net of amounts capitalized	(61)	(59)	(122)	(118)
Total other income (expense), net	16	(14)	32	(78)
SOUTHERN Co GAS | Natural gas
Derivative [Line Items]
Total cost of sales	452	231	1,546	814
SOUTHERN Co GAS | Cash Flow Hedging | Energy-related derivatives | Cost of Sales
Derivative [Line Items]
Gain (loss) on hedges	10	0	18	(2)
SOUTHERN Co GAS | Cash Flow Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(1)	(1)	(1)	(1)
SOUTHERN Co GAS | Fair Value Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	$ (22)	$ 4	$ (57)	$ 4

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Derivatives - Schedule of Cumulative Basis Adjustments for Fair Value Hedges (Details) - Fair Value Hedging - Long-term debt - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Derivative [Line Items]
Carrying Amount of the Hedged Item	$ (2,981)	$ (3,280)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	192	9
SOUTHERN Co GAS
Derivative [Line Items]
Carrying Amount of the Hedged Item	(437)	(493)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	$ 59	$ 2

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Derivatives - Schedule of Pre-tax Effect of Interest Rate and Energy Related Derivatives on Income (Details) - Derivatives not designated as hedging instruments - Energy-related derivatives - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ (40)	$ (94)	$ (18)	$ (104)
Natural gas revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	(15)	(103)	(13)	(120)
Cost of natural gas
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ (25)	$ 9	$ (5)	$ 16

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Acquisitions and Dispositions - Southern Power Narrative (Details) - SOUTHERN POWER CO - MW	1 Months Ended		6 Months Ended	12 Months Ended
	Mar. 31, 2022	Feb. 28, 2022	Jun. 30, 2022	Dec. 31, 2021
Tranquillity Solar Storage
Business Acquisition [Line Items]
Nameplate capacity placed in service (in MWs)	40		40	32
Garland Solar Storage
Business Acquisition [Line Items]
Nameplate capacity placed in service (in MWs)		15	15	73

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Acquisitions and Dispositions - Schedule of Construction Projects (Details) - SOUTHERN POWER CO - MW	1 Months Ended		5 Months Ended	6 Months Ended		12 Months Ended
	Mar. 31, 2022	Feb. 28, 2022	Mar. 31, 2022	Jun. 30, 2022	Feb. 28, 2022	Dec. 31, 2021
Garland Solar Storage
Business Acquisition [Line Items]
Approximate Nameplate Capacity (MW)				88
PPA Contract Period					20 years
Nameplate capacity placed in service (in MWs)		15		15		73
Tranquillity Solar Storage
Business Acquisition [Line Items]
Approximate Nameplate Capacity (MW)				72
PPA Contract Period			20 years
Nameplate capacity placed in service (in MWs)	40			40		32

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Acquisitions and Dispositions - Southern Company Gas (Details) $ in Millions	May 20, 2022 USD ($)
SOUTHERN Co GAS | Pivotal LNG | Disposal Group, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture of businesses, amount held back	$ 5

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Segment and Related Information - Narrative (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022 USD ($) state	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($) segment state	Jun. 30, 2021 USD ($)
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	3		3
Operating revenues	$ 6,226	$ 5,422	$ 12,486	$ 12,319
SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	$ 731	316	$ 1,146	611
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	4		4
Operating revenues	$ 1,063	1,349	$ 3,105	4,325
Number of reportable segments | segment			3
SOUTHERN Co GAS | Southern Natural Gas Company, LLC
Segment Reporting Information [Line Items]
Ownership percentage, equity method investment	50.00%		50.00%
SOUTHERN Co GAS | Dalton Pipeline
Segment Reporting Information [Line Items]
Ownership percentage, equity method investment	50.00%		50.00%
SOUTHERN Co GAS | PennEast Pipeline
Segment Reporting Information [Line Items]
Ownership percentage, equity method investment	20.00%		20.00%
Traditional Electric Operating Companies | Wholesale revenues, affiliates | SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	$ 232	112	$ 337	193
SOUTHERN POWER CO | Natural gas | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues		$ 6		$ 18

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Segment and Related Information - Schedule of Financial Data for Business Segments (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Segment Reporting Information [Line Items]
Operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Segment net income (loss)	1,107	372	2,139	1,508
Goodwill	5,280		5,280		$ 5,280
Total assets	130,769		130,769		127,534
Estimated loss on Plant Vogtle Units 3 and 4	52	460	52	508
GEORGIA POWER CO
Segment Reporting Information [Line Items]
Operating revenues	3,121	2,225	5,328	4,195
Total assets	50,974		50,974		48,461
Estimated loss on Plant Vogtle Units 3 and 4	52	460	52	508
Estimated loss on Plant Vogtle Units 3 and 4, net of tax	39	343	39	379
SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	899	490	1,438	930
Segment net income (loss)	98	36	170	133
Total assets	13,402		13,402		13,390
Gain on sale			2	39
SOUTHERN POWER CO | Wind Generating Facility
Segment Reporting Information [Line Items]
Gain on sale				37
Gain on sale, net of tax				28
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,083	677	3,140	2,371
Segment net income (loss)	115	(65)	433	333
Goodwill	5,015		5,015		5,015
Total assets	23,618		23,618		23,560
Impairment of PennEast Pipeline investment			0	82
SOUTHERN Co GAS | PennEast Pipeline
Segment Reporting Information [Line Items]
Impairment of PennEast Pipeline investment		82		82
Asset impairment charges, net of tax		58		58
Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	6,006	4,407	10,516	8,524
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,083	677	3,140	2,371
Gas distribution operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	4,034		4,034		4,034
Wholesale Gas Services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues		(110)		188
Gas marketing services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	981		981		981
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,080	672	3,133	2,373
Segment net income (loss)	116	(62)	425	332
Total assets	24,170		24,170		23,971
Operating Segments | Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	6,006	4,407	10,516	8,524
Segment net income (loss)	1,134	547	1,981	1,400
Goodwill	2		2		2
Total assets	105,357		105,357		101,774
Operating Segments | Traditional Electric Operating Companies
Segment Reporting Information [Line Items]
Operating revenues	5,563	4,031	9,778	7,795
Segment net income (loss)	1,036	511	1,811	1,267
Goodwill	0		0		0
Total assets	92,742		92,742		89,051
Operating Segments | SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	899	490	1,438	930
Segment net income (loss)	98	36	170	133
Goodwill	2		2		2
Total assets	13,402		13,402		13,390
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,083	677	3,140	2,371
Segment net income (loss)	115	(65)	433	333
Goodwill	5,015		5,015		5,015
Total assets	23,618		23,618		23,560
Operating Segments | Gas distribution operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	980	710	2,782	1,910
Segment net income (loss)	92	80	306	263
Total assets	21,183		21,183		20,917
Operating Segments | Gas Pipeline Investments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	8	8	16	16
Segment net income (loss)	23	(36)	52	(7)
Total assets	1,433		1,433		1,467
Operating Segments | Wholesale Gas Services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	0	(110)	0	188
Segment net income (loss)	0	(112)	0	14
Total assets	0		0		31
Operating Segments | Gas marketing services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	92	64	335	259
Segment net income (loss)	1	6	67	62
Total assets	1,554		1,554		1,556
Operating Segments | All Other
Segment Reporting Information [Line Items]
Operating revenues	159	154	283	288
Segment net income (loss)	(137)	(108)	(263)	(216)
Goodwill	263		263		263
Total assets	2,457		2,457		2,975
Operating Segments | All Other | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	10	11	26	18
Segment net income (loss)	(1)	(3)	8	1
Total assets	11,999		11,999		12,114
Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(42)	(40)	(85)	(75)
Segment net income (loss)	(5)	(2)	(12)	(9)
Goodwill	0		0		0
Total assets	(663)		(663)		(775)
Eliminations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	(7)	(6)	(19)	(20)
Segment net income (loss)	0	0	0	0
Total assets	(12,551)		(12,551)		(12,525)
Eliminations | Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	(456)	(114)	(700)	(201)
Segment net income (loss)	0	$ 0	0	$ 0
Goodwill	0		0		0
Total assets	$ (787)		$ (787)		$ (667)

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Segment and Related Information - Schedule of Financial Data for Products and Services (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Concentration Risk [Line Items]
Operating revenues	$ 7,206	$ 5,198	$ 13,854	$ 11,108
Retail
Concentration Risk [Line Items]
Operating revenues	4,789	3,599	8,402	6,941
Wholesale Electric
Concentration Risk [Line Items]
Operating revenues	937	546	1,601	1,091
Natural Gas
Concentration Risk [Line Items]
Operating revenues	1,083	677	3,140	2,371
Electric Utilities
Concentration Risk [Line Items]
Operating revenues	6,006	4,407	10,516	8,524
Electric Utilities | Retail
Concentration Risk [Line Items]
Operating revenues	4,789	3,599	8,402	6,941
Electric Utilities | Wholesale Electric
Concentration Risk [Line Items]
Operating revenues	937	546	1,601	1,091
Electric Utilities | Other Revenue
Concentration Risk [Line Items]
Operating revenues	280	262	513	492
Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	1,083	677	3,140	2,371
Southern Company Gas' Revenues | Gas Distribution Operations
Concentration Risk [Line Items]
Operating revenues	975	706	2,765	1,898
Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues	0	(110)	0	188
Southern Company Gas' Revenues | Gas marketing services
Concentration Risk [Line Items]
Operating revenues	92	64	335	259
Southern Company Gas' Revenues | Other
Concentration Risk [Line Items]
Operating revenues	16	17	40	26
Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	$ 1,083	677	$ 3,140	2,371
Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		(110)		188
Less Gross Gas Costs		1,429		3,783
Third Party Gross Revenues | Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		1,292		3,881
Intercompany Revenues | Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		27		90
Total Gross Revenues | Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		$ 1,319		$ 3,971