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 March 31, 2023

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	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
Georgia Power Company	Series 2017A 5.00% Junior Subordinated Notes due 2077	GPJA	NYSE
Southern Power Company	Series 2016B 1.850% Senior Notes due 2026	SO/26A	NYSE

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

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

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

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

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

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

Registrant	Description of Common Stock	Shares Outstanding at March 31, 2023
The Southern Company	Par Value $5 Per Share	1,090,402,540
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	89
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	132
Item 4.	Controls and Procedures	132
	PART II—OTHER INFORMATION
Item 1.	Legal Proceedings	133
Item 1A.	Risk Factors	133
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	133
	Signatures	136

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DEFINITIONS

Term	Meaning
2022 ARP	Alternate Rate Plan approved by the Georgia PSC in 2022 for Georgia Power for the years 2023 through 2025
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
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
ECO Plan	Mississippi Power's environmental compliance overview plan
ELG	Effluent limitations guidelines
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
FCC	Federal Communications Commission
FERC	Federal Energy Regulatory Commission
FFB	Federal Financing Bank
Fitch	Fitch Ratings, Inc.
Form 10-K	Annual Report on Form 10-K of Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas for the year ended December 31, 2022, as applicable
GAAP	U.S. generally accepted accounting principles
Georgia Power	Georgia Power Company
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
Heating Degree Days	A measure of weather, calculated when the average daily temperatures are less than 65 degrees Fahrenheit

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DEFINITIONS

(continued)

Term	Meaning
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
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.
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
N/M	Not meaningful
NRC	U.S. Nuclear Regulatory Commission
OCI	Other comprehensive income
OPC	Oglethorpe Power Corporation (an electric membership corporation)
PEP	Mississippi Power's Performance Evaluation Plan
PowerSecure	PowerSecure, Inc., a wholly-owned subsidiary of Southern Company
PPA	Power purchase agreements, as well as, for Southern Power, contracts for differences that provide the owner of a renewable facility a certain fixed price for the electricity sold to the grid
PSC	Public Service Commission
PTC	Production tax credit
Rate CNP	Alabama Power's Rate Certificated New Plant, consisting of Rate CNP New Plant, Rate CNP Compliance, Rate CNP PPA, and Rate CNP Depreciation
Rate ECR	Alabama Power's Rate Energy Cost Recovery
Rate RSE	Alabama Power's Rate Stabilization and Equalization
Registrants	Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power Company, and Southern Company Gas
ROE	Return on equity
S&P	S&P Global Ratings, a division of S&P Global Inc.
SAVE	Steps to Advance Virginia's Energy, an infrastructure replacement program at Virginia Natural Gas
SCS	Southern Company Services, Inc., the Southern Company system service company and a wholly-owned subsidiary of Southern Company
SEC	U.S. Securities and Exchange Commission

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DEFINITIONS

(continued)

Term	Meaning
SEGCO	Southern Electric Generating Company, 50% owned by each of Alabama Power and Georgia Power
SNG	Southern Natural Gas Company, L.L.C., a pipeline system in which Southern Company Gas has a 50% ownership interest
SOFR	Secured Overnight Financing Rate
Southern Company	The Southern Company
Southern Company Gas	Southern Company Gas and its subsidiaries
Southern Company Gas Capital	Southern Company Gas Capital Corporation, a 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
SRR	Mississippi Power's System Restoration Rider, a tariff for retail property damage cost recovery and reserve
Subsidiary Registrants	Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas
Toshiba	Toshiba Corporation, the parent company of Westinghouse
traditional electric operating companies	Alabama Power, Georgia Power, and Mississippi Power
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, including inflation, 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 dispositions, 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 extent and timing of costs and legal requirements related to CCR;

•current and future litigation or regulatory investigations, proceedings, or inquiries, including litigation and other disputes related to the Kemper County energy facility and Plant Vogtle Units 3 and 4;

•the effects, extent, and timing of the entry of additional competition in the markets in which Southern Company's subsidiaries operate, including from the development and deployment of alternative energy sources;

•variations in demand for electricity and natural gas;

•available sources and costs of natural gas and other fuels and commodities;

•the ability to complete necessary or desirable pipeline expansion or infrastructure projects, limits on pipeline capacity, public and policymaker support for such projects, and operational interruptions to natural gas distribution and transmission activities;

•transmission constraints;

•the ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of facilities or other projects, 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 the management of contractors or vendors; subcontractor performance; adverse weather conditions; shortages, delays, increased costs, or inconsistent quality of equipment, materials, and labor; contractor or supplier delay; the impacts of inflation; 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 Plant Vogtle Unit 4, inspections and the timely submittal by Southern Nuclear of the ITAAC documentation 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; continued challenges related to the COVID-19 pandemic or future pandemic health events; continued public and policymaker support for projects; environmental and geological conditions; delays or increased costs to interconnect facilities to transmission grids; and increased financing costs as a result of changes in market interest rates or as a result of project delays;

•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 notices of tender by OPC and Dalton of a portion of their ownership interests in Plant Vogtle Units 3 and 4 to Georgia Power, including related litigation;

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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 and battery energy storage technologies and negative carbon concepts;

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

•state and federal rate regulations and the impact of pending and future rate cases and negotiations, including rate actions relating to ROE, equity ratios, additional generating capacity, and 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 cyber and physical attacks;

•global and U.S. economic conditions, including impacts from recession, inflation, 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 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 direct or indirect effects on the Southern Company system's business resulting from incidents affecting the U.S. electric grid, natural gas pipeline infrastructure, or operation of generating or storage resources;

•impairments of goodwill or long-lived assets;

•the effect of accounting pronouncements issued periodically by standard-setting bodies; and

•other factors discussed elsewhere herein and in other reports (including the Form 10-K) filed by the Registrants from time to time with the SEC.

The Registrants expressly disclaim any obligation to update any forward-looking statements.

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PART I

Item 1. Financial Statements (Unaudited).

	Page
The Southern Company and Subsidiary Companies:
Condensed Consolidated Statements of Income	10
Condensed Consolidated Statements of Comprehensive Income	11
Condensed Consolidated Statements of Cash Flows	12
Condensed Consolidated Balance Sheets	13
Condensed Consolidated Statements of Stockholders' Equity	15
Alabama Power Company:
Condensed Statements of Income	16
Condensed Statements of Comprehensive Income	16
Condensed Statements of Cash Flows	17
Condensed Balance Sheets	18
Condensed Statements of Common Stockholder's Equity	20
Georgia Power Company:
Condensed Statements of Income	21
Condensed Statements of Comprehensive Income	21
Condensed Statements of Cash Flows	22
Condensed Balance Sheets	23
Condensed Statements of Common Stockholder's Equity	25
Mississippi Power Company:
Condensed Statements of Income and Comprehensive Income	26
Condensed Statements of Cash Flows	27
Condensed Balance Sheets	28
Condensed Statements of Common Stockholder's Equity	30
Southern Power Company and Subsidiary Companies:
Condensed Consolidated Statements of Income	31
Condensed Consolidated Statements of Comprehensive Income	31
Condensed Consolidated Statements of Cash Flows	32
Condensed Consolidated Balance Sheets	33
Condensed Consolidated Statements of Stockholders' Equity	35
Southern Company Gas and Subsidiary Companies:
Condensed Consolidated Statements of Income	36
Condensed Consolidated Statements of Comprehensive Income	36
Condensed Consolidated Statements of Cash Flows	37
Condensed Consolidated Balance Sheets	38
Condensed Consolidated Statements of Stockholder's Equity	40
Combined Notes to the Condensed Financial Statements	41

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Revenues:
Retail electric revenues	$	3,599	$	3,613
Wholesale electric revenues	599		664
Other electric revenues	190		177
Natural gas revenues (includes alternative revenue programs of $12 and $—, respectively)	1,875		2,058
Other revenues	217		136
Total operating revenues	6,480		6,648
Operating Expenses:
Fuel	1,050		1,111
Purchased power	242		232
Cost of natural gas	898		1,095
Cost of other sales	127		69
Other operations and maintenance	1,482		1,516
Depreciation and amortization	1,111		892
Taxes other than income taxes	394		372
Gain on dispositions, net	(42)		(23)
Total operating expenses	5,262		5,264
Operating Income	1,218		1,384
Other Income and (Expense):
Allowance for equity funds used during construction	65		51
Earnings from equity method investments	48		46
Interest expense, net of amounts capitalized	(582)		(462)
Other income (expense), net	147		145
Total other income and (expense)	(322)		(220)
Earnings Before Income Taxes	896		1,164
Income taxes	97		173
Consolidated Net Income	799		991
Dividends on preferred stock of subsidiaries	—		4
Net loss attributable to noncontrolling interests	(63)		(45)
Consolidated Net Income Attributable to    Southern Company	$	862	$	1,032
Common Stock Data:
Earnings per share -
Basic	$	0.79	$	0.97
Diluted	$	0.79	$	0.97
Average number of shares of common stock outstanding (in millions)
Basic	1,091		1,063
Diluted	1,098		1,069

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 March 31,
	2023		2022
	(in millions)
Consolidated Net Income	$	799	$	991
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(23) and $8, respectively	(63)		19
Reclassification adjustment for amounts included in net income,    net of tax of $7 and $6, respectively	19		20
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income,    net of tax of $— and $1, respectively	—		3
Total other comprehensive income (loss)	(44)		42
Comprehensive Income	755		1,033
Dividends on preferred stock of subsidiaries	—		4
Comprehensive loss attributable to noncontrolling interests	(63)		(45)
Consolidated Comprehensive Income Attributable to    Southern Company	$	818	$	1,074

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 Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Activities:
Consolidated net income	$	799	$	991
Adjustments to reconcile consolidated net income to net cash provided from operating activities —
Depreciation and amortization, total	1,233		989
Allowance for equity funds used during construction	(65)		(51)
Pension, postretirement, and other employee benefits	(126)		(123)
Settlement of asset retirement obligations	(113)		(87)
Stock based compensation expense	92		85
Natural gas cost under recovery – long-term	—		162
Retail fuel cost under recovery – long-term	454		(130)
Other, net	51		79
Changes in certain current assets and liabilities —
-Receivables	319		(217)
-Prepayments	(100)		(86)
-Fossil fuel for generation	(203)		39
-Materials and supplies	(98)		(28)
-Natural gas for sale, net of temporary LIFO liquidation	267		450
-Other current assets	143		8
-Accounts payable	(1,056)		132
-Accrued taxes	(237)		(58)
-Accrued compensation	(478)		(470)
-Accrued interest	(127)		(128)
-Natural gas cost over recovery	117		—
-Other current liabilities	(28)		35
Net cash provided from operating activities	844		1,592
Investing Activities:
Property additions	(1,850)		(1,419)
Nuclear decommissioning trust fund purchases	(256)		(294)
Nuclear decommissioning trust fund sales	251		289
Proceeds from dispositions	103		91
Cost of removal, net of salvage	(135)		(227)
Change in construction payables, net	(140)		23
Other investing activities	(91)		(18)
Net cash used for investing activities	(2,118)		(1,555)
Financing Activities:
Increase in notes payable, net	187		137
Proceeds —
Long-term debt	1,979		700
Short-term borrowings	100		850
Common stock	15		38
Redemptions and repurchases —
Long-term debt	(575)		(977)
Short-term borrowings	(400)		(100)
Capital contributions from noncontrolling interests	21		73
Distributions to noncontrolling interests	(48)		(97)
Payment of common stock dividends	(742)		(702)
Other financing activities	(83)		(115)
Net cash provided from (used for) financing activities	454		(193)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(820)		(156)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	2,037		1,829
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	1,217	$	1,673
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $32 and $23 capitalized for 2023 and 2022, respectively)	$	652	$	515
Income taxes, net	(9)		(8)
Noncash transactions —
Accrued property additions at end of period	833		863
Right-of-use assets obtained under operating leases	26		3
Right-of-use assets obtained under finance leases	1		—
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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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2023		At December 31, 2022
	(in millions)
Current Assets:
Cash and cash equivalents	$	1,053	$	1,917
Receivables —
Customer accounts	1,890		2,128
Unbilled revenues	596		1,012
Under recovered fuel clause revenues	484		10
Other accounts and notes	510		637
Accumulated provision for uncollectible accounts	(80)		(71)
Materials and supplies	1,756		1,664
Fossil fuel for generation	778		575
Natural gas for sale	216		438
Prepaid expenses	626		347
Assets from risk management activities, net of collateral	53		115
Regulatory assets – asset retirement obligations	342		332
Natural gas cost under recovery	—		108
Other regulatory assets	936		860
Other current assets	395		344
Total current assets	9,555		10,416
Property, Plant, and Equipment:
In service	118,690		117,529
Less: Accumulated depreciation	35,990		35,297
Plant in service, net of depreciation	82,700		82,232
Other utility plant, net	571		599
Nuclear fuel, at amortized cost	849		843
Construction work in progress	11,510		10,896
Total property, plant, and equipment	95,630		94,570
Other Property and Investments:
Goodwill	5,161		5,161
Nuclear decommissioning trusts, at fair value	2,245		2,145
Equity investments in unconsolidated subsidiaries	1,408		1,443
Other intangible assets, net of amortization of $350 and $340, respectively	397		406
Miscellaneous property and investments	616		602
Total other property and investments	9,827		9,757
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,505		1,531
Deferred charges related to income taxes	876		866
Prepaid pension costs	2,384		2,290
Unamortized loss on reacquired debt	234		238
Deferred under recovered fuel clause revenues	1,702		2,056
Regulatory assets – asset retirement obligations, deferred	5,701		5,764
Other regulatory assets, deferred	5,886		5,918
Other deferred charges and assets	1,456		1,485
Total deferred charges and other assets	19,744		20,148
Total Assets	$	134,756	$	134,891

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 March 31, 2023		At December 31, 2022
	(in millions)
Current Liabilities:
Securities due within one year	$	4,363	$	4,285
Notes payable	2,554		2,609
Accounts payable	2,365		3,525
Customer deposits	475		502
Accrued taxes —
Accrued income taxes	52		60
Other accrued taxes	435		764
Accrued interest	487		614
Accrued compensation	617		1,127
Asset retirement obligations	709		694
Liabilities from risk management activities, net of collateral	318		178
Operating lease obligations	199		197
Natural gas cost over recovery	117		—
Other regulatory liabilities	287		382
Other current liabilities	915		787
Total current liabilities	13,893		15,724
Long-term Debt	52,060		50,656
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	10,488		10,036
Deferred credits related to income taxes	5,107		5,235
Accumulated deferred ITCs	2,112		2,133
Employee benefit obligations	1,222		1,238
Operating lease obligations, deferred	1,374		1,388
Asset retirement obligations, deferred	10,209		10,146
Other cost of removal obligations	1,921		1,903
Other regulatory liabilities, deferred	690		733
Other deferred credits and liabilities	1,118		1,167
Total deferred credits and other liabilities	34,241		33,979
Total Liabilities	100,194		100,359
Total Stockholders' Equity (See accompanying statements)	34,562		34,532
Total Liabilities and Stockholders' Equity	$	134,756	$	134,891

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, 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

Balance at December 31, 2022	1,090	(1)	$	5,417	$	13,673	$	(53)	$	11,538	$	(167)	$	4,124	$	34,532
Consolidated net income (loss)	—	—	—		—		—		862		—		(63)		799
Other comprehensive income (loss)	—	—	—		—		—		—		(44)		—		(44)
Stock issued	2	—	4		11		—		—		—		—		15
Stock-based compensation	—	—	—		29		—		—		—		—		29
Cash dividends of $0.68 per share	—	—	—		—		—		(742)		—		—		(742)
Capital contributions from    noncontrolling interests	—	—	—		—		—		—		—		21		21
Distributions to noncontrolling interests	—	—	—		—		—		—		—		(48)		(48)
Other	—	—	—		2		(2)		—		—		—		—
Balance at March 31, 2023	1,092	(1)	$	5,421	$	13,715	$	(55)	$	11,658	$	(211)	$	4,034	$	34,562

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 March 31,
	2023		2022
	(in millions)
Operating Revenues:
Retail revenues	$	1,381	$	1,379
Wholesale revenues, non-affiliates	141		114
Wholesale revenues, affiliates	19		65
Other revenues	106		91
Total operating revenues	1,647		1,649
Operating Expenses:
Fuel	308		333
Purchased power, non-affiliates	101		67
Purchased power, affiliates	59		26
Other operations and maintenance	424		409
Depreciation and amortization	345		215
Taxes other than income taxes	115		104
Total operating expenses	1,352		1,154
Operating Income	295		495
Other Income and (Expense):
Allowance for equity funds used during construction	21		16
Interest expense, net of amounts capitalized	(103)		(89)
Other income (expense), net	40		36
Total other income and (expense)	(42)		(37)
Earnings Before Income Taxes	253		458
Income taxes (benefit)	(2)		107
Net Income	255		351
Dividends on Preferred Stock	—		4
Net Income After Dividends on Preferred Stock	$	255	$	347

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Net Income	$	255	$	351
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $— and $(1), respectively	—		(1)
Reclassification adjustment for amounts included in net income,    net of tax of $— and $—, respectively	—		1
Total other comprehensive income	—		—
Comprehensive Income	$	255	$	351

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 Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Activities:
Net income	$	255	$	351
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	398		250
Deferred income taxes	(75)		35
Pension, postretirement, and other employee benefits	(51)		(48)
Settlement of asset retirement obligations	(52)		(38)
Retail fuel cost under recovery – long-term	100		(46)
Other, net	(3)		(27)
Changes in certain current assets and liabilities —
-Receivables	90		(4)
-Fossil fuel stock	(78)		23
-Prepayments	(89)		(85)
-Other current assets	(37)		(10)
-Accounts payable	(400)		(237)
-Accrued taxes	109		102
-Accrued compensation	(102)		(99)
-Other current liabilities	(35)		(13)
Net cash provided from operating activities	30		154
Investing Activities:
Property additions	(389)		(343)
Nuclear decommissioning trust fund purchases	(87)		(72)
Nuclear decommissioning trust fund sales	87		72
Cost of removal, net of salvage	(41)		(60)
Change in construction payables	(70)		39
Other investing activities	(9)		(1)
Net cash used for investing activities	(509)		(365)
Financing Activities:
Increase in notes payable, net	170		—
Proceeds —
Senior notes	—		700
Other long-term debt	16		—
Redemptions — Senior notes	—		(550)
Capital contributions from parent company	325		625
Payment of common stock dividends	(285)		(254)
Other financing activities	(7)		(17)
Net cash provided from financing activities	219		504
Net Change in Cash, Cash Equivalents, and Restricted Cash	(260)		293
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	687		1,060
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	427	$	1,353
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $7 and $4 capitalized for 2023 and 2022, respectively)	$	138	$	110
Noncash transactions —
Accrued property additions at end of period	111		188
Right-of-use assets obtained under operating leases	13		1
Right-of-use assets obtained under finance leases	1		—

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

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    Table of Contents                                Index to Financial Statements

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2023		At December 31, 2022
	(in millions)
Current Assets:
Cash and cash equivalents	$	427	$	687
Receivables —
Customer accounts	446		431
Unbilled revenues	129		174
Affiliated	98		101
Other accounts and notes	86		153
Accumulated provision for uncollectible accounts	(15)		(14)
Fossil fuel stock	307		229
Materials and supplies	586		557
Prepaid expenses	136		65
Other regulatory assets	485		474
Other current assets	48		67
Total current assets	2,733		2,924
Property, Plant, and Equipment:
In service	33,803		33,472
Less: Accumulated provision for depreciation	10,664		10,470
Plant in service, net of depreciation	23,139		23,002
Other utility plant, net	571		599
Nuclear fuel, at amortized cost	238		239
Construction work in progress	1,510		1,526
Total property, plant, and equipment	25,458		25,366
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,170		1,127
Equity investments in unconsolidated subsidiaries	55		57
Miscellaneous property and investments	125		124
Total other property and investments	1,350		1,308
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	81		71
Deferred charges related to income taxes	253		250
Prepaid pension and other postretirement benefit costs	689		657
Regulatory assets – asset retirement obligations	1,827		1,845
Other regulatory assets, deferred	2,034		2,107
Other deferred charges and assets	454		442
Total deferred charges and other assets	5,338		5,372
Total Assets	$	34,879	$	34,970

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 March 31, 2023		At December 31, 2022
	(in millions)
Current Liabilities:
Securities due within one year	$	323	$	301
Notes payable	170		—
Accounts payable —
Affiliated	242		443
Other	380		641
Customer deposits	105		106
Accrued taxes	148		57
Accrued interest	78		120
Accrued compensation	133		229
Asset retirement obligations	334		330
Other regulatory liabilities	74		96
Other current liabilities	132		91
Total current liabilities	2,119		2,414
Long-term Debt	10,322		10,329
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,997		3,981
Deferred credits related to income taxes	1,836		1,925
Accumulated deferred ITCs	79		81
Employee benefit obligations	149		145
Operating lease obligations	75		67
Asset retirement obligations, deferred	3,940		3,957
Other regulatory liabilities, deferred	300		315
Other deferred credits and liabilities	75		69
Total deferred credits and other liabilities	10,451		10,540
Total Liabilities	22,892		23,283
Common Stockholder's Equity (See accompanying statements)	11,987		11,687
Total Liabilities and Stockholder's Equity	$	34,879	$	34,970

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 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, 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
Balance at December 31, 2022	31	$	1,222	$	6,710	$	3,764	$	(9)	$	11,687
Net income after dividends on    preferred stock	—	—		—		255		—		255
Capital contributions from parent company	—	—		330		—		—		330
Cash dividends on common stock	—	—		—		(285)		—		(285)
Balance at March 31, 2023	31	$	1,222	$	7,040	$	3,734	$	(9)	$	11,987

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 March 31,
	2023		2022
	(in millions)
Operating Revenues:
Retail revenues	$	1,981	$	2,017
Wholesale revenues	31		66
Other revenues	164		125
Total operating revenues	2,176		2,208
Operating Expenses:
Fuel	402		419
Purchased power, non-affiliates	123		150
Purchased power, affiliates	206		206
Other operations and maintenance	496		517
Depreciation and amortization	408		351
Taxes other than income taxes	131		125
Total operating expenses	1,766		1,768
Operating Income	410		440
Other Income and (Expense):
Allowance for equity funds used during construction	40		32
Interest expense, net of amounts capitalized	(146)		(107)
Other income (expense), net	45		50
Total other income and (expense)	(61)		(25)
Earnings Before Income Taxes	349		415
Income taxes	53		30
Net Income	$	296	$	385

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Net Income	$	296	$	385
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $— and $3, respectively	(1)		9
Reclassification adjustment for amounts included in net income,    net of tax of $— and $1, respectively	1		1
Total other comprehensive income	—		10
Comprehensive Income	$	296	$	395

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 Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Activities:
Net income	$	296	$	385
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	455		397
Deferred income taxes	57		(6)
Allowance for equity funds used during construction	(40)		(32)
Pension, postretirement, and other employee benefits	(64)		(63)
Settlement of asset retirement obligations	(54)		(41)
Storm damage accruals	8		53
Retail fuel cost under recovery – long-term	354		(84)
Other, net	(40)		(54)
Changes in certain current assets and liabilities —
-Receivables	(136)		—
-Fossil fuel stock	(107)		18
-Materials and supplies	(46)		(11)
-Other current assets	6		(20)
-Accounts payable	(293)		39
-Accrued taxes	(266)		(78)
-Accrued compensation	(85)		(79)
-Customer refunds	(103)		2
-Accrued interest	(23)		(43)
-Other current liabilities	28		(22)
Net cash provided from (used for) operating activities	(53)		361
Investing Activities:
Property additions	(1,042)		(749)
Nuclear decommissioning trust fund purchases	(169)		(221)
Nuclear decommissioning trust fund sales	164		217
Cost of removal, net of salvage	(64)		(140)
Change in construction payables, net of joint owner portion	(27)		14
Proceeds from dispositions	56		56
Other investing activities	(35)		14
Net cash used for investing activities	(1,117)		(809)
Financing Activities:
Increase in notes payable, net	465		410
Proceeds —
Revenue bonds	229		—
Short-term borrowings	100		450
Redemptions and repurchases —
Senior notes	—		(400)
FFB loan	(21)		(24)
Short-term borrowings	(200)		—
Capital contributions from parent company	750		445
Payment of common stock dividends	(464)		(423)
Other financing activities	(9)		(17)
Net cash provided from financing activities	850		441
Net Change in Cash, Cash Equivalents, and Restricted Cash	(320)		(7)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	480		33
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	160	$	26
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $21 and $16 capitalized for 2023 and 2022, respectively)	$	159	$	139
Noncash transactions —
Accrued property additions at end of period	548		459
Right-of-use assets obtained under operating leases	3		1

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

22

    Table of Contents                                Index to Financial Statements

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2023		At December 31, 2022
	(in millions)
Current Assets:
Cash and cash equivalents	$	—	$	364
Receivables —
Customer accounts, net	597		735
Unbilled revenues	197		309
Under recovered fuel clause revenues	447		—
Joint owner accounts	100		128
Affiliated	59		53
Other accounts and notes	45		62
Fossil fuel stock	399		291
Materials and supplies	774		729
Regulatory assets – asset retirement obligations	166		158
Other regulatory assets	377		324
Other current assets	264		246
Total current assets	3,425		3,399
Property, Plant, and Equipment:
In service	42,465		41,879
Less: Accumulated provision for depreciation	13,383		13,115
Plant in service, net of depreciation	29,082		28,764
Nuclear fuel, at amortized cost	611		604
Construction work in progress	8,639		8,103
Total property, plant, and equipment	38,332		37,471
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,075		1,018
Equity investments in unconsolidated subsidiaries	50		51
Miscellaneous property and investments	116		107
Total other property and investments	1,241		1,176
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	974		1,007
Deferred charges related to income taxes	592		583
Prepaid pension costs	771		738
Deferred under recovered fuel clause revenues	1,702		2,056
Regulatory assets – asset retirement obligations, deferred	3,635		3,671
Other regulatory assets, deferred	2,576		2,522
Other deferred charges and assets	489		540
Total deferred charges and other assets	10,739		11,117
Total Assets	$	53,737	$	53,163

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

23

    Table of Contents                                Index to Financial Statements

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2023		At December 31, 2022
	(in millions)
Current Liabilities:
Securities due within one year	$	901	$	901
Notes payable	1,965		1,600
Accounts payable —
Affiliated	606		928
Other	1,099		1,076
Customer deposits	251		252
Accrued taxes	222		508
Accrued interest	133		157
Accrued compensation	133		254
Operating lease obligations	154		151
Asset retirement obligations	308		295
Other regulatory liabilities	47		170
Other current liabilities	426		286
Total current liabilities	6,245		6,578
Long-term Debt	14,219		14,009
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,818		3,707
Deferred credits related to income taxes	2,220		2,244
Accumulated deferred ITCs	316		319
Employee benefit obligations	310		318
Operating lease obligations, deferred	840		851
Asset retirement obligations, deferred	5,820		5,739
Other deferred credits and liabilities	506		540
Total deferred credits and other liabilities	13,830		13,718
Total Liabilities	34,294		34,305
Common Stockholder's Equity (See accompanying statements)	19,443		18,858
Total Liabilities and Stockholder's Equity	$	53,737	$	53,163

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

24

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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, 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
Balance at December 31, 2022	9	$	398	$	15,626	$	2,846	$	(12)	$	18,858
Net income	—	—		—		296		—		296
Capital contributions from parent company	—	—		752		—		—		752
Cash dividends on common stock	—	—		—		(464)		—		(464)
Other	—	—		—		1		—		1
Balance at March 31, 2023	9	$	398	$	16,378	$	2,679	$	(12)	$	19,443

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

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MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Revenues:
Retail revenues	$	236	$	217
Wholesale revenues, non-affiliates	68		68
Wholesale revenues, affiliates	75		42
Other revenues	11		8
Total operating revenues	390		335
Operating Expenses:
Fuel and purchased power	151		132
Other operations and maintenance	82		76
Depreciation and amortization	47		45
Taxes other than income taxes	32		29
Total operating expenses	312		282
Operating Income	78		53
Other Income and (Expense):
Interest expense, net of amounts capitalized	(16)		(13)
Other income (expense), net	9		10
Total other income and (expense)	(7)		(3)
Earnings Before Income Taxes	71		50
Income taxes	13		8
Net Income and Comprehensive Income	$	58	$	42

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

26

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Activities:
Net income	$	58	$	42
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	58		55
Settlement of asset retirement obligations	(3)		(5)
Other, net	(5)		17
Changes in certain current assets and liabilities —
-Receivables	73		(7)
-Retail fuel cost under recovery	(23)		(11)
-Other current assets	(1)		(11)
-Accounts payable	(74)		(9)
-Accrued taxes	(62)		(63)
-Accrued compensation	(17)		(18)
-Other current liabilities	(7)		(6)
Net cash used for operating activities	(3)		(16)
Investing Activities:
Property additions	(94)		(45)
Construction payables	(9)		(8)
Payments pursuant to LTSAs	(8)		(8)
Other investing activities	(6)		(7)
Net cash used for investing activities	(117)		(68)
Financing Activities:
Increase in notes payable, net	126		25
Capital contributions from parent company	—		50
Payment of common stock dividends	(46)		(43)
Other financing activities	(1)		—
Net cash provided from financing activities	79		32
Net Change in Cash, Cash Equivalents, and Restricted Cash	(41)		(52)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	59		61
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	18	$	9
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest	$	25	$	22
Noncash transactions —
Accrued property additions at end of period	13		17
Right-of-use assets obtained under operating leases	1		—

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

27

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2023		At December 31, 2022
	(in millions)
Current Assets:
Cash and cash equivalents	$	18	$	59
Receivables —
Customer accounts, net	69		47
Unbilled revenues	37		47
Affiliated	26		82
Other accounts and notes	29		35
Fossil fuel stock	51		44
Materials and supplies	80		80
Other regulatory assets	80		72
Other current assets	13		38
Total current assets	403		504
Property, Plant, and Equipment:
In service	5,319		5,254
Less: Accumulated provision for depreciation	1,723		1,689
Plant in service, net of depreciation	3,596		3,565
Construction work in progress	225		208
Total property, plant, and equipment	3,821		3,773
Other Property and Investments	165		167
Deferred Charges and Other Assets:
Deferred charges related to income taxes	29		30
Prepaid pension costs	114		109
Regulatory assets – asset retirement obligations	239		239
Other regulatory assets, deferred	253		249
Accumulated deferred income taxes	103		107
Other deferred charges and assets	89		94
Total deferred charges and other assets	827		828
Total Assets	$	5,216	$	5,272

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

28

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2023		At December 31, 2022
	(in millions)
Current Liabilities:
Securities due within one year	$	1	$	1
Notes payable	126		—
Accounts payable —
Affiliated	69		121
Other	75		106
Accrued taxes	62		124
Accrued compensation	20		37
Asset retirement obligations	35		37
Other regulatory liabilities	25		43
Other current liabilities	81		85
Total current liabilities	494		554
Long-term Debt	1,544		1,544
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	470		466
Deferred credits related to income taxes	247		253
Employee benefit obligations	69		69
Asset retirement obligations, deferred	143		142
Other cost of removal obligations	196		196
Other regulatory liabilities, deferred	84		96
Other deferred credits and liabilities	26		21
Total deferred credits and other liabilities	1,235		1,243
Total Liabilities	3,273		3,341
Common Stockholder's Equity (See accompanying statements)	1,943		1,931
Total Liabilities and Stockholder's Equity	$	5,216	$	5,272

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

29

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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)		Total
	(in millions)
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
Balance at December 31, 2022	1	$	38	$	4,652	$	(2,759)	$	1,931
Net income	—	—		—		58		58
Cash dividends on common stock	—	—		—		(46)		(46)
Balance at March 31, 2023	1	$	38	$	4,652	$	(2,747)	$	1,943

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

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    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Revenues:
Wholesale revenues, non-affiliates	$	362	$	426
Wholesale revenues, affiliates	135		105
Other revenues	11		8
Total operating revenues	508		539
Operating Expenses:
Fuel	191		232
Purchased power	26		21
Other operations and maintenance	107		105
Depreciation and amortization	128		120
Taxes other than income taxes	13		13
Gain on dispositions, net	(20)		(2)
Total operating expenses	445		489
Operating Income	63		50
Other Income and (Expense):
Interest expense, net of amounts capitalized	(33)		(37)
Other income (expense), net	2		2
Total other income and (expense)	(31)		(35)
Earnings Before Income Taxes	32		15
Income taxes (benefit)	(7)		(12)
Net Income	39		27
Net loss attributable to noncontrolling interests	(63)		(45)
Net Income Attributable to Southern Power	$	102	$	72

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Net Income	$	39	$	27
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(3) and $(6), respectively	(8)		(17)
Reclassification adjustment for amounts included in net income,    net of tax of $— and $7, respectively	1		22
Total other comprehensive income (loss)	(7)		5
Comprehensive Income	32		32
Comprehensive loss attributable to noncontrolling interests	(63)		(45)
Comprehensive Income Attributable to Southern Power	$	95	$	77

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

31

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SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Activities:
Net income	$	39	$	27
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	133		126
Deferred income taxes	3		12
Amortization of investment tax credits	(15)		(15)
Gain on dispositions, net	(20)		(2)
Other, net	(14)		(3)
Changes in certain current assets and liabilities —
-Receivables	120		11
-Prepaid income taxes	15		(8)
-Other current assets	(13)		—
-Accounts payable	(92)		(21)
-Accrued compensation	(13)		(13)
-Other current liabilities	(8)		3
Net cash provided from operating activities	135		117
Investing Activities:
Property additions	(11)		(19)
Proceeds from dispositions	46		29
Change in construction payables	(15)		(31)
Payments pursuant to LTSAs	(16)		(15)
Other investing activities	—		(1)
Net cash provided from (used for) investing activities	4		(37)
Financing Activities:
Decrease in notes payable, net	(59)		(3)
Capital contributions from noncontrolling interests	21		73
Distributions to noncontrolling interests	(48)		(97)
Payment of common stock dividends	(63)		(49)
Other financing activities	3		—
Net cash used for financing activities	(146)		(76)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(7)		4
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	133		135
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	126	$	139
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest	$	30	$	29
Income taxes, net	(9)		(8)
Noncash transactions —
Accrued property additions at end of period	12		46
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.

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SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2023		At December 31, 2022
	(in millions)
Current Assets:
Cash and cash equivalents	$	123	$	131
Receivables —
Customer accounts, net	133		226
Affiliated	39		51
Other	71		70
Materials and supplies	85		88
Prepaid income taxes	291		5
Other current assets	59		50
Total current assets	801		621
Property, Plant, and Equipment:
In service	14,635		14,658
Less: Accumulated provision for depreciation	3,760		3,661
Plant in service, net of depreciation	10,875		10,997
Construction work in progress	43		41
Total property, plant, and equipment	10,918		11,038
Other Property and Investments:
Intangible assets, net of amortization of $134 and $129, respectively	258		263
Equity investments in unconsolidated subsidiaries	—		49
Net investment in sales-type leases	152		154
Total other property and investments	410		466
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	487		489
Prepaid LTSAs	208		193
Other deferred charges and assets	310		274
Total deferred charges and other assets	1,005		956
Total Assets	$	13,134	$	13,081

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

33

    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholders' Equity	At March 31, 2023		At December 31, 2022
	(in millions)
Current Liabilities:
Securities due within one year	$	291	$	290
Notes payable	165		225
Accounts payable —
Affiliated	71		139
Other	31		67
Accrued taxes	22		24
Accrued interest	27		28
Other current liabilities	90		111
Total current liabilities	697		884
Long-term Debt	2,700		2,689
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	581		279
Accumulated deferred ITCs	1,541		1,556
Operating lease obligations	510		514
Other deferred credits and liabilities	247		243
Total deferred credits and other liabilities	2,879		2,592
Total Liabilities	6,276		6,165
Total Stockholders' Equity (See accompanying statements)	6,858		6,916
Total Liabilities and Stockholders' Equity	$	13,134	$	13,081

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

34

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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, 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

Balance at December 31, 2022	$	1,069	$	1,741	$	(18)	$	2,792	$	4,124	$	6,916
Net income (loss)	—		102		—		102		(63)		39
Other comprehensive income (loss)	—		—		(7)		(7)		—		(7)
Cash dividends on common stock	—		(63)		—		(63)		—		(63)
Capital contributions from    noncontrolling interests	—		—		—		—		21		21
Distributions to noncontrolling interests	—		—		—		—		(48)		(48)
Balance at March 31, 2023	$	1,069	$	1,780	$	(25)	$	2,824	$	4,034	$	6,858

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 March 31,
	2023		2022
	(in millions)
Operating Revenues:
Natural gas revenues (includes revenue taxes of $66 and $71, respectively)	$	1,875	$	2,058
Total operating revenues	1,875		2,058
Operating Expenses:
Cost of natural gas	898		1,095
Other operations and maintenance	305		305
Depreciation and amortization	141		137
Taxes other than income taxes	102		100
Total operating expenses	1,446		1,637
Operating Income	429		421
Other Income and (Expense):
Earnings from equity method investments	45		40
Interest expense, net of amounts capitalized	(76)		(61)
Other income (expense), net	14		16
Total other income and (expense)	(17)		(5)
Earnings Before Income Taxes	412		416
Income taxes	103		97
Net Income	$	309	$	319

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Net Income	$	309	$	319
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(10) and $10, respectively	(24)		26
Reclassification adjustment for amounts included in net income,     net of tax of $6 and $(2), respectively	14		(6)
Total other comprehensive income (loss)	(10)		20
Comprehensive Income	$	299	$	339

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

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    Table of Contents                                Index to Financial Statements

SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Operating Activities:
Net income	$	309	$	319
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	141		137
Deferred income taxes	27		5
Mark-to-market adjustments	13		(38)
Natural gas cost under recovery – long-term	—		162
Other, net	(15)		41
Changes in certain current assets and liabilities —
-Receivables	266		(115)
-Natural gas for sale, net of temporary LIFO liquidation	267		450
-Prepaid income taxes	33		34
-Other current assets	90		(1)
-Accounts payable	(303)		(23)
-Accrued taxes	36		54
-Natural gas cost over recovery	117		—
-Other current liabilities	(3)		(1)
Net cash provided from operating activities	978		1,024
Investing Activities:
Property additions	(299)		(247)
Cost of removal, net of salvage	(24)		(20)
Change in construction payables, net	(53)		(5)
Other investing activities	(3)		1
Net cash used for investing activities	(379)		(271)
Financing Activities:
Decrease in notes payable, net	(448)		(577)
Redemptions — Short-term borrowings	(200)		(100)
Capital contributions from parent company	192		39
Payment of common stock dividends	(146)		(130)
Other financing activities	9		—
Net cash used for financing activities	(593)		(768)
Net Change in Cash, Cash Equivalents, and Restricted Cash	6		(15)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	83		48
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	89	$	33
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $4 and $2 capitalized for 2023 and 2022, respectively)	$	76	$	55
Noncash transactions — Accrued property additions at end of period	124		107

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 March 31, 2023		At December 31, 2022
	(in millions)
Current Assets:
Cash and cash equivalents	$	88	$	81
Receivables —
Customer accounts	586		616
Unbilled revenues	218		453
Other accounts and notes	73		76
Accumulated provision for uncollectible accounts	(58)		(50)
Natural gas for sale	216		438
Prepaid expenses	74		93
Natural gas cost under recovery	—		108
Other regulatory assets	126		119
Other current assets	118		104
Total current assets	1,441		2,038
Property, Plant, and Equipment:
In service	19,918		19,723
Less: Accumulated depreciation	5,350		5,276
Plant in service, net of depreciation	14,568		14,447
Construction work in progress	996		909
Total property, plant, and equipment	15,564		15,356
Other Property and Investments:
Goodwill	5,015		5,015
Equity investments in unconsolidated subsidiaries	1,282		1,276
Other intangible assets, net of amortization of $159 and $156, respectively	23		26
Miscellaneous property and investments	29		28
Total other property and investments	6,349		6,345
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	55		57
Prepaid pension costs	190		183
Other regulatory assets, deferred	478		497
Other deferred charges and assets	145		145
Total deferred charges and other assets	868		882
Total Assets	$	24,222	$	24,621

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

38

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SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2023		At December 31, 2022
	(in millions)
Current Liabilities:
Securities due within one year	$	401	$	400
Notes payable	120		768
Accounts payable —
Affiliated	91		104
Other	361		701
Customer deposits	99		125
Accrued taxes	113		77
Accrued interest	69		67
Accrued compensation	68		105
Temporary LIFO liquidation	45		—
Natural gas cost over recovery	117		—
Other regulatory liabilities	104		36
Other current liabilities	208		187
Total current liabilities	1,796		2,570
Long-term Debt	7,055		7,042
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,583		1,560
Deferred credits related to income taxes	781		788
Employee benefit obligations	112		120
Operating lease obligations	50		51
Other cost of removal obligations	1,725		1,707
Accrued environmental remediation	200		207
Other deferred credits and liabilities	167		179
Total deferred credits and other liabilities	4,618		4,612
Total Liabilities	13,469		14,224
Common Stockholder's Equity (See accompanying statements)	10,753		10,397
Total Liabilities and Stockholder's Equity	$	24,222	$	24,621

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

39

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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, 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
Balance at December 31, 2022	$	10,445	$	(79)	$	31	$	10,397
Net income	—		309		—		309
Capital contributions from parent company	203		—		—		203
Other comprehensive income (loss)	—		—		(10)		(10)
Cash dividends on common stock	—		(146)		—		(146)
Other	1		(1)		—		—
Balance at March 31, 2023	$	10,649	$	83	$	21	$	10,753

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

40

    Table of Contents                                Index to Financial Statements

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

FOR

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

ALABAMA POWER COMPANY

GEORGIA POWER COMPANY

MISSISSIPPI POWER COMPANY

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

(UNAUDITED)

INDEX TO THE NOTES TO THE CONDENSED FINANCIAL STATEMENTS

Note		Page
A	Introduction	42
B	Regulatory Matters	45
C	Contingencies	53
D	Revenue from Contracts with Customers and Lease Income	57
E	Consolidated Entities and Equity Method Investments	60
F	Financing and Leases	63
G	Income Taxes	65
H	Retirement Benefits	66
I	Fair Value Measurements	69
J	Derivatives	74
K	Segment and Related Information	86

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
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
Southern Company Gas	A, B, C, D, E, F, G, H, I, J, K

41

    Table of Contents                                Index to Financial Statements

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

(UNAUDITED)

(A) INTRODUCTION

The condensed quarterly financial statements of each Registrant included herein have been prepared by such Registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets at December 31, 2022 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 March 31, 2023 and 2022. 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 March 31, 2023 and December 31, 2022 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,161
Southern Company Gas:
Gas distribution operations	$	4,034
Gas marketing services	981
Southern Company Gas total	$	5,015

Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if impairment indicators arise.

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Other intangible assets were as follows:

	At March 31, 2023						At December 31, 2022
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Subject to amortization:
Customer relationships	$	212	$	(164)	$	48	$	212	$	(162)	$	50
Trade names	64		(47)		17		64		(44)		20
PPA fair value adjustments	390		(134)		256		390		(129)		261
Other	6		(5)		1		5		(5)		—
Total subject to amortization	$	672	$	(350)	$	322	$	671	$	(340)	$	331
Not subject to amortization:
FCC licenses	75		—		75		75		—		75
Total other intangible assets	$	747	$	(350)	$	397	$	746	$	(340)	$	406
Southern Power(*)
PPA fair value adjustments	$	390	$	(134)	$	256	$	390	$	(129)	$	261
Southern Company Gas(*)
Gas marketing services
Customer relationships	$	156	$	(140)	$	16	$	156	$	(139)	$	17
Trade names	26		(19)		7		26		(17)		9
Total other intangible assets	$	182	$	(159)	$	23	$	182	$	(156)	$	26

(*) All subject to amortization.

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2023		March 31, 2022
	(in millions)
Southern Company(a)	$	10	$	10
Southern Power(b)	5		5
Southern Company Gas	3		3

(a)Includes $5 million recorded as a reduction to operating revenues for both periods presented.

(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:

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	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
At March 31, 2023
Cash and cash equivalents	$	1,053	$	—	$	123	$	88
Restricted cash(a):
Other current assets	117		115		—		2
Other deferred charges and assets	47		45		3		—
Total cash, cash equivalents, and restricted cash(b)	$	1,217	$	160	$	126	$	89
At December 31, 2022
Cash and cash equivalents	$	1,917	$	364	$	131	$	81
Restricted cash(a):
Other current assets	62		60		—		2
Other deferred charges and assets	58		56		3		—
Total cash, cash equivalents, and restricted cash(b)	$	2,037	$	480	$	133	$	83

(a)For Georgia Power, reflects $116 million at both March 31, 2023 and December 31, 2022 related to proceeds from the issuance of solid waste disposal facility revenue bonds in 2022 and $44 million at March 31, 2023 related to funds from a Georgia Housing and Finance Authority (GHFA) rental assistance program used to offset qualifying customers' past due balances, which expired on March 31, 2023 and will be returned to the GHFA. For Southern Power, reflects $3 million at both March 31, 2023 and December 31, 2022 held to fund estimated construction completion costs at the Deuel Harvest wind facility. 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 March 31, 2023 is expected to be restored prior to year-end.

Storm Damage Reserves

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

Storm damage reserve activity for the traditional electric operating companies during the three months ended March 31, 2023 was as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power
	(in millions)
Balance at December 31, 2022	$	216	$	97	$	83	$	36
Accrual	13		3		8		2
Weather-related damages	(43)		(12)		(31)		—
Balance at March 31, 2023	$	186	$	88	$	60	$	38

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Asset Retirement Obligations

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

Following initial criticality on March 6, 2023, Georgia Power recorded AROs of approximately $90 million related to Plant Vogtle Unit 3. See Note (B) under "Georgia Power – Nuclear Construction" for additional information on construction and start-up of Plant Vogtle Units 3 and 4.

(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 March 31, 2023 and December 31, 2022 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2023		December 31, 2022
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, current	$	23	$	47
	Other regulatory assets, deferred	18		—
Rate CNP PPA	Other regulatory assets, current	17		18
	Other regulatory assets, deferred	100		102
Retail Energy Cost Recovery	Other regulatory assets, current	101		102
	Other regulatory assets, deferred	420		520
Georgia Power
Fuel Cost Recovery(*)	Receivables – under recovered fuel clause revenues	$	447	$	—
	Deferred under recovered fuel clause revenues	1,702		2,056
Mississippi Power
Fuel Cost Recovery	Receivables – customer accounts, net	$	25	$	1
Ad Valorem Tax	Other regulatory assets, current	9		12
	Other regulatory assets, deferred	19		19
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	—	$	108
	Natural gas cost over recovery	117		—

(*)See "Georgia Power – Fuel Cost Recovery" herein for additional information.

Alabama Power

Certificates of Convenience and Necessity

In 2020, the Alabama PSC approved a certificate of convenience and necessity authorizing Alabama Power's construction of Plant Barry Unit 8 and the recovery of estimated actual in-service costs of $652 million. At March 31, 2023, project expenditures associated with Plant Barry Unit 8 totaled approximately $541 million, of which $536 million and $5 million was included in CWIP and property, plant, and equipment in service, respectively. The unit is expected to be placed in service in November 2023. The ultimate outcome of this matter cannot be determined at this time.

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Rate CNP New Plant

On March 24, 2023, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover costs associated with the acquisition of the Central Alabama Generating Station. The filing reflected an annual increase in retail revenues of $78 million effective with June 2023 billings. Through May 2023, Alabama Power expects to recover substantially all costs associated with the Central Alabama Generating Station through Rate RSE, offset by revenues from 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.

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. On April 4, 2023, the Alabama PSC approved two new solar PPAs totaling 160 MWs. Alabama Power has procured solar capacity totaling approximately 490 MWs under the RGC.

Georgia Power

Fuel Cost Recovery

On February 28, 2023, Georgia Power filed a request with the Georgia PSC to increase fuel rates. On April 13, 2023, Georgia Power and the staff of the Georgia PSC reached a stipulated agreement that includes the following terms: (i) Georgia Power would update fuel rates from the original request for revised fuel costs and to reflect a three-year recovery period, starting June 1, 2023, for $2.2 billion of the under recovered fuel balance and (ii) Georgia Power would be required to file its next fuel case no later than February 28, 2026. On April 24, 2023, Georgia Power filed an updated request reflecting a 54% increase in fuel rates effective June 1, 2023, which is expected to increase annual billings by approximately $1.1 billion and includes recovery of the under recovered fuel balance described above. Changes in fuel rates have no significant effect on Georgia Power's net income but do impact the related operating cash flows. Georgia Power expects the Georgia PSC to make a final decision on this matter on May 16, 2023. The ultimate outcome of this matter cannot be determined at this time.

Integrated Resource Plans

In August 2022, Restore Chattooga Gorge Coalition (RCG) filed a petition in the Superior Court of Fulton County, Georgia against Georgia Power and the Georgia PSC. The petition challenges Georgia Power's plan to expend $115 million to modernize Plant Tugalo, as approved in the 2019 IRP, and seeks judicial review of the Georgia PSC's order in the 2022 IRP proceeding with respect to the denial of RCG's challenge to the modernization plan. In November 2022, Georgia Power and the Georgia PSC both filed motions to dismiss the RCG petition. The ultimate outcome of this matter 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 currently 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

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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 second quarter 2023 and the first quarter 2024, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,553
Construction contingency estimate	40
Total project capital cost forecast(a)(b)	10,593
Net investment at March 31, 2023(b)	(9,747)
Remaining estimate to complete	$	846

(a)Includes approximately $610 million of costs that are not shared with the other Vogtle Owners, including $33 million of construction monitoring costs approved for recovery by the Georgia PSC in its nineteenth VCM order, and approximately $407 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 $418 million, of which $334 million had been accrued through March 31, 2023.

(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 $3.5 billion, of which $3.3 billion had been incurred through March 31, 2023.

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 start-up testing and related test results, engineering support, commodity installation, system turnovers, 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 plans. As of March 31, 2023, 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. Future COVID-19 variants could further disrupt or delay construction and testing activities.

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On March 6, 2023, Unit 3 achieved self-sustaining nuclear fission, commonly referred to as initial criticality, and, on April 1, 2023, the generator successfully synchronized to the power grid and generated electricity for the first time. Operators continue to perform tests at various power levels to help ensure the reactor performs as designed, and Southern Nuclear continues to remediate various equipment and component issues as they are identified. Based on the expected duration of start-up testing, Unit 3 is projected to be placed in service during May or June 2023. Hot functional testing for Unit 4 commenced on March 20, 2023, with fuel load projected to occur in the third quarter 2023. Unit 4 is projected to be placed in service during late fourth quarter 2023 or the first quarter 2024.

During the first quarter 2023, established construction contingency totaling $20 million was assigned to the base capital cost forecast for costs primarily associated with additional craft and support resources.

The projected schedule for Unit 3 primarily depends on the progression of pre-operational testing and start-up, which may be impacted by further equipment, component, and/or other operational challenges. The projected schedule for Unit 4 primarily depends on potential impacts arising from Unit 4 testing activities overlapping with Unit 3 start-up and commissioning; maintaining overall construction productivity and production levels, particularly in subcontractor scopes of work; and maintaining appropriate levels of craft laborers. As Unit 4 completes construction and transitions further into testing, ongoing and potential future challenges include the duration of hot functional testing; the timeframe and duration of other testing; the pace and quality of remaining commodities installation; the completion of documentation to support ITAAC submittals; the pace of remaining work package closures and system turnovers; and the availability of craft, supervisory, and technical support resources. Ongoing or future challenges for both units also include management of contractors and vendors; subcontractor performance; and/or related cost escalation. New challenges also may continue to arise, as Unit 3 completes start-up and commissioning and Unit 4 moves further into 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). These challenges may result in further schedule delays and/or cost increases.

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. 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. With the receipt of the NRC's 103(g) finding in August 2022, Unit 3 is now subject to the NRC's operating reactor oversight process and must meet applicable technical and operational requirements contained in its operating license. Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC documentation and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel for Unit 4, may arise, which may result in additional license amendment requests or require other resolution. If any license amendment requests or other licensing-based compliance issues, including inspections and ITAACs for Unit 4, 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 second quarter 2023 for Unit 3 or the first quarter 2024 for Unit 4, including the joint owner cost sharing and tender impacts described below, is estimated to result in additional base capital costs for Georgia Power of up to $15 million per month for Unit 3 and $35 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.

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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, of which Georgia Power's share is $8.4 billion (VCM 19 Forecast Amount), 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 VCM 19 Forecast Amount (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 VCM 19 Forecast Amount (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. The Global Amendments provide that if the EAC is revised and exceeds the VCM 19 Forecast Amount 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 VCM 19 Forecast Amount 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 (Project 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

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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 and all the Vogtle Owners 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. The other Vogtle Owners notified Georgia Power that they believe the project capital cost forecast approved by the Vogtle Owners in February 2022 triggered the tender provisions. In June 2022 and July 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. Georgia Power did not accept these purported tender exercises.

In June 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 had 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. In July 2022, Georgia Power filed its answers in the lawsuits filed by MEAG Power and OPC 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. In September 2022, Dalton filed complaints in each of these lawsuits. Also in September 2022, Georgia Power and MEAG Power reached an agreement to resolve their dispute regarding the proper interpretation of the cost-sharing and tender provisions of the Global Amendments. Under the terms of the agreement, among other items, (i) MEAG Power will not exercise its tender option and will retain its full ownership interest in Plant Vogtle Units 3 and 4; (ii) Georgia Power will reimburse a portion of MEAG Power's costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs, which payments will total approximately $92 million based on the current project capital cost forecast; and (iii) Georgia Power will reimburse 20% of MEAG Power's costs of construction with respect to any amounts over the current project capital cost forecast, with no further adjustment for force majeure costs. In addition, MEAG Power agreed to vote to continue construction upon occurrence of a Project Adverse Event unless the commercial operation date of either of Plant Vogtle Unit 3 or Unit 4 is not projected to occur by December 31, 2025. In October 2022, MEAG Power and Georgia Power filed a notice of settlement and voluntary dismissal of their pending litigation, including Georgia Power's counterclaim, and Dalton dismissed its related complaint.

Georgia Power recorded pre-tax charges to income through the fourth quarter 2022 of $407 million ($304 million after tax) associated with the cost-sharing and tender provisions of the Global Amendments, including the settlement with MEAG Power. This total is included in the total project capital cost forecast and will not be recovered from retail customers. The settlement with MEAG Power does not resolve the separate pending litigation with OPC, including Dalton's associated complaint, described above. Georgia Power may be required to record further pre-tax charges to income of up to approximately $345 million associated with the cost-sharing and tender provisions of the Global Amendments for OPC and Dalton based on the current project capital cost forecast.

Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%. Georgia Power believes the increases in the total project capital cost forecast through December 31, 2022 triggered the tender provisions, but Georgia Power disagrees with OPC and Dalton on the tender provisions trigger date. Valid notices of tender from OPC and Dalton would require Georgia Power to pay 100% of their respective remaining shares of the costs

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necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest will 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 March 31, 2023, Georgia Power had recovered approximately $2.9 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 December 2022, the Georgia PSC approved Georgia Power's filing to increase the NCCR tariff by $36 million annually, effective January 1, 2023.

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 at that time) 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

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(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 $300 million in 2022 and are estimated to have negative earnings impacts of approximately $270 million in 2023 and $60 million in 2024. 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 also has reviewed two additional VCM reports, which reflected $1.1 billion of additional construction capital costs incurred through June 30, 2022. Georgia Power filed its twenty-eighth VCM report with the Georgia PSC on February 16, 2023, which reflected the revised capital cost forecast described above and $461 million of construction capital costs incurred from July 1, 2022 through December 31, 2022.

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

Mississippi Power

Performance Evaluation Plan

On March 15, 2023, Mississippi Power submitted its annual retail PEP filing for 2023 to the Mississippi PSC indicating no change in retail rates. The ultimate outcome of this matter cannot be determined at this time.

Ad Valorem Tax Adjustment

On March 31, 2023, Mississippi Power submitted its annual ad valorem tax adjustment filing for 2023, which requested a $7 million annual decrease in revenues. The ultimate outcome of this matter cannot be determined at this time.

Environmental Compliance Overview Plan

On April 4, 2023, the Mississippi PSC approved Mississippi Power's annual ECO Plan filing, resulting in a $3 million annual increase in revenues effective with the first billing cycle of May 2023.

System Restoration Rider

On April 4, 2023, the Mississippi PSC approved Mississippi Power's annual SRR filing, which indicated no change in retail rates. Mississippi Power's minimum annual SRR accrual was increased from $8 million to $12 million.

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Southern Company Gas

Infrastructure Replacement Programs and Capital Projects

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first three months of 2023 were as follows:

Utility	Program	Three Months Ended March 31, 2023
		(in millions)
Nicor Gas	Investing in Illinois	$	62
Virginia Natural Gas	SAVE	20
Atlanta Gas Light	System Reinforcement Rider	32
Chattanooga Gas	Pipeline Replacement Program	1
Total		$	115

(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.

Alabama Power

In September 2022, Mobile Baykeeper filed a citizen suit in the U.S. District Court for the Southern District of Alabama alleging that Alabama Power's plan to close the Plant Barry ash pond utilizing a closure-in-place methodology violates the Resource Conservation and Recovery Act (RCRA) and regulations governing CCR. Among other relief requested, Mobile Baykeeper seeks a declaratory judgment that the RCRA and regulations governing CCR are being violated, preliminary and injunctive relief to prevent implementation of Alabama Power's closure plan and the development of a closure plan that satisfies regulations governing CCR requirements. On December 19, 2022, Alabama Power filed a motion to dismiss the case. On January 31, 2023, the EPA issued a Notice of Potential Violations associated with Alabama Power's plan to close the Plant Barry ash pond. Alabama Power submitted responses on March 20, 2023, March 24, 2023, and April 3, 2023 affirming its position that it is in compliance with CCR requirements. The ultimate outcome of these matters cannot be determined at this time but could have an impact on Alabama Power's ARO estimates. See Note 6 to the financial statements in Item 8 of the Form 10-K for a discussion of Alabama Power's ARO liabilities.

Georgia Power

Municipal Franchise Fees

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

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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, which was denied on January 27, 2023. On February 6, 2023, the plaintiffs filed a motion for reconsideration with the Georgia Supreme Court, which was denied on February 16, 2023. This matter is now concluded.

Plant Scherer

In July 2020, a group of individual plaintiffs filed a complaint, which was amended in December 2022, in the Superior Court of Fulton County, Georgia against Georgia Power alleging that the construction and operation of Plant Scherer has impacted groundwater 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 December 2022, the Superior Court of Fulton County, Georgia granted Georgia Power's motion to transfer the case to the Superior Court of Monroe County, Georgia.

In October 2021 and February 2022, a total of seven 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 sought an unspecified amount of monetary damages including punitive damages. In November 2021 and March 2022, Georgia Power removed these cases to the U.S. District Court for the Middle District of Georgia. In November 2022, the plaintiffs voluntarily dismissed their complaints without prejudice. Georgia Power anticipates that these plaintiffs will refile their complaints.

On January 9, 2023, an additional complaint was filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that the construction and operation of Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries. The plaintiff sought an unspecified amount of monetary damages, including punitive damages. On January 19, 2023, Georgia Power filed a notice to remove the case to the U.S. District Court for the Middle District of Georgia. On February 21, 2023, the plaintiff voluntarily dismissed the complaint without prejudice. Georgia Power anticipates that this plaintiff will refile the complaint.

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

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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. In March 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. In May 2022, the U.S. Court of Appeals for the Fifth Circuit denied a petition by Mississippi Power for a rehearing en banc and remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. In June 2022, Mississippi Power filed with the trial court a motion to dismiss the complaint with prejudice, which was granted on March 15, 2023. On March 28, 2023, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. 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 $15 million at both March 31, 2023 and December 31, 2022. 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 $243 million and $256 million at March 31, 2023 and December 31, 2022, 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

Traditional Electric Operating Companies

In April 2019, Bellsouth Telecommunications d/b/a AT&T Alabama (AT&T) filed a complaint against Alabama Power with the FCC alleging that the pole rental rate AT&T is required to pay pursuant to the parties' joint use agreement is unjust and unreasonable under federal law. The complaint sought a new rate and approximately $87 million in refunds of alleged overpayments for the preceding six years. In August 2019, the FCC stayed the case in favor of arbitration, which AT&T has not pursued. The ultimate outcome of this matter cannot be determined at this time, but an adverse outcome could have a material impact on the financial statements of Southern Company and Alabama Power. Georgia Power and Mississippi Power have joint use agreements with other AT&T affiliates.

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Mississippi Power

In August 2022, the Mississippi Department of Revenue (Mississippi DOR) completed an audit of sales and use taxes paid by Mississippi Power from 2016 to 2019 and entered a final assessment, indicating a total amount due of $28 million, including associated penalties and interest. Additional interest of approximately $1 million was estimated through March 31, 2023. Mississippi Power does not agree with the audit findings and, in October 2022, filed an administrative appeal with the Mississippi DOR. See Note 3 to the financial statements in Item 8 of the Form 10-K under "Other Matters – Mississippi Power – Department of Revenue Audit" for information regarding a Mississippi PSC accounting order related to the tax audit proceeding. The ultimate outcome of this matter cannot be determined at this time.

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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 months ended March 31, 2023 and 2022:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2023
Operating revenues
Retail electric revenues
Residential	$	1,525	$	659	$	801	$	65	$	—	$	—
Commercial	1,251		430		753		68		—		—
Industrial	789		398		313		78		—		—
Other	27		3		22		2		—		—
Total retail electric revenues	3,592		1,490		1,889		213		—		—
Natural gas distribution revenues
Residential	896		—		—		—		—		896
Commercial	232		—		—		—		—		232
Transportation	319		—		—		—		—		319
Industrial	23		—		—		—		—		23
Other	117		—		—		—		—		117
Total natural gas distribution revenues	1,587		—		—		—		—		1,587
Wholesale electric revenues
PPA energy revenues	284		72		12		4		202		—
PPA capacity revenues	190		60		11		32		89		—
Non-PPA revenues	36		20		3		107		103		—
Total wholesale electric revenues	510		152		26		143		394		—
Other natural gas revenues
Gas marketing services	231		—		—		—		—		231
Other natural gas revenues	11		—		—		—		—		11
Total natural gas revenues	242		—		—		—		—		242
Other revenues	310		54		132		11		11		—
Total revenue from contracts with customers	6,241		1,696		2,047		367		405		1,829
Other revenue sources(*)	239		(49)		129		23		103		46
Total operating revenues	$	6,480	$	1,647	$	2,176	$	390	$	508	$	1,875

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Operating revenues
Retail electric revenues
Residential	$	1,525	$	634	$	821	$	70	$	—	$	—
Commercial	1,178		375		738		65		—		—
Industrial	727		323		334		70		—		—
Other	26		4		20		2		—		—
Total retail electric revenues	3,456		1,336		1,913		207		—		—
Natural gas distribution revenues
Residential	1,016		—		—		—		—		1,016
Commercial	270		—		—		—		—		270
Transportation	337		—		—		—		—		337
Industrial	32		—		—		—		—		32
Other	129		—		—		—		—		129
Total natural gas distribution revenues	1,784		—		—		—		—		1,784
Wholesale electric revenues
PPA energy revenues	342		59		32		3		251		—
PPA capacity revenues	134		39		12		3		81		—
Non-PPA revenues	58		64		9		102		73		—
Total wholesale electric revenues	534		162		53		108		405		—
Other natural gas revenues
Gas marketing services	243		—		—		—		—		243
Other natural gas revenues	16		—		—		—		—		16
Total natural gas revenues	259		—		—		—		—		259
Other revenues	225		48		95		9		8		—
Total revenue from contracts with customers	6,258		1,546		2,061		324		413		2,043
Other revenue sources(*)	390		103		147		11		126		15
Total operating revenues	$	6,648	$	1,649	$	2,208	$	335	$	539	$	2,058

(*)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.

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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 March 31, 2023 and December 31, 2022:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At March 31, 2023	$	2,433	$	622	$	672	$	79	$	119	$	853
At December 31, 2022	3,123		696		922		92		237		1,107
Contract Assets
At March 31, 2023	$	160	$	3	$	74	$	—	$	—	$	19
At December 31, 2022	156		2		89		—		—		—
Contract Liabilities
At March 31, 2023	$	61	$	2	$	14	$	1	$	1	$	—
At December 31, 2022	45		4		9		—		1		—

Contract assets for Georgia Power primarily relate 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 primarily relate to cash collections recognized in advance of revenue for unregulated service agreements. At March 31, 2023, Southern Company Gas' contract assets relate to work performed on an energy efficiency enhancement and upgrade contract with the U.S. General Services Administration. Southern Company Gas receives cash advances from a third-party financial institution to fund work performed, of which approximately $30 million had been received at March 31, 2023. These advances have been accounted for as long-term debt on the balance sheets. See Note 1 to the financial statements under "Affiliate Transactions" in Item 8 of the Form 10-K for additional information regarding the construction contract. At March 31, 2023 and December 31, 2022, Southern Company's unregulated distributed generation business had contract assets of $64 million and $65 million, respectively, and contract liabilities of $44 million and $32 million, respectively, for outstanding performance obligations.

Revenues recognized in the three months ended March 31, 2023, which were included in contract liabilities at December 31, 2022, were $19 million for Southern Company and immaterial for the other Registrants.

Remaining Performance Obligations

The Subsidiary Registrants may enter into long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. For Alabama Power, Georgia Power, 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 primarily relate to the U.S. General Services Administration contract described above. 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 March 31, 2023 are expected to be recognized as follows:

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	2023 (remaining)		2024		2025		2026		2027		Thereafter
	(in millions)
Southern Company	$	632	$	553	$	347	$	315	$	319	$	2,089
Alabama Power	17		7		6		—		—		—
Georgia Power	68		60		25		13		14		23
Southern Power	268		345		302		303		310		2,077
Southern Company Gas	15		29		—		—		—		—

Lease Income

Lease income for the three months ended March 31, 2023 and 2022 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended March 31, 2023
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	49		18		7		1		21		9
Variable lease income	69		—		—		—		75		—
Total lease income	$	124	$	18	$	7	$	5	$	98	$	9
For the Three Months Ended March 31, 2022
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	51		20		8		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	141	$	20	$	8	$	4	$	113	$	9

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 Company

At March 31, 2023 and December 31, 2022, Southern Holdings had equity method investments totaling $120 million and $112 million, respectively, primarily related to investments in venture capital funds focused on energy and utility investments. Earnings from these investments were immaterial for both periods presented.

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.

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SP Solar and SP Wind

At March 31, 2023 and December 31, 2022, SP Solar had total assets of $5.8 billion and $5.9 billion, respectively, total liabilities of $0.4 billion, and noncontrolling interests of $1.0 billion and $1.1 billion, respectively. 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 March 31, 2023 and December 31, 2022, SP Wind had total assets of $2.2 billion, total liabilities of $172 million and $169 million, respectively, and noncontrolling interests of $39 million. 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 March 31, 2023 and December 31, 2022, the other VIEs had total assets of $1.8 billion, total liabilities of $0.2 billion, and noncontrolling interests of $0.8 billion. 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 December 31, 2022, Southern Power had equity method investments in wind and battery energy storage projects totaling $49 million. During the first quarter 2023, Southern Power sold its remaining equity method investments in the projects and received proceeds of $50 million. Earnings (loss) from these investments, including the gains associated with the sales, were immaterial for the three months ended March 31, 2023 and 2022.

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Southern Company Gas

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at March 31, 2023 and December 31, 2022 and related earnings from those investments for the three months ended March 31, 2023 and 2022 were as follows:

Investment Balance	March 31, 2023		December 31, 2022
	(in millions)
SNG	$	1,249	$	1,243
Other	33		33
Total	$	1,282	$	1,276

	Three Months Ended March 31,
Earnings from Equity Method Investments	2023		2022
	(in millions)
SNG	$	44	$	39
Other	1		1
Total	$	45	$	40

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(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 March 31, 2023, 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		225		—
Southern Power(a)	—		—		—		600		600		587		—
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	$	7,564	$	280

(a)Does not include Southern Power Company's $75 million and $100 million continuing letter of credit facilities for standby letters of credit, expiring in 2025 and 2026, respectively, of which $9 million and $16 million, respectively, was unused at March 31, 2023. In March 2023, Southern Power amended the $100 million letter of credit facility, which, among other things, extended the expiration date from 2025 to 2026 and increased the amount from $75 million. 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 under a $250 million credit arrangement expiring in 2023.

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 March 31, 2023, 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 March 31, 2023 was approximately $1.7 billion (comprised of approximately $789 million at Alabama Power, $819 million at Georgia Power, and $69 million at Mississippi Power). In addition, at March 31, 2023, Alabama Power and Georgia Power had approximately $120 million and $285 million, respectively, of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

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Convertible Senior Notes

In February 2023, Southern Company issued $1.5 billion aggregate principal amount of Series 2023A 3.875% Convertible Senior Notes due December 15, 2025 (Series 2023A Convertible Senior Notes). In March 2023, Southern Company issued an additional $225 million aggregate principal amount of the Series 2023A Convertible Senior Notes upon the exercise by the initial purchasers of their over-allotment option.

Interest on the Series 2023A Convertible Senior Notes is payable semiannually, beginning June 15, 2023. The Series 2023A Convertible Senior Notes will mature on December 15, 2025, unless earlier converted or repurchased, but are not redeemable at the option of Southern Company. The Series 2023A Convertible Senior Notes are direct, unsecured, and unsubordinated obligations of Southern Company, ranking equally with all of Southern Company's other unsecured and unsubordinated indebtedness from time to time outstanding, and are effectively subordinated to all secured indebtedness of Southern Company.

Holders may convert their Series 2023A Convertible Senior Notes at their option prior to the close of business on the business day preceding September 15, 2025, but only under the following circumstances:

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

•during the five business day period after any 10 consecutive trading day period (Measurement Period) in which the trading price per $1,000 principal amount of Series 2023A Convertible Senior Notes for each trading day of the Measurement Period was less than 98% of the product of the last reported sale price of the common stock and the conversion rate on each such trading day; or

•upon the occurrence of certain corporate events specified in the indenture governing the Series 2023A Convertible Senior Notes.

On or after September 15, 2025, a holder may convert all or any portion of its Series 2023A Convertible Senior Notes at any time prior to the close of business on the second scheduled trading day immediately preceding the maturity date regardless of the foregoing conditions.

Southern Company will settle conversions of the Series 2023A Convertible Senior Notes by paying cash up to the aggregate principal amount of the Series 2023A Convertible Senior Notes to be converted and paying or delivering, as the case may be, cash, shares of common stock or a combination of cash and shares of common stock, at Southern Company's election, in respect of the remainder, if any, of Southern Company's conversion obligation in excess of the aggregate principal amount of the Series 2023A Convertible Senior Notes being converted. The Series 2023A Convertible Senior Notes are initially convertible at a rate of 11.8818 shares of common stock per $1,000 principal amount converted, which is approximately equal to $84.16 per share of common stock. The conversion rate will be subject to adjustment upon the occurrence of certain specified events but will not be adjusted for accrued and unpaid interest. In addition, upon the occurrence of a make-whole fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes), Southern Company will, in certain circumstances, increase the conversion rate by a number of additional shares of common stock for conversions in connection with the make-whole fundamental change.

Upon the occurrence of a fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes), holders of the Series 2023A Convertible Senior Notes may require Southern Company to purchase all or a portion of their Series 2023A Convertible Senior Notes, in principal amounts equal to $1,000 or an integral multiple thereof, for cash at a price equal to 100% of the principal amount of the Series 2023A Convertible Senior Notes to be purchased plus any accrued and unpaid interest.

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Earnings per Share

For Southern Company, the only difference in computing basic and diluted earnings per share (EPS) is attributable to awards outstanding under stock-based compensation plans and the Series 2023A Convertible Senior Notes. EPS dilution resulting from stock-based compensation plans is determined using the treasury stock method and EPS dilution resulting from the Series 2023A Convertible Senior Notes is determined using the net share settlement method. See Note 12 to the financial statements in Item 8 of the Form 10-K and "Convertible Senior Notes" herein for additional information. Shares used to compute diluted EPS were as follows:

	Three Months Ended March 31,
	2023	2022
	(in millions)
As reported shares	1,091	1,063
Effect of stock-based compensation	7	6
Diluted shares	1,098	1,069

For the three months ended March 31, 2023, there were no anti-dilutive shares. For the three months ended March 31, 2022, an immaterial number of stock-based compensation awards was excluded from the diluted EPS calculation because the awards were anti-dilutive.

For both periods presented, there was no dilution resulting from the Series 2023A Convertible Senior Notes.

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. In June 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. Subsequently, the lessee failed to make the semi-annual lease payment due in December 2022. As a result, the Southern Holdings subsidiary was unable to make its corresponding payment to the holders of the underlying non-recourse debt related to the generation assets. The parties to the lease have entered into a forbearance agreement which suspends the related contractual rights of the parties while they continue restructuring negotiations, 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. Southern Company will continue to monitor the operational performance of the underlying assets and evaluate the ability of the lessee to continue to make the required lease payments and meet its obligations associated with a future closure or retirement of the generation assets and associated properties, including the dry ash landfill.

(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

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 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.

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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 10.8% for the three months ended March 31, 2023 compared to 14.9% for the corresponding period in 2022. The effective tax rate decrease was primarily due to an increase in the flowback of certain excess deferred income taxes at Alabama Power in 2023, partially offset by the flowback of certain excess deferred income taxes ending in 2022 at Georgia Power.

Alabama Power

Alabama Power's effective tax benefit rate was (0.8)% for the three months ended March 31, 2023 compared to an effective tax rate of 23.3% for the corresponding period in 2022. The effective tax rate decrease was primarily due to an increase in the flowback of certain excess deferred income taxes in 2023. See Note 2 to the financial statements under "Alabama Power – Excess Accumulated Deferred Income Tax Accounting Order" in Item 8 of the Form 10-K for additional information.

Georgia Power

Georgia Power's effective tax rate was 15.1% for the three months ended March 31, 2023 compared to 7.3% for the corresponding period in 2022. The effective tax rate increase was primarily due to the flowback of certain excess deferred income taxes ending in 2022.

Southern Power

Southern Power's effective tax benefit rate was (20.7)% for the three months ended March 31, 2023 compared to (80.0)% for the corresponding period in 2022. The effective tax rate increase was primarily due to higher pre-tax earnings and the impacts of noncontrolling interests.

(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, 2023. 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.

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 months ended March 31, 2023 and 2022 are presented in the following tables.

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(UNAUDITED)

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2023
Pension Plans
Service cost	$	69	$	16	$	17	$	3	$	2	$	6
Interest cost	156		36		48		7		2		11
Expected return on plan assets	(307)		(74)		(96)		(14)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net (gain) loss	8		2		3		—		—		(1)
Net periodic pension income	$	(74)	$	(20)	$	(28)	$	(4)	$	—	$	(3)
Postretirement Benefits
Service cost	$	4	$	1	$	1	$	—	$	—	$	—
Interest cost	18		4		6		1		—		2
Expected return on plan assets	(21)		(8)		(7)		(1)		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net gain	(3)		(1)		(1)		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(2)	$	(4)	$	(1)	$	—	$	—	$	1

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(UNAUDITED)

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Pension Plans
Service cost	$	103	$	25	$	26	$	4	$	2	$	9
Interest cost	102		24		31		5		2		7
Expected return on plan assets	(316)		(77)		(99)		(15)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	60		16		18		3		1		2
Net periodic pension cost (income)	$	(51)	$	(12)	$	(24)	$	(3)	$	1	$	(1)
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	10		3		4		—		—		1
Expected return on plan assets	(20)		(8)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1

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(UNAUDITED)

(I) FAIR VALUE MEASUREMENTS

At March 31, 2023, 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 March 31, 2023	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)	$	4	$	100	$	—	$	—	$	104
Interest rate derivatives	—		2		—		—		2
Investments in trusts:(b)(c)
Domestic equity	680		192		—		—		872
Foreign equity	138		162		—		—		300
U.S. Treasury and government agency securities	—		316		—		—		316
Municipal bonds	—		48		—		—		48
Pooled funds – fixed income	—		7		—		—		7
Corporate bonds	—		403		—		—		403
Mortgage and asset backed securities	—		90		—		—		90
Private equity	—		—		—		160		160
Cash and cash equivalents	2		—		—		—		2
Other	40		12		—		9		61
Cash equivalents	433		13		—		—		446
Other investments	9		29		8		—		46
Total	$	1,306	$	1,374	$	8	$	169	$	2,857
Liabilities:
Energy-related derivatives(a)	$	40	$	354	$	—	$	—	$	394
Interest rate derivatives	—		261		—		—		261
Foreign currency derivatives	—		218		—		—		218
Contingent consideration	—		—		12		—		12
Other	—		13		—		—		13
Total	$	40	$	846	$	12	$	—	$	898

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(UNAUDITED)

	Fair Value Measurements Using:
At March 31, 2023	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	$	—	$	32	$	—	$	—	$	32
Nuclear decommissioning trusts:(b)
Domestic equity	404		185		—		—		589
Foreign equity	138		—		—		—		138
U.S. Treasury and government agency securities	—		19		—		—		19
Municipal bonds	—		1		—		—		1
Corporate bonds	—		223		—		—		223
Mortgage and asset backed securities	—		22		—		—		22
Private equity	—		—		—		160		160
Other	7		—		—		9		16
Cash equivalents	193		13		—		—		206
Other investments	—		29		—		—		29
Total	$	742	$	524	$	—	$	169	$	1,435
Liabilities:
Energy-related derivatives	$	—	$	96	$	—	$	—	$	96
Georgia Power
Assets:
Energy-related derivatives	$	—	$	22	$	—	$	—	$	22
Nuclear decommissioning trusts:(b)(c)
Domestic equity	276		1		—		—		277
Foreign equity	—		161		—		—		161
U.S. Treasury and government agency securities	—		297		—		—		297
Municipal bonds	—		47		—		—		47
Corporate bonds	—		180		—		—		180
Mortgage and asset backed securities	—		68		—		—		68
Other	33		12		—		—		45
Total	$	309	$	788	$	—	$	—	$	1,097
Liabilities:
Energy-related derivatives	$	—	$	132	$	—	$	—	$	132
Interest rate derivatives	—		1		—		—		1
Total	$	—	$	133	$	—	$	—	$	133

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(UNAUDITED)

	Fair Value Measurements Using:
At March 31, 2023	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	$	—	$	35	$	—	$	—	$	35
Cash equivalents	3		—		—		—		3
Total	$	3	$	35	$	—	$	—	$	38
Liabilities:
Energy-related derivatives	$	—	$	62	$	—	$	—	$	62
Southern Power
Assets:
Energy-related derivatives	$	—	$	5	$	—	$	—	$	5
Cash equivalents	13		—		—		—		13
Total	$	13	$	5	$	—	$	—	$	18
Liabilities:
Energy-related derivatives	$	—	$	14	$	—	$	—	$	14
Foreign currency derivatives	—		47		—		—		47
Contingent consideration	—		—		12		—		12
Other	—		13		—		—		13
Total	$	—	$	74	$	12	$	—	$	86
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	4	$	6	$	—	$	—	$	10
Interest rate derivatives	—		1		—		—		1
Non-qualified deferred compensation trusts:
Domestic equity	—		6		—		—		6
Foreign equity	—		1		—		—		1
Pooled funds – fixed income	—		7		—		—		7
Cash equivalents	2		—		—		—		2
Cash equivalents and restricted cash	55		—		—		—		55
Total	$	61	$	21	$	—	$	—	$	82
Liabilities:
Energy-related derivatives(a)	$	40	$	50	$	—	$	—	$	90
Interest rate derivatives	—		72		—		—		72
Total	$	40	$	122	$	—	$	—	$	162

(a)Excludes cash collateral of $60 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.

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(UNAUDITED)

(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. At March 31, 2023, approximately $37 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 months ended March 31, 2023 and 2022. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

	Three Months Ended
Fair value increases (decreases)	March 31, 2023		March 31, 2022
	(in millions)
Southern Company	$	102	$	(150)
Alabama Power	45		(67)
Georgia Power	57		(83)

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.

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(UNAUDITED)

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" primarily includes investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds.

At March 31, 2023, the fair value measurements of private market investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $169 million and unfunded commitments related to the private market investments totaled $75 million. Private market investments include high-quality private equity funds across several market sectors, funds that invest in real estate assets, and a private credit fund. Private market funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated.

At March 31, 2023, 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	$	56.1	$	10.6	$	14.9	$	1.5	$	3.0	$	7.5
Fair value	51.6		9.5		13.7		1.3		2.9		6.7

(*)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.

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(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. 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.

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.

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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 March 31, 2023, 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(*)	437	2030	2028
Alabama Power	111	2026	2023
Georgia Power	122	2026	2023
Mississippi Power	86	2027	2023
Southern Power	11	2030	2023
Southern Company Gas(*)	107	2028	2028

(*)Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 113.6 million mmBtu and short natural gas positions of 6.6 million mmBtu at March 31, 2023, 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 22 million mmBtu for Southern Company, which includes 6 million mmBtu for Alabama Power, 8 million mmBtu for Georgia Power, 3 million mmBtu for Mississippi Power, and 5 million mmBtu for Southern Power.

For cash flow hedges of energy-related derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2024 are $(42) million for Southern Company, $(12) million for Southern Power, $(30) million for Southern Company Gas, and 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 March 31, 2023, the following interest rate derivatives were outstanding:

	Notional Amount		Weighted Average Interest Rate Paid	Interest Rate Received	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2023
	(in millions)					(in millions)
Cash Flow Hedges of Forecasted Debt
Georgia Power	$	750	3.63%	N/A	February 2033	$	(1)
Southern Company parent	500		3.47%	N/A	June 2033	—
Southern Company Gas	250		3.40%	N/A	August 2033	1
Fair Value Hedges of Existing Debt
Southern Company parent	400		1-month LIBOR + 0.68%	1.75%	March 2028	(45)
Southern Company parent	1,000		1-month LIBOR + 2.36%	3.70%	April 2030	(142)
Southern Company Gas	500		1-month LIBOR + 0.38%	1.75%	January 2031	(71)
Southern Company	$	3,400				$	(258)

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 March 31, 2024 are $(15) million for Southern Company and 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 March 31, 2023, the following foreign currency derivatives were outstanding:

	Pay Notional		Pay Rate	Receive Notional		Receive Rate	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2023
	(in millions)			(in millions)				(in millions)
Cash Flow Hedges of Existing Debt
Southern Power	$	564	3.78%	€	500	1.85%	June 2026	$	(47)
Fair Value Hedges of Existing Debt
Southern Company parent	1,476		3.39%	1,250		1.88%	September 2027	(171)
Southern Company	$	2,040		€	1,750			$	(218)

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 March 31, 2024 are $11 million for Southern Power.

Derivative Financial Statement Presentation and Amounts

The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.

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The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Liabilities from risk management activities	$	41	$	230	$	123	$	121
Other deferred charges and assets/Other deferred credits and liabilities	53		113		52		44
Total derivatives designated as hedging instruments for regulatory purposes	94		343		175		165
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities	—		38		3		27
Other deferred charges and assets/Other deferred credits and liabilities	4		4		6		4
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities	2		71		12		62
Other deferred charges and assets/Other deferred credits and liabilities	—		191		—		240
Foreign currency derivatives:
Assets from risk management activities/Liabilities from risk management activities	—		35		—		34
Other deferred charges and assets/Other deferred credits and liabilities	—		183		—		182
Total derivatives designated as hedging instruments in cash flow and fair value hedges	6		522		21		549
Energy-related derivatives not designated as hedging instruments
Assets from risk management activities/Liabilities from risk management activities	4		8		13		13
Other deferred charges and assets/Other deferred credits and liabilities	2		1		2		1
Total derivatives not designated as hedging instruments	6		9		15		14
Gross amounts recognized	106		874		211		728
Gross amounts offset(a)	(57)		(118)		(70)		(111)
Net amounts recognized in the Balance Sheets(b)	$	49	$	756	$	141	$	617

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	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power(c)
Energy-related derivatives designated as hedging instruments for regulatory purposes
Other current assets/Other current liabilities	$	14	$	54	$	42	$	21
Other deferred charges and assets/Other deferred credits and liabilities	18		42		20		18
Total derivatives designated as hedging instruments for regulatory purposes	32		96		62		39
Gross amounts offset	(28)		(28)		(24)		(24)
Net amounts recognized in the Balance Sheets	$	4	$	68	$	38	$	15
Georgia Power
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Other current liabilities	$	10	$	86	$	36	$	43
Other deferred charges and assets/Other deferred credits and liabilities	11		45		6		18
Total derivatives designated as hedging instruments for regulatory purposes	21		131		42		61
Interest rate derivatives designated as hedging instruments in cash flow and fair value hedges
Assets from risk management activities/Other current liabilities	—		1		—		—
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	1		1		—		1
Gross amounts recognized	22		133		42		62
Gross amounts offset	(19)		(19)		(21)		(21)
Net amounts recognized in the Balance Sheets	$	3	$	114	$	21	$	41
Mississippi Power(c)
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Other current liabilities	$	11	$	37	$	33	$	24
Other deferred charges and assets/Other deferred credits and liabilities	24		25		26		8
Total derivatives designated as hedging instruments for regulatory purposes	35		62		59		32
Gross amounts offset	(25)		(25)		(17)		(17)
Net amounts recognized in the Balance Sheets	$	10	$	37	$	42	$	15

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	At March 31, 2023				At December 31, 2022
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	$	—	$	12	$	—	$	12
Other deferred charges and assets/Other deferred credits and liabilities	4		—		5		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		11		—		11
Other deferred charges and assets/Other deferred credits and liabilities	—		36		—		36
Total derivatives designated as hedging instruments in cash flow and fair value hedges	4		59		5		59
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	—		2		2		—
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	1		2		3		—
Gross amounts recognized	5		61		8		59
Net amounts recognized in the Balance Sheets	$	5	$	61	$	8	$	59

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(UNAUDITED)

	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Energy-related derivatives designated as hedging instruments for regulatory purposes
Other current assets/Other current liabilities	$	6	$	53	$	12	$	33
Other deferred charges and assets/Other deferred credits and liabilities	—		1		—		—
Total derivatives designated as hedging instruments for regulatory purposes	6		54		12		33
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	—		26		3		15
Other deferred charges and assets/Other deferred credits and liabilities	—		4		1		4
Interest rate derivatives:
Other current assets/Other current liabilities	1		19		—		14
Other deferred charges and assets/Other deferred credits and liabilities	—		53		—		72
Total derivatives designated as hedging instruments in cash flow and fair value hedges	1		102		4		105
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	3		5		11		12
Other deferred charges and assets/Other deferred credits and liabilities	1		1		1		1
Total derivatives not designated as hedging instruments	4		6		12		13
Gross amounts recognized	11		162		28		151
Gross amounts offset(a)	18		(43)		—		(41)
Net amounts recognized in the Balance Sheets(b)	$	29	$	119	$	28	$	110

(a)Gross amounts offset includes cash collateral held on deposit in broker margin accounts of $60 million and $41 million at March 31, 2023 and December 31, 2022, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for both periods presented.

(c)Energy-related derivatives not designated as hedging instruments were immaterial for Alabama Power and Mississippi Power for both periods presented.

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At March 31, 2023 and December 31, 2022, 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 March 31, 2023:
Energy-related derivatives:
Other regulatory assets, current	$	(198)	$	(44)	$	(78)	$	(29)	$	(47)
Other regulatory assets, deferred	(67)		(24)		(35)		(8)		—
Other regulatory liabilities, current	19		3		2		3		11
Other regulatory liabilities, deferred	9		1		1		7		—
Total energy-related derivative gains (losses)	$	(237)	$	(64)	$	(110)	$	(27)	$	(36)
At December 31, 2022:
Energy-related derivatives:
Other regulatory assets, current	$	(71)	$	(8)	$	(26)	$	(13)	$	(24)
Other regulatory assets, deferred	(23)		(7)		(14)		(2)		—
Other regulatory liabilities, current	72		29		19		22		2
Other regulatory liabilities, deferred	31		9		2		20		—
Total energy-related derivative gains (losses)	$	9	$	23	$	(19)	$	27	$	(22)

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(UNAUDITED)

For the three months ended March 31, 2023 and 2022, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI for the applicable Registrants were as follows:

Gain (Loss) Recognized in OCI on Derivatives	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	(45)	$	42
Interest rate derivatives	(13)		9
Foreign currency derivatives	—		(28)
Fair value hedges(*):
Foreign currency derivatives	(28)		4
Total	$	(86)	$	27
Georgia Power
Cash flow hedges:
Interest rate derivatives	$	(1)	$	12
Southern Power
Cash flow hedges:
Energy-related derivatives	$	(11)	$	5
Foreign currency derivatives	—		(28)
Total	$	(11)	$	(23)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	(34)	$	37
Interest rate derivatives	1		—
Total	$	(33)	$	37

(*)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 months ended March 31, 2023, the pre-tax effects of energy-related derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for Alabama Power and Mississippi Power. There were no such instruments for Alabama Power and Mississippi Power at March 31, 2022.

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For the three months ended March 31, 2023 and 2022, 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 March 31,
	2023		2022
	(in millions)
Southern Company
Total cost of natural gas	$	898	$	1,095
Gain (loss) on energy-related cash flow hedges(a)	(20)		9
Total depreciation and amortization	1,111		892
Gain (loss) on energy-related cash flow hedges(a)	(9)		2
Total interest expense, net of amounts capitalized	(582)		(462)
Gain (loss) on interest rate cash flow hedges(a)	(4)		(7)
Gain (loss) on foreign currency cash flow hedges(a)	(3)		(6)
Gain (loss) on interest rate fair value hedges(b)	43		(123)
Total other income (expense), net	147		145
Gain (loss) on foreign currency cash flow hedges(a)(c)	10		(25)
Gain (loss) on foreign currency fair value hedges	(2)		(24)
Amount excluded from effectiveness testing recognized in earnings	28		(4)
Southern Power
Total depreciation and amortization	$	128	$	120
Gain (loss) on energy-related cash flow hedges(a)	(9)		2
Total interest expense, net of amounts capitalized	(33)		(37)
Gain (loss) on foreign currency cash flow hedges(a)	(3)		(6)
Total other income (expense), net	2		2
Gain (loss) on foreign currency cash flow hedges(a)(c)	10		(25)
Southern Company Gas
Total cost of natural gas	$	898	$	1,095
Gain (loss) on energy-related cash flow hedges(a)	(20)		9
Total interest expense, net of amounts capitalized	(76)		(61)
Gain (loss) on interest rate cash flow hedges(a)	(1)		(1)
Gain (loss) on interest rate fair value hedges(b)	13		(36)

(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.

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 for both periods presented.

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(UNAUDITED)

At March 31, 2023 and December 31, 2022, 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 March 31, 2023		At December 31, 2022		At March 31, 2023		At December 31, 2022
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(3,007)	$	(2,927)	$	228	$	282
Southern Company Gas
Long-term debt	$	(428)	$	(415)	$	69	$	81

For the three months ended March 31, 2023 and 2022, 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 March 31,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location		2023		2022
			(in millions)
Energy-related derivatives:	Natural gas revenues(*)		$	—	$	2
	Cost of natural gas		13		21
Total derivatives in non-designated hedging relationships			$	13	$	23

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

For the three months ended March 31, 2023 and 2022, 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. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. At March 31, 2023, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For Southern Company and Southern Power, the fair value of interest rate derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were $73 million and $23 million, respectively, at March 31, 2023. For the traditional electric operating companies and Southern Power, energy-related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were immaterial at March 31, 2023. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade.

Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions and they may be required to post collateral based on the value of the positions in

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS (Continued)

(UNAUDITED)

these accounts and the associated margin requirements. At March 31, 2023, cash collateral posted in these accounts was $15 million for Southern Power and immaterial for Alabama Power. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At March 31, 2023, cash collateral held on deposit in broker margin accounts was $60 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) 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.

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 $135 million and $105 million for the three months ended March 31, 2023 and 2022, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies and Southern Power were immaterial for both periods presented. The "All Other" column includes the Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications and, for the three months ended March 31, 2022, 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 months ended March 31, 2023 and 2022 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 March 31, 2023
Operating revenues	$	4,113	$	508	$	(138)	$	4,483	$	1,875	$	166	$	(44)	$	6,480
Segment net income (loss)(a)(b)	610		102		—		712		309		(154)		(5)		862
At March 31, 2023
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	144	$	—	$	5,161
Total assets	96,223		13,134		(575)		108,782		24,222		2,606		(854)		134,756
Three Months Ended March 31, 2022
Operating revenues	$	4,191	$	539	$	(221)	$	4,509	$	2,058	$	123	$	(42)	$	6,648
Segment net income (loss)(a)	774		72		—		846		319		(125)		(8)		1,032
At December 31, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	144	$	—	$	5,161
Total assets	95,861		13,081		(659)		108,283		24,621		2,665		(678)		134,891

(a)Attributable to Southern Company.

(b)For Southern Power, includes a $16 million pre-tax gain ($12 million after tax) on the sale of spare parts.

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2023	$	3,599	$	599	$	285	$	4,483
Three Months Ended March 31, 2022	3,613		664		232		4,509

	Southern Company Gas' Revenues
	Gas Distribution Operations		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended March 31, 2023	$	1,610	$	246	$	19	$	1,875
Three Months Ended March 31, 2022	1,791		243		24		2,058

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(UNAUDITED)

Southern Company Gas

Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. The non-reportable segments are combined and presented as all other.

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. 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 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. The all other column included a natural gas storage facility in Texas through its sale in November 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information, including the sale of a natural gas storage facility in California expected to be completed later in 2023.

Business segment financial data for the three months ended March 31, 2023 and 2022 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2023
Operating revenues	$	1,618	$	8	$	246	$	1,872	$	12	$	(9)	$	1,875
Segment net income	221		31		50		302		7		—		309
Total assets at March 31, 2023	22,223		1,583		1,596		25,402		9,598		(10,778)		24,222
Three Months Ended March 31, 2022
Operating revenues	$	1,803	$	8	$	243	$	2,054	$	16	$	(12)	$	2,058
Segment net income	214		29		66		309		10		—		319
Total assets at December 31, 2022	22,040		1,577		1,616		25,233		8,943		(9,555)		24,621

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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	90
Results of Operations	92
Southern Company	92
Alabama Power	98
Georgia Power	103
Mississippi Power	107
Southern Power	110
Southern Company Gas	113
Future Earnings Potential	118
Accounting Policies	122
Financial Condition and Liquidity	122

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. See Note (K) to the Condensed Financial Statements herein for additional information on segment reporting. Alabama Power, Georgia Power, and Mississippi Power each operate with one reportable business segment, since substantially all of their business is providing electric service to customers. Southern Power also operates its business with one reportable business segment, the sale of electricity in the competitive wholesale market. For additional information on the Registrants' primary business activities, see BUSINESS – "The Southern Company System" in Item 1 of the Form 10-K.

The Registrants continue to focus on several key performance indicators. For the traditional electric operating companies and Southern Company Gas, these indicators include, but are not limited to, customer satisfaction, plant availability, electric and natural gas system reliability, and execution of major construction projects. 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

During the first three months of 2023, Alabama Power continued construction of Plant Barry Unit 8, which is expected to be placed in service in November 2023. At March 31, 2023, project expenditures associated with Plant Barry Unit 8 totaled approximately $541 million.

On March 24, 2023, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover costs associated with the acquisition of the Central Alabama Generating Station. The filing reflected an annual increase in retail revenues of $78 million effective with June 2023 billings. Through May 2023, Alabama Power expects to recover substantially all costs associated with the Central Alabama Generating Station through Rate RSE, offset by revenues from a power sales agreement.

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 second quarter 2023 and the first quarter 2024, respectively, is $10.6 billion.

On March 6, 2023, Unit 3 achieved self-sustaining nuclear fission, commonly referred to as initial criticality, and, on April 1, 2023, the generator successfully synchronized to the power grid and generated electricity for the first time. Operators continue to perform tests at various power levels to help ensure the reactor performs as designed, and Southern Nuclear continues to remediate various equipment and component issues as they are identified. Based on the expected duration of start-up testing, Unit 3 is projected to be placed in service during May or June 2023. The projected schedule for Unit 3 primarily depends on the progression of pre-operational testing and start-up,

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

which may be impacted by further equipment, component, and/or other operational challenges. Hot functional testing for Unit 4 commenced on March 20, 2023, with fuel load projected to occur in the third quarter 2023. Unit 4 is projected to be placed in service during late fourth quarter 2023 or the first quarter 2024. The projected schedule for Unit 4 primarily depends on potential impacts arising from Unit 4 testing activities overlapping with Unit 3 start-up and commissioning; maintaining overall construction productivity and production levels, particularly in subcontractor scopes of work; and maintaining appropriate levels of craft laborers. Any further delays could result in later in-service dates and cost increases.

During the first quarter 2023, established construction contingency totaling $20 million was assigned to the base capital cost forecast for costs primarily associated with additional craft and support resources.

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 notified Georgia Power that they believe the project capital cost forecast approved by the Vogtle Owners in February 2022 triggered the tender provisions.

In June 2022 and July 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. Georgia Power did not accept these purported tender exercises. In June 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 had been triggered. In July 2022, Georgia Power filed its answers in the lawsuits filed by MEAG Power and OPC 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. In September 2022, Dalton filed complaints in each of these lawsuits.

Also in September 2022, Georgia Power and MEAG Power reached an agreement to resolve their dispute regarding the proper interpretation of the cost-sharing and tender provisions of the Global Amendments. Under the terms of the agreement, among other items, (i) MEAG Power will not exercise its tender option and will retain its full ownership interest in Plant Vogtle Units 3 and 4; (ii) Georgia Power will reimburse a portion of MEAG Power's costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs, which payments will total approximately $92 million based on the current project capital cost forecast; and (iii) Georgia Power will reimburse 20% of MEAG Power's costs of construction with respect to any amounts over the current project capital cost forecast, with no further adjustment for force majeure costs. In October 2022, MEAG Power and Georgia Power filed a notice of settlement and voluntary dismissal of the pending litigation described above, including Georgia Power's counterclaim, and Dalton dismissed its related complaint.

Georgia Power recorded pre-tax charges to income through the fourth quarter 2022 of $407 million ($304 million after tax) associated with the cost-sharing and tender provisions of the Global Amendments, including the settlement with MEAG Power. This total is included in the total project capital cost forecast and will not be recovered from retail customers. The settlement with MEAG Power does not resolve the separate pending litigation with OPC, including Dalton's associated complaint, described above. Georgia Power may be required to record further pre-tax charges to income of up to approximately $345 million associated with the cost-sharing and tender provisions of the Global Amendments for OPC and Dalton based on the current project capital cost forecast.

Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%. Georgia Power believes the increases in the total project capital cost forecast through December 31, 2022 triggered the tender provisions, but Georgia Power disagrees with OPC and Dalton on the tender provisions trigger date. Valid notices of tender from OPC and Dalton would require Georgia Power to pay 100% of their respective remaining shares of the costs necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest will be calculated and conveyed to Georgia Power after Plant Vogtle Units 3 and 4 are placed in service.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

The ultimate impact of these matters on the construction schedule and project capital cost forecast and related cost recovery 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.

Fuel Cost Recovery

On February 28, 2023, Georgia Power filed a request with the Georgia PSC to increase fuel rates. On April 24, 2023, Georgia Power filed an updated request reflecting a 54% increase in fuel rates effective June 1, 2023, which is expected to increase annual billings by approximately $1.1 billion. Changes in fuel rates have no significant effect on Georgia Power's net income but do impact the related operating cash flows. Georgia Power expects the Georgia PSC to make a final decision on this matter on May 16, 2023. The ultimate outcome of this matter cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Georgia Power – Fuel Cost Recovery" herein for additional information.

RESULTS OF OPERATIONS

Southern Company

Net Income

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(170)	(16.5)

Consolidated net income attributable to Southern Company was $0.9 billion ($0.79 per share) in the first quarter 2023 compared to $1.0 billion ($0.97 per share) for the corresponding period in 2022. The decrease was primarily due to higher depreciation and amortization, a decrease in retail electric revenues associated with milder weather in the first quarter 2023 compared to the corresponding period in 2022, and higher interest expense, partially offset by an increase in retail electric revenues associated with rates and pricing and an increase in other revenues.

Retail Electric Revenues

In the first quarter 2023, retail electric revenues were $3.60 billion compared to $3.61 billion for the corresponding period in 2022. Details of the changes in retail electric revenues were as follows:

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Rates and pricing	$	97	2.7	%
Sales growth	7		0.2
Weather	(152)		(4.2)
Fuel and other cost recovery	34		0.9
Retail electric revenues	$	(14)	(0.4)	%

Revenues associated with changes in rates and pricing increased in the first quarter 2023 when compared to the corresponding period in 2022. The increase was primarily due to an increase in Rate CNP Compliance revenues at Alabama Power and base tariff increases in accordance with Georgia Power's 2022 ARP. In addition, revenues associated with Rate CNP Depreciation increased $73 million and were fully offset by customer bill credits of $73 million related to the flowback of excess accumulated deferred income taxes at Alabama Power. See Note 2 to the financial statements under "Alabama Power" and "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Revenues attributable to changes in sales increased in the first quarter 2023 when compared to the corresponding period in 2022. Weather-adjusted residential and commercial KWH sales increased 1.2% and 1.8%, respectively, in the first quarter 2023 when compared to the corresponding period in 2022 primarily due to residential customer growth and increased commercial usage. Commercial customer usage increased as customers continued their return to regular business trends. Industrial KWH sales decreased 1.6% in the first quarter 2023 when compared to the corresponding period in 2022 primarily due to a decrease in the chemicals sector, partially offset by increases in the pipeline and primary metals sectors.

Fuel and other cost recovery revenues increased $34 million in the first quarter 2023 compared to the corresponding period in 2022 primarily due to higher recoverable fuel costs. Electric rates for the traditional electric operating companies include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of PPA costs, and do not affect net income. The traditional electric operating companies each have one or more regulatory mechanisms to recover other costs such as environmental and other compliance costs, storm damage, new plants, and PPA capacity costs. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein for additional information.

Wholesale Electric Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(65)	(9.8)

In the first quarter 2023, wholesale electric revenues were $599 million compared to $664 million for the corresponding period in 2022. The decrease was primarily due to a $97 million decrease in energy revenues in the first quarter 2023 as a result of fuel and purchased power price decreases when compared to the corresponding period in 2022 and a net decrease in the volume of KWHs sold primarily associated with natural gas PPAs at Southern Power. The decrease in energy revenues was partially offset by an increase in capacity revenues of $32 million in the first quarter 2023 primarily resulting from a new power sales agreement that began in July 2022 at Alabama Power and a net increase in capacity sales from 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.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Other Electric Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$13	7.3

In the first quarter 2023, other electric revenues were $190 million compared to $177 million for the corresponding period in 2022. The increase was primarily due to an increase of $7 million in transmission revenues at the traditional electric operating companies and Southern Power, an increase of $6 million in outdoor lighting sales at Georgia Power, and a $4 million gain on the resale of gas at Alabama Power, partially offset by a $5 million decrease in cogeneration steam revenue primarily associated with lower natural gas prices at Alabama Power.

Natural Gas Revenues

In the first quarter 2023, natural gas revenues were $1.9 billion compared to $2.1 billion for the corresponding period in 2022. Details of the changes in natural gas revenues were as follows:

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Infrastructure replacement programs and rate changes	$	50	2.4	%
Gas costs and other cost recovery	(199)		(9.7)
Gas marketing services	(21)		(1.0)
Other	(13)		(0.6)
Natural gas revenues	$	(183)	(8.9)	%

Revenues from infrastructure replacement programs and rate changes at the natural gas distribution utilities increased in the first quarter 2023 compared to the corresponding period in 2022 primarily due to rate increases at the natural gas distribution utilities 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 from gas costs and other cost recovery decreased in the first quarter 2023 compared to the corresponding period in 2022 primarily due to lower natural gas cost recovery associated with the timing of natural gas purchases and the recovery of those costs from 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.

Revenues from gas marketing services decreased in the first quarter 2023 compared to the corresponding period in 2022 primarily due to lower natural gas prices and the timing of unrealized hedge losses, partially offset by higher variable price spreads in Georgia and Illinois and higher customer count in Georgia.

Other Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$81	59.6

In the first quarter 2023, other revenues were $217 million compared to $136 million for the corresponding period in 2022. The increase was primarily due to increases of $36 million related to distributed infrastructure projects at PowerSecure, $24 million in unregulated sales associated with power delivery construction and maintenance projects primarily at Georgia Power, and $15 million in unregulated sales of products and services at Alabama Power.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Fuel and Purchased Power Expenses

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Fuel	$	(61)	(5.5)
Purchased power	10		4.3
Total fuel and purchased power expenses	$	(51)

In the first quarter 2023, total fuel and purchased power expenses were $1.29 billion compared to $1.34 billion for the corresponding period in 2022. The decrease was due to a $42 million decrease in the average cost of fuel and purchased power and a $9 million net decrease 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.

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

	First Quarter 2023	First Quarter 2022
Total generation (in billions of KWHs)(a)	44	46
Total purchased power (in billions of KWHs)	5	4
Sources of generation (percent)(a) —
Gas	54	46
Coal	15	23
Nuclear	17	17
Hydro	5	6
Wind, Solar, and Other	9	8
Cost of fuel, generated (in cents per net KWH)—
Gas(a)	3.13	3.53
Coal	4.02	3.11
Nuclear	0.71	0.72
Average cost of fuel, generated (in cents per net KWH)(a)	2.80	2.86
Average cost of purchased power (in cents per net KWH)(b)	5.50	5.58

(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel through July 12, 2022 as its fuel was previously 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 first quarter 2023, fuel expense was $1.05 billion compared to $1.11 billion for the corresponding period in 2022. The decrease was primarily due to a 39.1% decrease in the volume of KWHs generated by coal and an 11.3% decrease in the average cost of natural gas per KWH generated, partially offset by a 29.3% increase in the average cost of coal per KWH generated, a 16.3% increase in the volume of KWHs generated by natural gas, and a 13.9% decrease in the volume of KWHs generated by hydro.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Purchased Power

In the first quarter 2023, purchased power expense was $242 million compared to $232 million for the corresponding period in 2022. The increase was primarily due to a 1.7% increase in the volume of KWHs purchased, partially offset by a 1.4% decrease in the average cost per KWH purchased primarily due to a decrease in natural gas prices.

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.

Cost of Natural Gas

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(197)	(18.0)

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 85% of the total cost of natural gas in the first quarter 2023.

In the first quarter 2023, cost of natural gas was $0.9 billion compared to $1.1 billion for the corresponding period in 2022. The decrease reflects lower gas cost recovery as a result of a 31% decrease in natural gas prices in the first quarter 2023 compared to the corresponding period in 2022.

Cost of Other Sales

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$58	84.1

In the first quarter 2023, cost of other sales was $127 million compared to $69 million for the corresponding period in 2022. The increase was primarily due to a $29 million increase related to distributed infrastructure projects at PowerSecure and a $24 million increase from unregulated power delivery construction and maintenance projects primarily at Georgia Power.

Other Operations and Maintenance Expenses

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(34)	(2.2)

In the first quarter 2023, other operations and maintenance expenses were $1.48 billion compared to $1.52 billion for the corresponding period in 2022. The decrease was primarily due to decreases of $45 million in storm damage recovery as authorized in Georgia Power's 2022 ARP, $44 million in generation expenses primarily associated with non-outage and scheduled outage maintenance costs, and $31 million in transmission and distribution expenses primarily related to line maintenance, partially offset by a $39 million increase in technology infrastructure and application production costs, a $25 million decrease in nuclear property insurance refunds at Georgia Power and Alabama Power, a $12 million increase in compensation and benefit expenses, and a $9 million increase related to the injuries and damages reserves at Alabama Power and Georgia Power.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Depreciation and Amortization

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$219	24.6

In the first quarter 2023, depreciation and amortization was $1.1 billion compared to $0.9 billion for the corresponding period in 2022. The increase was primarily due to an increase of $179 million resulting from higher depreciation rates at Alabama Power and Georgia Power and an increase of $26 million from additional plant in service. See Notes 2 and 5 to the financial statements under "Alabama Power" and "Depreciation and Amortization," respectively, in Item 8 of the Form 10-K for additional information.

Taxes Other Than Income Taxes

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$22	5.9

In the first quarter 2023, taxes other than income taxes were $394 million compared to $372 million for the corresponding period in 2022. The increase primarily reflects a $13 million increase in property taxes at the traditional electric operating companies and a $9 million increase in utility license taxes at Alabama Power.

Gain on Dispositions, Net

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$19	82.6

In the first quarter 2023, gain on dispositions, net was $42 million compared to $23 million for the corresponding period in 2022. The increase was primarily due to a gain on the sale of spare parts at Southern Power in 2023.

Allowance for Equity Funds Used During Construction

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$14	27.5

In the first quarter 2023, allowance for equity funds used during construction was $65 million compared to $51 million for the corresponding period in 2022. The increase was primarily associated with an increase in capital expenditures subject to AFUDC at Georgia Power and an increase in capital expenditures related to Plant Barry Unit 8 construction at Alabama Power. 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 "Alabama Power – Certificates of Convenience and Necessity" for additional information.

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AND RESULTS OF OPERATIONS (Continued)

Interest Expense, Net of Amounts Capitalized

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$120	26.0

In the first quarter 2023, interest expense, net of amounts capitalized was $582 million compared to $462 million for the corresponding period in 2022. The increase primarily reflects approximately $62 million related to higher interest rates and $39 million related to higher average outstanding borrowings. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.

Income Taxes

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(76)	(43.9)

In the first quarter 2023, income taxes were $97 million compared to $173 million for the corresponding period in 2022. The decrease was primarily due to lower pre-tax earnings and an increase in the flowback of certain excess deferred income taxes at Alabama Power, partially offset by a decrease in the flowback of certain excess deferred income taxes at Georgia Power that ended in 2022. See Note (G) to the Condensed Financial Statements herein for additional information.

Net Loss Attributable to Noncontrolling Interests

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(18)	(40.0)

Substantially all noncontrolling interests relate to renewable projects at Southern Power. In the first quarter 2023, net loss attributable to noncontrolling interests was $63 million compared to $45 million for the corresponding period in 2022. The increased loss was primarily due to $16 million in higher HLBV loss allocations to Southern Power's wind tax equity partners due to higher wind PTCs in 2023.

Alabama Power

Net Income

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(92)	(26.5)

Alabama Power's net income after dividends on preferred stock in the first quarter 2023 was $255 million compared to $347 million for the corresponding period in 2022. The decrease was primarily due to an increase in depreciation rates effective January 2023, a decrease in weather-related revenues due to milder weather in Alabama Power's service territory in the first quarter 2023 compared to the corresponding period in 2022, and a decrease in customer usage. These decreases to income were partially offset by a decrease in income tax expense and an increase in Rate CNP Compliance revenues. See Note 2 to the financial statements in Item 8 of the Form 10-K under "Alabama Power" for additional information.

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AND RESULTS OF OPERATIONS (Continued)

Retail Revenues

In both the first quarter 2023 and 2022, retail revenues were $1.38 billion. Details of the changes in retail revenues were as follows:

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Rates and pricing	$	58	4.2	%
Sales decline	(17)		(1.3)
Weather	(61)		(4.4)
Fuel and other cost recovery	22		1.6
Retail revenues	$	2	0.1	%

Revenues associated with changes in rates and pricing increased in the first quarter 2023 when compared to the corresponding period in 2022 primarily due to an increase in Rate CNP Compliance revenues. In addition, revenues associated with Rate CNP Depreciation increased $73 million and were fully offset by customer bill credits of $73 million related to the flowback of excess accumulated deferred income taxes. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales decreased in the first quarter 2023 when compared to the corresponding period in 2022. Weather-adjusted residential KWH sales increased 0.1% and weather-adjusted commercial KWH sales decreased 0.3% in the first quarter 2023 when compared to the corresponding period in 2022. The residential and commercial changes were primarily due to residential customer growth and a decrease in commercial usage, respectively. Industrial KWH sales decreased 2.4% primarily due to decreases in the chemicals sector, partially offset by an increase in the primary metals sector.

Fuel and other cost recovery revenues increased in the first quarter 2023 when compared to the corresponding period in 2022 primarily as a result of higher recoverable fuel costs.

Electric rates include provisions to recognize the recovery of fuel costs, purchased power costs, PPAs certificated by the Alabama PSC, and costs associated with the NDR. Under these provisions, fuel and other cost recovery revenues generally equal fuel and other cost recovery expenses and do not affect net income. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

Wholesale Revenues – Non-Affiliates

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$27	23.7

In the first quarter 2023, wholesale revenues from sales to non-affiliates were $141 million compared to $114 million for the corresponding period in 2022. The increase was primarily due to an 18.1% increase in the volume of KWH sales and a 4.8% increase in the price of energy both due to a new power sales agreement that began in July 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 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

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(46)	(70.8)

In the first quarter 2023, wholesale revenues from sales to affiliates were $19 million compared to $65 million for the corresponding period in 2022. The decrease was primarily due to a 63.5% decrease in the volume of KWH sales due to higher demand for Southern Company system lower cost generation and an 18.2% decrease in the price of energy due to lower natural gas prices.

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

Other Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$15	16.5

In the first quarter 2023, other revenues were $106 million compared to $91 million for the corresponding period in 2022. The increase was primarily due to an increase of $15 million in unregulated sales of products and services and a $4 million gain on the resale of gas, partially offset by a $5 million decrease in cogeneration steam revenue primarily associated with lower natural gas prices.

Fuel and Purchased Power Expenses

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Fuel	$	(25)	(7.5)
Purchased power – non-affiliates	34		50.7
Purchased power – affiliates	33		126.9
Total fuel and purchased power expenses	$	42

In the first quarter 2023, total fuel and purchased power expenses were $468 million compared to $426 million for the corresponding period in 2022. The increase was due to a $39 million net increase related to the volume of KWHs generated and purchased and a $3 million net increase in the cost of fuel and purchased power.

Fuel and purchased power energy transactions do not have a significant impact on earnings, since energy expenses are generally offset by energy revenues through Alabama Power's energy cost recovery clause. See Note 2 to the financial statements under "Alabama Power – Rate ECR" in Item 8 of the Form 10-K for additional information.

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AND RESULTS OF OPERATIONS (Continued)

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

	First Quarter 2023	First Quarter 2022
Total generation (in billions of KWHs)(a)	14	15
Total purchased power (in billions of KWHs)	3	2
Sources of generation (percent)(a) —
Coal	30	42
Nuclear	28	25
Gas	29	19
Hydro	13	14
Cost of fuel, generated (in cents per net KWH) —
Coal	3.33	2.90
Nuclear	0.67	0.67
Gas(a)	3.37	3.45
Average cost of fuel, generated (in cents per net KWH)(a)	2.49	2.36
Average cost of purchased power (in cents per net KWH)(b)	6.35	6.82

(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel through July 12, 2022 as its fuel was previously 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 first quarter 2023, fuel expense was $308 million compared to $333 million for the corresponding period in 2022. The decrease was primarily due to a 35.0% decrease in the volume of KWHs generated by coal and a 2.3% decrease in the average cost of natural gas per KWH generated, which excludes tolling agreements, partially offset by a 36.6% increase in the volume of KWHs generated by natural gas, a 14.8% increase in the average cost of coal per KWH generated, and a 12.8% decrease in the volume of KWHs generated by hydro facilities as a result of less rainfall in the first quarter 2023 compared to the corresponding period in 2022.

Purchased Power – Non-Affiliates

In the first quarter 2023, purchased power expense from non-affiliates was $101 million compared to $67 million for the corresponding period in 2022. The increase was primarily due to a 57.6% increase in the volume of KWHs purchased due to the availability of lower cost generation from market resources, partially offset by an 18.7% decrease in the average cost per KWH purchased due to a decrease in natural gas 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 first quarter 2023, purchased power expense from affiliates was $59 million compared to $26 million for the corresponding period in 2022. The increase was primarily due to an 82.5% increase in the volume of KWHs purchased due to the availability of lower cost gas generation in the Southern Company system and a 22.3% increase in the average cost per KWH purchased due to the purchase of additional capacity for reliability.

Energy purchases from affiliates will vary depending on demand for energy and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance with the IIC or other contractual agreements, as approved by the FERC.

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AND RESULTS OF OPERATIONS (Continued)

Other Operations and Maintenance Expenses

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$15	3.7

In the first quarter 2023, other operations and maintenance expenses were $424 million compared to $409 million for the corresponding period in 2022. The increase was primarily due to a $14 million decrease in nuclear property insurance refunds and increases of $8 million in expenses related to unregulated products and services, $7 million in technology infrastructure and application production costs, $5 million related to the injuries and damages reserve, $4 million in employee compensation and benefits, and $3 million in bad debt expense. The increases were partially offset by a $30 million decrease in generation expenses primarily associated with planned outages and maintenance.

Depreciation and Amortization

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$130	60.5

In the first quarter 2023, depreciation and amortization was $345 million compared to $215 million for the corresponding period in 2022. The increase was primarily due to an increase in depreciation rates effective in 2023. See Notes 2 and 5 to the financial statements under "Alabama Power" and "Depreciation and Amortization," respectively, in Item 8 of the Form 10-K for additional information.

Taxes Other Than Income Taxes

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$11	10.6

In the first quarter 2023, taxes other than income taxes were $115 million compared to $104 million for the corresponding period in 2022. The increase was primarily due to an increase in utility license taxes.

Interest Expense, Net of Amounts Capitalized

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$14	15.7

In the first quarter 2023, interest expense, net of amounts capitalized was $103 million compared to $89 million for the corresponding period in 2022. The increase was primarily associated with increases of approximately $11 million related to higher average outstanding borrowings and $5 million related to higher interest rates. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" herein for additional information on borrowings.

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AND RESULTS OF OPERATIONS (Continued)

Income Taxes (Benefit)

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(109)	N/M

In the first quarter 2023, income tax benefit was $2 million compared to income tax expense of $107 million for the corresponding period in 2022. The change was primarily due to an increase in the flowback of certain excess deferred income taxes and lower pre-tax earnings in the first quarter 2023. See Note 2 to the financial statements under "Alabama Power – Excess Accumulated Deferred Income Tax Accounting Order" in Item 8 of the Form 10-K and Note (G) to the Condensed Financial Statements herein for additional information.

Georgia Power

Net Income

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(89)	(23.1)

Georgia Power's net income in the first quarter 2023 was $296 million compared to $385 million for the corresponding period in 2022. The decrease was primarily due to a decrease in retail revenues associated with milder weather in the first quarter 2023 compared to the corresponding period in 2022. Partially offsetting this net income reduction were the impacts of the 2022 ARP effective January 1, 2023, including increased retail rates, partially offset by higher depreciation and amortization. See Note 2 to the financial statements under "Georgia Power" in Item 8 of the Form 10-K for additional information.

Retail Revenues

In the first quarter 2023, retail revenues were $1.98 billion compared to $2.02 billion for the corresponding period in 2022. Details of the changes in retail revenues were as follows:

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Rates and pricing	$	34	1.7	%
Sales growth	23		1.1
Weather	(85)		(4.2)
Fuel cost recovery	(8)		(0.4)
Retail revenues	$	(36)	(1.8)	%

Revenues associated with changes in rates and pricing increased in the first quarter 2023 when compared to the corresponding period in 2022. The increase was primarily due to base tariff increases in accordance with the 2022 ARP. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the first quarter 2023 when compared to the corresponding period in 2022. Weather-adjusted residential and commercial KWH sales increased 2.2% and 2.5%, respectively, primarily due to increased customer usage and customer growth. Commercial customer usage increased as customers continued their return to regular business trends. Weather-adjusted industrial KWH sales decreased 2.1% primarily due to decreases in the textile, chemical, and rubber sectors, partially offset by increases in the electronic, transportation, and pipeline sectors.

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AND RESULTS OF OPERATIONS (Continued)

Fuel revenues and costs are allocated between retail and wholesale jurisdictions. Retail fuel cost recovery revenues decreased in the first quarter 2023 when compared to the corresponding period in 2022 due to lower 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 (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 – Fuel Cost Recovery" for additional information.

Wholesale Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(35)	(53.0)

In the first quarter 2023, wholesale revenues were $31 million compared to $66 million for the corresponding period in 2022. The decrease was primarily due to a $23 million decrease in KWH sales associated with lower market demand and a $5 million decrease related to the average cost per KWH sold due to lower Southern Company system fuel and purchased power costs.

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

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

Other Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$39	31.2

In the first quarter 2023, other revenues were $164 million compared to $125 million for the corresponding period in 2022. The increase was primarily due to increases of $34 million in unregulated sales associated with power delivery construction and maintenance, outdoor lighting, and energy conservation projects.

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AND RESULTS OF OPERATIONS (Continued)

Fuel and Purchased Power Expenses

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Fuel	$	(17)	(4.1)
Purchased power – non-affiliates	(27)		(18.0)
Purchased power – affiliates	—		—
Total fuel and purchased power expenses	$	(44)

In the first quarter 2023, total fuel and purchased power expenses were $731 million compared to $775 million for the corresponding period in 2022. The decrease was due to a decrease of $55 million related to the volume of KWHs generated and purchased, partially offset by a net increase of $11 million related to the average cost of fuel and purchased power.

Fuel and purchased power energy transactions do not have a significant impact on earnings since these fuel expenses are generally offset by fuel revenues through Georgia Power's fuel cost recovery mechanism. See Note (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 – Fuel Cost Recovery" for additional information.

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

	First Quarter 2023	First Quarter 2022
Total generation (in billions of KWHs)	13	15
Total purchased power (in billions of KWHs)	8	8
Sources of generation (percent) —
Gas	55	46
Nuclear	26	24
Coal	14	25
Hydro and other	5	5
Cost of fuel, generated (in cents per net KWH) —
Gas	3.57	3.58
Nuclear	0.75	0.77
Coal	5.24	3.41
Average cost of fuel, generated (in cents per net KWH)	3.05	2.83
Average cost of purchased power (in cents per net KWH)(*)	4.52	4.81

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

Fuel

In the first quarter 2023, fuel expense was $402 million compared to $419 million for the corresponding period in 2022. The decrease was primarily due to a 48.4% decrease in the volume of KWHs generated by coal, partially offset by increases of 53.7% in the average cost per KWH generated by coal and 6.4% in the volume of KWHs generated by natural gas.

Purchased Power – Non-Affiliates

In the first quarter 2023, purchased power expense from non-affiliates was $123 million compared to $150 million for the corresponding period in 2022. The decrease was primarily due to a 33.3% decrease in the volume of KWHs

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AND RESULTS OF OPERATIONS (Continued)

purchased as Georgia Power and other Southern Company system units generally dispatched at a lower cost than available market resources, partially offset by a 23.6% increase in the average cost per KWH purchased primarily due to higher 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

Purchased power expense from affiliates was $206 million in both the first quarter 2023 and 2022 and reflects a 14.3% increase in the volume of KWHs purchased, offset by a 14.1% decrease in the average cost per KWH purchased primarily due to higher coal prices.

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

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(21)	(4.1)

In the first quarter 2023, other operations and maintenance expenses were $496 million compared to $517 million for the corresponding period in 2022. The decrease was primarily due to decreases of $45 million in storm damage recovery as authorized in the 2022 ARP, $25 million in distribution and transmission expenses primarily associated with line maintenance, and $14 million in generation expenses primarily due to non-outage maintenance partially offset by scheduled generation outages. These decreases were partially offset by increases of $24 million in technology infrastructure and application production costs and $20 million from unregulated power delivery construction and maintenance and energy conservation projects, as well as a $12 million decrease in nuclear property insurance refunds. See Note 2 to the financial statements under "Georgia Power – Storm Damage Recovery" in Item 8 of the Form 10-K for additional information.

Depreciation and Amortization

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$57	16.2

In the first quarter 2023, depreciation and amortization was $408 million compared to $351 million for the corresponding period in 2022. The increase was primarily due to increases of $47 million resulting from higher depreciation rates as authorized in the 2022 ARP and $14 million associated with additional plant in service. See Note 5 to the financial statements under "Depreciation and Amortization" in Item 8 of the Form 10-K for additional information.

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AND RESULTS OF OPERATIONS (Continued)

Allowance for Equity Funds Used During Construction

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$8	25.0

In the first quarter 2023, allowance for equity funds used during construction was $40 million compared to $32 million for the corresponding period in 2022. The increase was primarily due to an increase in capital expenditures subject to AFUDC.

Interest Expense, Net of Amounts Capitalized

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$39	36.4

In the first quarter 2023, interest expense, net of amounts capitalized was $146 million compared to $107 million for the corresponding period in 2022. The increase was primarily associated with increases of approximately $21 million related to higher average outstanding borrowings and $19 million related to higher interest rates. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.

Income Taxes

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$23	76.7

In the first quarter 2023, income taxes were $53 million compared to $30 million for the corresponding period in 2022. The increase was primarily due to the flowback of certain excess deferred income taxes that ended in 2022, partially offset by lower pre-tax earnings. See Note (G) to the Condensed Financial Statements herein for additional information.

Mississippi Power

Net Income

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$16	38.1

Mississippi Power's net income in the first quarter 2023 was $58 million compared to $42 million for the corresponding period in 2022. The increase was primarily due to an increase in affiliate wholesale capacity revenues, partially offset by an increase in non-fuel operations and maintenance expenses.

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Retail Revenues

In the first quarter 2023, retail revenues were $236 million compared to $217 million for the corresponding period in 2022. Details of the changes in retail revenues were as follows:

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Rates and pricing	$	4	1.8	%
Sales growth	2		1.0
Weather	(6)		(2.8)
Fuel and other cost recovery	19		8.8
Retail revenues	$	19	8.8	%

Revenues associated with changes in rates and pricing increased in the first quarter 2023 when compared to the corresponding period in 2022 primarily due to new PEP rates that became effective for the first billing cycle of April 2022 and ECO Plan rates that became effective for the first billing cycle of May 2022. See Note 2 to the financial statements under "Mississippi Power – Performance Evaluation Plan" and " – Environmental Compliance Overview Plan" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the first quarter 2023 when compared to the corresponding period in 2022. Weather-adjusted residential KWH sales decreased 2.1% in the first quarter 2023 when compared to the corresponding period in 2022 due to a decrease in customer usage. Weather-adjusted commercial KWH sales increased 3.2% in the first quarter 2023 when compared to the corresponding period in 2022 due to an increase in customer usage. Industrial KWH sales increased 5.5% in the first quarter 2023 when compared to the corresponding period in 2022 primarily due to increases in the non-manufacturing, petroleum, and pipeline sectors, partially offset by decreases in the chemicals sector.

Fuel and other cost recovery revenues increased in the first quarter 2023 when compared to the corresponding period in 2022 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 for additional information.

Wholesale Revenues – Affiliates

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$33	78.6

In the first quarter 2023, wholesale revenues from sales to affiliates were $75 million compared to $42 million for the corresponding period in 2022. The increase was due to a $29 million increase in capacity revenues resulting from an increase in pricing and volume of generation reserves and a $17 million increase associated with higher KWH sales, partially offset by a $13 million decrease associated with lower natural gas prices.

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

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Other Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$3	37.5

In the first quarter 2023, other revenues were $11 million compared to $8 million for the corresponding period in 2022. The increase was due to an increase in unregulated sales associated with power delivery construction and maintenance projects.

Fuel and Purchased Power Expenses

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Fuel	$	21	16.7
Purchased power	(2)		(31.0)
Total fuel and purchased power expenses	$	19

In the first quarter 2023, total fuel and purchased power expenses were $151 million compared to $132 million for the corresponding period in 2022. The increase was due to a $12 million increase related to the volume of KWHs generated and a $7 million increase related to the average cost of fuel and purchased power.

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

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

	First Quarter 2023	First Quarter 2022
Total generation (in millions of KWHs)	4,443	4,074
Total purchased power (in millions of KWHs)	100	120
Sources of generation (percent) –
Gas	94	92
Coal	6	8
Cost of fuel, generated (in cents per net KWH) –
Gas	3.34	3.30
Coal	5.78	3.74
Average cost of fuel, generated (in cents per net KWH)	3.51	3.34
Average cost of purchased power (in cents per net KWH)	4.10	4.54

Fuel

In the first quarter 2023, fuel expense was $147 million compared to $126 million for the corresponding period in 2022. The increase was due to a 13.6% increase in the volume of KWHs generated by natural gas, a 1.2% increase in the average cost of natural gas per KWH generated, and a 54.5% increase in the average cost of coal per KWH generated, partially offset by a 17.3% decrease in the volume of KWHs generated by coal.

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AND RESULTS OF OPERATIONS (Continued)

Other Operations and Maintenance Expenses

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$6	7.9

In the first quarter 2023, other operations and maintenance expenses were $82 million compared to $76 million for the corresponding period in 2022. The increase was primarily due to increases of $2 million in technology infrastructure and application production costs and $2 million in unregulated power delivery construction and maintenance projects.

Income Taxes

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$5	62.5

In the first quarter 2023, income taxes were $13 million compared to $8 million for the corresponding period in 2022. The increase was primarily due to higher pre-tax earnings.

Southern Power

Net Income Attributable to Southern Power

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$30	41.7

Net income attributable to Southern Power in the first quarter 2023 was $102 million compared to $72 million for the corresponding period in 2022. The increase was primarily due to a gain on the sale of spare parts and higher income associated with tax equity partnerships.

Operating Revenues

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(31)	(5.8)

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

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are driven by fuel or purchased power prices are accompanied by an increase or decrease in fuel and purchased power costs and do not have a significant impact on net income.

Solar and Wind Energy Revenue

Southern Power's energy sales from solar and wind generating facilities are predominantly through long-term PPAs that do not have capacity revenue. Customers either purchase the energy output of a dedicated renewable facility through an energy charge or pay a fixed price related to the energy generated from the respective facility and sold to the grid. As a result, Southern Power's ability to recover fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors.

See FUTURE EARNINGS POTENTIAL – "Southern Power's Power Sales Agreements" in Item 7 of the Form 10-K for additional information regarding Southern Power's PPAs.

Operating Revenues Details

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

	First Quarter 2023		First Quarter 2022
	(in millions)
PPA capacity revenues	$	112	$	102
PPA energy revenues	277		345
Total PPA revenues	389		447
Non-PPA revenues	108		84
Other revenues	11		8
Total operating revenues	$	508	$	539

In the first quarter 2023, total operating revenues were $508 million, reflecting a $31 million, or 5.8%, decrease from the corresponding period in 2022. The decrease in operating revenues was primarily due to the following:

•PPA capacity revenues increased $10 million, or 9.8%, primarily due to a net increase in MW capacity under contract from natural gas PPAs and an increase associated with a change in rates from natural gas PPAs.

•PPA energy revenues decreased $68 million, or 19.7%, primarily due to a $38 million decrease in sales under existing natural gas PPAs resulting from a $43 million decrease in the price of fuel and purchased power, partially offset by a $5 million increase in the volume of KWHs sold. Also contributing to the decrease was a $21 million decrease in sales associated with expired natural gas PPAs, net of new natural gas PPAs.

•Non-PPA revenues increased $24 million, or 28.6%, due to a $58 million increase in the volume of KWHs sold through short-term sales, largely offset by a $34 million decrease in the market price of energy.

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Fuel and Purchased Power Expenses

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

	First Quarter 2023	First Quarter 2022
	(in billions of KWHs)
Generation	12.3	11.0
Purchased power	0.7	0.5
Total generation and purchased power	13.0	11.5
Total generation and purchased power (excluding solar, wind, fuel cells, and tolling agreements)	8.4	6.9

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:

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Fuel	$	(41)	(17.7)
Purchased power	5		23.8
Total fuel and purchased power expenses	$	(36)

In the first quarter 2023, total fuel and purchased power expenses decreased $36 million, or 14.2%, compared to the corresponding period in 2022. Fuel expense decreased $41 million due to an $84 million decrease associated with the average cost of fuel, partially offset by a $43 million increase associated with the volume of KWHs generated. Purchased power expense increased $5 million due to an $11 million increase associated with the volume of KWHs purchased, largely offset by a $7 million decrease associated with the average cost of purchased power.

Depreciation and Amortization

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$8	6.7

In the first quarter 2023, depreciation and amortization was $128 million compared to $120 million for the corresponding period in 2022. The increase was primarily due to capital improvements at natural gas generating facilities.

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Gain on Dispositions, Net

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$18	N/M

In the first quarter 2023, gain on dispositions, net was $20 million compared to $2 million for the corresponding period in 2022. The increase was primarily due to a $16 million gain on the sale of spare parts in 2023.

Interest Expense, Net of Amounts Capitalized

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(4)	(10.8)

In the first quarter 2023, interest expense, net of amounts capitalized was $33 million compared to $37 million for the corresponding period in 2022. The decrease was primarily due to lower average outstanding borrowings.

Income Taxes (Benefit)

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$5	41.7

In the first quarter 2023, income tax benefit was $7 million compared to $12 million for the corresponding period in 2022. The change was primarily due to higher pre-tax earnings in 2023. See Note (G) to the Condensed Financial Statements herein for additional information.

Net Loss Attributable to Noncontrolling Interests

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(18)	(40.0)

In the first quarter 2023, net loss attributable to noncontrolling interests was $63 million compared to $45 million for the corresponding period in 2022. The increased loss was primarily due to $16 million in higher HLBV loss allocations to wind tax equity partners due to higher wind PTCs in 2023.

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.

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.

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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. 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

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(10)	(3.1)

In the first quarter 2023, net income was $309 million compared to $319 million for the corresponding period in 2022. The decrease was primarily due to a $16 million decrease at gas marketing services primarily related to hedge losses, partially offset by a $7 million increase at gas distribution operations primarily due to rate increases and continued investment in infrastructure replacement.

Natural Gas Revenues

In the first quarter 2023, natural gas revenues were $1.9 billion compared to $2.1 billion for the corresponding period in 2022. Details of the changes in natural gas revenues were as follows:

	First Quarter 2023 vs. First Quarter 2022
	(change in millions)		(% change)
Infrastructure replacement programs and rate changes	$	50	2.4	%
Gas costs and other cost recovery	(199)		(9.7)
Gas marketing services	(21)		(1.0)
Other	(13)		(0.6)
Natural gas revenues	$	(183)	(8.9)	%

Revenues from infrastructure replacement programs and rate changes increased in the first quarter 2023 compared to the corresponding period in 2022 primarily due to rate increases at the natural gas distribution utilities 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 from gas costs and other cost recovery decreased in the first quarter 2023 compared to the corresponding period in 2022 primarily due to lower natural gas cost recovery associated with the timing of natural gas purchases and the recovery of those costs from customers. 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 first quarter 2023 compared to the corresponding period in 2022 primarily due to lower natural gas prices and the timing of unrealized hedge losses, partially offset by higher variable price spreads in Georgia and Illinois and higher customer count in Georgia.

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 the majority of any remaining exposure

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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.

	First Quarter			2023 vs. normal		2023 vs. 2022
	Normal(*)	2023	2022	warmer		warmer
	(in thousands)
Illinois	3,064	2,661	3,007	(13.2)	%	(11.5)	%
Georgia	1,329	908	1,251	(31.7)	%	(27.4)	%

(*)Normal represents the 10-year average from January 1, 2013 through March 31, 2022 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.

The following table provides the number of customers served by Southern Company Gas at March 31, 2023 and 2022:

	March 31,
	2023		2022		2023 vs. 2022
	(in thousands, except market share %)				(% change)
Gas distribution operations	4,375		4,358		0.4	%
Gas marketing services
Energy customers(*)	635		598		6.2	%
Market share of energy customers in Georgia	29.8	%	28.7	%

(*)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

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$(197)	(18.0)

Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from gas distribution operations. Cost of natural gas at gas distribution operations represented 85% of the total cost of natural gas in the first quarter 2023. See MANAGEMENT'S DISCUSSION AND ANALYSIS – RESULTS OF OPERATIONS – "Southern Company Gas – Cost of Natural Gas" in Item 7 of the Form 10-K and "Natural Gas Revenues" herein for additional information.

In the first quarter 2023, cost of natural gas was $0.9 billion compared to $1.1 billion for the corresponding period in 2022. The decrease reflects lower gas cost recovery as a result of a 31% decrease in natural gas prices in the first quarter 2023 compared to the corresponding period in 2022.

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

	First Quarter		2023 vs. 2022
	2023	2022
Gas distribution operations (mmBtu in millions)
Firm	258	304	(15.1)	%
Interruptible	25	25	—
Total	283	329	(14.0)	%
Gas marketing services (mmBtu in millions)
Firm:
Georgia	13	16	(18.8)	%
Illinois	3	3	—
Other	5	4	25.0
Interruptible large commercial and industrial	4	4	—
Total	25	27	(7.4)	%

Other Operations and Maintenance Expenses

Other operations and maintenance expenses were $305 million for both the first quarter 2023 and 2022 and reflect a $17 million increase in compensation and benefits, partially offset by a $12 million decrease in expenses passed through to customers primarily related to bad debt at gas distribution operations.

Interest Expense, Net of Amounts Capitalized

First Quarter 2023 vs. First Quarter 2022
(change in millions)	(% change)
$15	24.6

In the first quarter 2023, interest expense, net of amounts capitalized was $76 million compared to $61 million for the corresponding period in 2022. The increase primarily reflects higher interest rates and higher average outstanding debt. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings.

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Segment Information

Operating revenues, operating expenses, and net income for each segment are provided in the table below. See Note (K) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information.

	2023						2022
	Operating Revenues		Operating Expenses		Net Income		Operating Revenues		Operating Expenses		Net Income
	(in millions)						(in millions)
First Quarter
Gas distribution operations	$	1,618	$	1,264	$	221	$	1,803	$	1,475	$	214
Gas pipeline investments	8		3		31		8		3		29
Gas marketing services	246		175		50		243		150		66
All other	12		9		7		16		21		10
Intercompany eliminations	(9)		(5)		—		(12)		(12)		—
Consolidated	$	1,875	$	1,446	$	309	$	2,058	$	1,637	$	319

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.

In the first quarter 2023, net income increased $7 million, or 3.3%, when compared to the corresponding period in 2022, as described further below:

•Operating revenues decreased $185 million primarily due to lower gas cost over recovery, partially offset by 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 decreased $211 million primarily due to a $218 million decrease in cost of natural gas as a result of lower gas prices and lower volumes sold compared to 2022, partially offset by higher depreciation resulting from additional assets placed in service and higher compensation and benefits. The decrease in operating expenses also includes lower costs passed through directly to customers, primarily related to bad debt expenses and revenue taxes.

•Interest expense, net of amounts capitalized increased $13 million primarily due to higher interest rates and higher average outstanding debt.

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Gas Pipeline Investments

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

In the first quarter 2023, net income increased $2 million primarily due to higher earnings at SNG resulting from higher revenues primarily due to increased demand, partially offset by higher interest expense, net of amounts capitalized.

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 first quarter 2023, net income decreased $16 million, or 24.2%, when compared to the corresponding period in 2022 primarily due to a $25 million increase in operating expenses primarily resulting from a $22 million increase in cost of natural gas due to the timing of unrealized hedge losses, partially offset by lower gas prices and lower volumes sold. Net income also reflects a decrease of $6 million in income taxes as a result of lower pre-tax earnings.

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. All other included a natural gas storage facility in Texas through its sale in November 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information, including the sale of a natural gas storage facility in California expected to be completed later in 2023.

In the first quarter 2023, net income decreased $3 million when compared to the corresponding period in 2022. The change was primarily related to an increase in income taxes, largely offset by a decrease in operating expenses primarily related to lower depreciation in 2023.

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, other major factors are completing construction and start-up of Plant Vogtle Units 3 and 4, meeting the related cost and schedule projections, and completing the related cost recovery proceedings.

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.

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Global and U.S. economic conditions continue to be significantly affected by a series of demand and supply shocks that caused a global and national economic recession in 2020 and have been further impacted by the invasion of Ukraine and significant declines in labor force participation rates. The confluence of these disruptions has resulted in the highest levels of inflation globally in 40 years and driven a significant policy response by central banks across the global economy. The U.S. Federal Reserve has increased policy interest rates faster than any rate increase cycle in the last 40 years and to levels high enough to slow economic activity. These actions and impacts, including increased costs for goods and services and borrowing costs, have led to a slowing of some economic activity and a significantly increased risk of recession. Recent challenges facing small and midsize banks may tighten lending standards, cause uncertainty in the banking sector, and further reduce economic growth. Additionally, inflation remains elevated in part due to continued supply chain and labor market constraints. Electricity sales across all classes have recovered to pre-COVID-19 pandemic levels and customer growth at both the traditional electric operating companies and natural gas distribution utilities has remained strong. However, weakening economic activity increases the risk of slowing to declining energy sales. Additionally, the current economic environment has increased the uncertainty of future energy demand and operating costs. See RESULTS OF OPERATIONS herein for information on energy sales in the Southern Company system's service territory during the first three months of 2023.

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; continued availability of federal and state ITCs 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. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Income Tax Matters" in Item 7 of the Form 10-K for information regarding the Inflation Reduction Act's expansion of the availability of federal ITCs and PTCs.

The level of future earnings for Southern Company Gas' primary business of distributing natural gas and its complementary businesses in the gas pipeline investments and gas marketing services sectors depends on numerous factors. These factors include the natural gas distribution utilities' ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs, including those related to projected long-term demand growth, safety, system reliability and resiliency, natural gas, and capital expenditures, including expanding and improving the natural gas distribution systems; the completion and subsequent operation of ongoing infrastructure and other construction projects; customer creditworthiness; and certain policies to limit the use of natural gas, such as the potential across certain parts of the U.S. for state or municipal bans on the use of natural gas or policies designed to promote electrification. The volatility of natural gas prices has an impact on Southern Company Gas' customer rates, its long-term competitive position against other energy sources, and the ability of Southern Company Gas' gas marketing services business to capture value from locational and seasonal spreads. Additionally, changes in commodity prices, primarily driven by tight gas supplies, geopolitical events, and diminished gas production, subject a portion of Southern Company Gas' operations to earnings variability and may result in higher natural gas prices. Additional economic factors may contribute to this environment. The demand for natural gas may increase, which may cause natural gas prices to rise and drive higher volatility in the natural gas markets on a longer-term basis. Alternatively, a significant drop in oil and natural gas prices could lead to a consolidation of natural gas producers or reduced levels of natural gas production.

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; customer energy conservation practices; the use of alternative energy sources by customers; government incentives to reduce overall energy usage; fuel, labor, and material prices in an environment of heightened inflation and material and labor supply chain disruptions; and the price elasticity of

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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 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 "General Litigation Matters" and "Environmental Remediation" herein, for additional information.

Environmental Laws and Regulations

Air Quality

On February 13, 2023, the EPA published a final rule disapproving 19 state implementation plans (SIPs), including the States of Alabama and Mississippi, under the interstate transport (good neighbor) provisions of the Clean Air Act for the 2015 Ozone National Ambient Air Quality Standards (NAAQS). On March 14, 2023 and March 15, 2023, the State of Mississippi and Mississippi Power, respectively, challenged the EPA's disapproval of the Mississippi SIP in the U.S. Court of Appeals for the Fifth Circuit. On April 13, 2023 and April 14, 2023, the State of Alabama and Alabama Power, respectively, challenged the EPA's disapproval of the Alabama SIP in the U.S. Court of Appeals for the Eleventh Circuit. The ultimate impact of these cases cannot be determined at this time. As a result of the SIP disapprovals, on March 15, 2023, the EPA released the prepublication version of the 2015 Ozone NAAQS Good Neighbor federal implementation plan with initial compliance expected to begin in May 2023. The ultimate impact of the rule cannot be determined at this time; however, it will likely result in increased compliance costs for the traditional electric operating companies.

Water Quality

On March 29, 2023, the EPA published a proposed ELG Supplemental Rule revising certain effluent limits of the 2020 and 2015 ELG rules. The proposal imposes more stringent requirements for flue gas desulfurization wastewater, bottom ash transport water, and combustion residual leachate to be met no later than December 31, 2029. The EPA is also proposing that a limited number of facilities already achieving compliance with the 2020 ELG Reconsideration Rule be allowed to elect retirement or repowering by December 31, 2032 as opposed to meeting the new more stringent requirements. The proposal maintains the 2020 ELG Reconsideration Rule's permanent cessation of coal combustion subcategory allowing units to continue to operate until the end of 2028 without having to install additional technologies. A final rule is anticipated in 2024. The ultimate impact of this proposal cannot be determined at this time; however, it may result in significant compliance costs.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Regulatory Matters

See Note 2 to the financial statements in Item 8 of the Form 10-K, OVERVIEW – "Recent Developments" herein, and Note (B) to the Condensed Financial Statements herein for a discussion of regulatory matters related to Alabama Power, Georgia Power, Mississippi Power, and Southern Company Gas, including items that could impact the applicable Registrants' future earnings, cash flows, and/or financial condition.

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 in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Alabama Power – Certificates of Convenience and Necessity" for information regarding Alabama Power's construction of Plant Barry Unit 8.

Southern Company Gas is engaged in various infrastructure improvement programs designed to update or expand the natural gas distribution systems of the natural gas distribution utilities to improve reliability and resiliency, reduce emissions, and meet operational flexibility and growth. The natural gas distribution utilities recover their investment and a return associated with these infrastructure programs through their regulated rates. 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 "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.

Southern Power's Power Sales Agreements

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Southern Power's Power Sales Agreements" in Item 7 of the Form 10-K for additional information.

At March 31, 2023, 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 2027 and 90% through 2032, with an average remaining contract duration of approximately 12 years.

General Litigation and Other Matters

The Registrants are involved in various matters being litigated and/or regulatory and other matters that could affect future earnings, cash flows, and/or financial condition. The ultimate outcome of such pending or potential litigation against each Registrant and any subsidiaries or regulatory and other matters cannot be determined at this time; however, for current proceedings and/or matters not specifically reported herein or in Notes (B) and (C) to the Condensed Financial Statements herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings and/or matters would have a material effect on such Registrant's financial statements. See Notes (B) and (C) to the Condensed Financial Statements for a discussion of various contingencies, including matters being litigated, regulatory matters, and other matters which may affect future earnings potential.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

ACCOUNTING POLICIES

See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES in Item 7 of the Form 10-K for a complete discussion of the Registrants' critical accounting policies and estimates, as well as recently issued accounting standards.

The Registrants prepare their financial statements in accordance with GAAP. Significant accounting policies are described in the notes to the financial statements in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on the Registrants' results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements.

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" in Item 7 of the Form 10-K for additional information. The financial condition of each Registrant remained stable at March 31, 2023. 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 first quarter 2023, the market price of Southern Company's common stock was $69.58 per share (based on the closing price as reported on the NYSE) and the book value was $28.00 per share, representing a market-to-book ratio of 249%, compared to $71.41, $27.93, and 256%, respectively, at the end of 2022. Southern Company's common stock dividend for the first quarter 2023 was $0.68 per share compared to $0.66 per share in the first quarter 2022.

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 and, for the traditional electric operating companies, operating cash flows related to fuel cost under recovery. The fuel cost under recovery balances are primarily the result of higher than forecasted prices for natural gas and purchased power. See Note (B) to the Condensed Financial Statements herein under "Georgia Power – Fuel Cost Recovery" for additional information.

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 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 under "Southern Power" in Item 8 of the Form 10-K for additional information regarding Southern Power's plant acquisitions and construction projects.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

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, 2022.

Sources of Capital

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" in Item 7 of the Form 10-K for additional information. Southern Company intends to meet its future capital needs through operating cash flows, borrowings from financial institutions, and debt, hybrid, and/or equity issuances. Equity capital can be provided from any combination of Southern Company's stock plans, private placements, or public offerings.

The Subsidiary Registrants plan to obtain the funds to meet their future capital needs from sources similar to those they used in the past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity contributions from Southern Company. Operating cash flows provide a substantial portion of the Registrants' cash needs. In addition, Southern Power plans to utilize tax equity partnership contributions (as discussed further herein). Georgia Power intends to continue utilizing short-term floating rate bank loans and commercial paper issuances to fund operating cash flows related to fuel cost under recovery.

The amount, type, and timing of any financings in 2023, 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 three months ended March 31, 2023, Southern Power obtained tax equity funding for existing tax equity partnerships totaling $21 million. See Note 1 to the financial statements under "General" in Item 8 of the Form 10-K 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 March 31, 2023, the amount of subsidiary retained earnings restricted to dividend totaled $1.6 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 March 31, 2023 for the applicable Registrants:

At March 31, 2023	Southern Company		Georgia Power		Mississippi Power		Southern Company Gas
	(in millions)
Current liabilities in excess of current assets	$	4,338	$	2,820	$	91	$	355

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 March 31, 2023, the Registrants' unused committed credit arrangements with banks were as follows:

At March 31, 2023	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	$	225	$	587	$	1,748	$	30	$	7,564

(a)At March 31, 2023, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $25 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 March 31, 2023 was approximately $1.7 billion (comprised of approximately $789 million at Alabama Power, $819 million at Georgia Power, and $69 million at Mississippi Power). In addition, at March 31, 2023, Alabama Power and Georgia Power had approximately $120 million and $285 million, respectively, 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 March 31, 2023				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	$	2,554	5.5	%	$	2,753	5.2	%	$	3,270
Alabama Power	170		5.1		83		4.8		230
Georgia Power	1,965		5.5		1,671		5.3		2,025
Mississippi Power	126		5.6		49		5.1		136
Southern Power	165		5.6		179		5.1		267
Southern Company Gas:
Southern Company Gas Capital	$	120	5.6	%	$	215	4.9	%	$	297
Nicor Gas	—		—		239		4.8		483
Southern Company Gas Total	$	120	5.6	%	$	454	4.9	%

(*)Average and maximum amounts are based upon daily balances during the three-month period ended March 31, 2023.

Analysis of Cash Flows

Net cash flows provided from (used for) operating, investing, and financing activities for the three months ended March 31, 2023 and 2022 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)
Three Months Ended March 31, 2023
Operating activities	$	844	$	30	$	(53)	$	(3)	$	135	$	978
Investing activities	(2,118)		(509)		(1,117)		(117)		4		(379)
Financing activities	454		219		850		79		(146)		(593)
Three Months Ended March 31, 2022
Operating activities	$	1,592	$	154	$	361	$	(16)	$	117	$	1,024
Investing activities	(1,555)		(365)		(809)		(68)		(37)		(271)
Financing activities	(193)		504		441		32		(76)		(768)

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 decreased $0.7 billion for the three months ended March 31, 2023 as compared to the corresponding period in 2022 primarily due to the timing of vendor payments and the timing of fossil fuel stock purchases, partially offset by increased fuel cost recovery and the timing of customer receivable collections.

The net cash used for investing activities for the three months ended March 31, 2023 was primarily related to the Subsidiary Registrants' construction programs.

The net cash provided from financing activities for the three months ended March 31, 2023 was primarily related to net issuances of long-term debt, partially offset by common stock dividend payments.

Alabama Power

Net cash provided from operating activities decreased $124 million for the three months ended March 31, 2023 as compared to the corresponding period in 2022 primarily due to the timing of vendor payments and fuel stock purchases, partially offset by increased fuel cost recovery.

The net cash used for investing activities for the three months ended March 31, 2023 was primarily related to gross property additions, including approximately $23 million related to the construction of Plant Barry Unit 8. See Note (B) to the Condensed Financial Statements under "Alabama Power" herein for additional information.

The net cash provided from financing activities for the three months ended March 31, 2023 was primarily related to capital contributions from Southern Company and an increase in short-term borrowings, partially offset by common stock dividend payments.

Georgia Power

Net cash used for operating activities increased $414 million for the three months ended March 31, 2023 as compared to the corresponding period in 2022 primarily due to the timing of vendor payments, higher payments for property taxes and municipal franchise fees, and the timing of fossil fuel stock purchases, partially offset by the timing of customer receivable collections.

The net cash used for investing activities for the three months ended March 31, 2023 was primarily related to gross property additions, including a total of approximately $225 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 three months ended March 31, 2023 was primarily related to capital contributions from Southern Company, a net increase in short-term borrowings, and reofferings of pollution control revenue bonds, partially offset by common stock dividend payments.

Mississippi Power

Net cash used for operating activities decreased $13 million for the three months ended March 31, 2023 as compared to the corresponding period in 2022 primarily due to the timing of customer receivable collections, partially offset by the timing of vendor payments.

The net cash used for investing activities for the three months ended March 31, 2023 was primarily related to gross property additions.

The net cash provided from financing activities for the three months ended March 31, 2023 was primarily related to an increase in short-term borrowings, partially offset by common stock dividend payments.

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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 $18 million for the three months ended March 31, 2023 as compared to the corresponding period in 2022 primarily due to the timing of customer receivable collections, partially offset by the timing of vendor payments.

The net cash provided from investing activities for the three months ended March 31, 2023 was primarily related to the sale of equity method investments in wind and battery energy storage projects, partially offset by ongoing construction activities.

The net cash used for financing activities for the three months ended March 31, 2023 was primarily related to common stock dividend payments, net repayments of short-term debt, and net distributions to noncontrolling interests.

Southern Company Gas

Net cash provided from operating activities decreased $46 million for the three months ended March 31, 2023 as compared to the corresponding period in 2022 primarily due to lower gas cost recovery, timing of vendor payments, and a change in natural gas for sale, net of temporary LIFO liquidation due to use of stored natural gas, partially offset by the timing of customer receivable collections.

The net cash used for investing activities for the three months ended March 31, 2023 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 three months ended March 31, 2023 was primarily related to repayment of short-term debt and common stock dividend payments, partially offset by capital contributions from Southern Company.

Significant Balance Sheet Changes

Southern Company

Significant balance sheet changes for the three months ended March 31, 2023 included:

•an increase of $1.5 billion in long-term debt (including securities due within one year) related to new issuances;

•a decrease of $1.2 billion in accounts payable primarily related to the timing of vendor payments;

•an increase of $1.1 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants' construction programs;

•a decrease of $0.9 billion in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Southern Company" herein;

•a decrease of $0.5 billion in accrued compensation due to the timing of payments;

•an increase of $0.5 billion in accumulated deferred income taxes primarily related to the expected utilization of ITCs in 2023, as well as an increase in property-related timing differences; and

•a decrease of $0.4 billion in unbilled revenues primarily related to seasonality.

See "Financing Activities" herein and Notes (B), (F), and (G) 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 three months ended March 31, 2023 included:

•an increase of $300 million in common stockholder's equity primarily due to capital contributions from Southern Company, partially offset by dividends paid to Southern Company;

•a decrease of $261 million in other accounts payable primarily due to the timing of vendor payments;

•a decrease of $260 million in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Alabama Power" herein;

•a decrease of $201 million in affiliated accounts payable due to the timing of payments to affiliates; and

•an increase of $170 million in notes payable primarily due to an increase in commercial paper borrowings.

Georgia Power

Significant balance sheet changes for the three months ended March 31, 2023 included:

•an increase of $861 million in total property, plant, and equipment primarily related to the construction of generation, transmission, and distribution facilities, including $270 million for Plant Vogtle Units 3 and 4;

•an increase of $585 million in common stockholder's equity primarily due to capital contributions from Southern Company and net income, partially offset by dividends paid to Southern Company;

•an increase of $365 million in notes payable primarily due to an increase in commercial paper;

•a decrease of $364 million in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Georgia Power" herein;

•a decrease of $322 million in affiliated accounts payable due to the timing of payments to affiliates;

•a decrease of $286 million in accrued taxes primarily related to payments for municipal franchise fees and property taxes; and

•an increase of $210 million in long-term debt (including securities due within one year) primarily due to reofferings of pollution control revenue bonds.

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

Mississippi Power

Significant balance sheet changes for the three months ended March 31, 2023 included:

•an increase of $126 million in notes payable due to an increase in short-term borrowings;

•a decrease of $62 million in accrued taxes primarily due to the payment of ad valorem taxes;

•decreases of $56 million in affiliated receivables and $52 million in affiliated accounts payable primarily due to fluctuations in affiliate sales/purchases and the timing of payments;

•an increase of $48 million in total property, plant, and equipment primarily related to the construction of transmission and distribution facilities; and

•a decrease of $41 million in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Mississippi Power" herein.

See "Financing Activities – 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

Significant balance sheet changes for the three months ended March 31, 2023 included:

•increases of $302 million in accumulated deferred income tax liabilities and $286 million in prepaid income taxes primarily related to the expected utilization of ITCs in 2023 and

•a decrease of $120 million in total property, plant, and equipment primarily due to continued depreciation of assets.

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

Southern Company Gas

Significant balance sheet changes for the three months ended March 31, 2023 included:

•a decrease of $648 million in notes payable due to repayments of short-term debt and commercial paper borrowings;

•an increase of $356 million in common stockholder's equity related to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company;

•a decrease of $340 million in other accounts payable due to seasonality and the timing of vendor payments;

•a decrease of $268 million in total accounts receivable primarily related to a decrease of $235 million in unbilled revenues as a result of seasonality;

•a decrease of $222 million in natural gas for sale primarily due to the use of stored natural gas; and

•an increase of $208 million in total property, plant, and equipment primarily related to the construction of transportation and distribution assets and additional infrastructure investment.

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 three months of 2023:

	Issuances/Reofferings						Maturities and Redemptions
Company	Senior Notes		Revenue Bonds		Other Long-Term Debt		Other Long- Term Debt(*)
	(in millions)
Southern Company parent	$	1,725	$	—	$	—	$	550
Alabama Power	—		—		16		—
Georgia Power	—		229		—		22
Southern Company Gas	—		—		8		—
Other	—		—		—		3
Southern Company	$	1,725	$	229	$	24	$	575

(*)Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization payments totaling $21 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 three months of 2022, Southern Company issued approximately 1.6 million shares of common stock primarily through employee equity compensation plans and received proceeds of approximately $15 million.

In January 2023, Southern Company redeemed all $550 million aggregate principal amount of its Series 2016B Junior Subordinated Notes due March 15, 2057.

In February 2023, Southern Company issued $1.5 billion aggregate principal amount of its Series 2023A 3.875% Convertible Senior Notes due December 15, 2025 (Series 2023A Convertible Senior Notes) in a private offering. In March 2023, Southern Company issued an additional $225 million aggregate principal amount of the Series 2023A Convertible Senior Notes upon the exercise by the initial purchasers of their over-allotment option. See Note (F) to the Condensed Financial Statements under "Convertible Senior Notes" herein for additional information.

Alabama Power

During the first quarter 2023, a subsidiary of Alabama Power borrowed $16 million under a $39 million long-term floating rate bank loan entered into in December 2022 with a maturity date of December 12, 2029.

Georgia Power

In March 2023, Georgia Power reoffered to the public the following pollution control revenue bonds that previously had been purchased and were held by Georgia Power at December 31, 2022:

•approximately $28 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), Second Series 2006;

•approximately $89 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), Second Series 2009;

•approximately $49 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), First Series 2012;

•approximately $18 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Scherer Project), First Series 2013; and

•$46 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 1996.

Also in March 2023, Georgia Power borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a mutually agreed upon rate and payable on demand. Subsequent to March 31, 2023, Georgia Power borrowed an additional $150 million under the arrangement.

Also in March 2023, Georgia Power repaid at maturity a $200 million short-term floating rate bank loan entered into in March 2022.

Subsequent to March 31, 2023, Georgia Power repaid at maturity $100 million aggregate principal amount of its Series N 5.750% Senior Notes.

Also subsequent to March 31, 2023, Georgia Power repaid at maturity a $200 million short-term floating rate bank loan entered into in April 2022.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Mississippi Power

In March 2023, Mississippi Power borrowed $50 million of short-term debt pursuant to its $125 million revolving credit arrangement bearing interest based on term SOFR.

Southern Power

In January 2023, Southern Power borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a mutually agreed upon rate and payable on demand.

Southern Company Gas

In February 2023, Nicor Gas repaid its $150 million and $50 million short-term floating rate bank loans entered into in February 2022 and March 2022, respectively.

Credit Rating Risk

At March 31, 2023, 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 March 31, 2023 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	407		2		60		1		345		—
At BB+ and/or Ba1 or below	2,086		422		937		320		1,233		69

(*)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 March 31, 2023.

The amounts in the previous table for the traditional electric operating companies and Southern Power include certain agreements that could require collateral if either Alabama Power or Georgia Power has a credit rating change to below investment grade. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. Additionally, a credit rating downgrade could impact the ability of the Registrants to access capital markets and would be likely to impact the cost at which they do so.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

During the three months ended March 31, 2023, 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 control over financial reporting.

There have been no changes in Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended) during the first quarter 2023 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)	-	Twenty-Seventh Supplemental Indenture to Senior Note Indenture dated as of February 28, 2023, providing for the issuance of the Series 2023A Convertible Senior Notes due December 15, 2025. (Designated in Form 8-K dated February 28, 2023, File No. 1-3526, as Exhibit 4.2.)
	(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, 2022, File No. 1-3526 as Exhibit 24(a)1.)
	Alabama Power
	(b)1	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2022, File No. 1-3164 as Exhibit 24(b)1.)
*	(b)2	-	Power of Attorney of Moses H. Feagin.
	Georgia Power
	(c)1	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2022, File No. 1-6468 as Exhibit 24(c)1.)
*	(c)2	-	Power of Attorney of Kimberly S. Greene.
	Mississippi Power
	(d)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2022, File No. 001-11229 as Exhibit 24(d)1.)
	Southern Power
	(e)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2022, File No. 001-37803 as Exhibit 24(e)1.)
	Southern Company Gas
	(f)1	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2022, File No. 1-14174 as Exhibit 24(f)1.)
*	(f)2	-	Power of Attorney of James Y. Kerr II.

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	(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.
	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.

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	Mississippi Power
*	(d)	-	Certificate of Mississippi Power's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	Southern Power
*	(e)	-	Certificate of Southern Power Company's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	Southern Company Gas
*	(f)	-	Certificate of Southern Company Gas' Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	(101) Interactive Data Files
*	INS	-	Inline XBRL Instance Document – The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.
*	SCH	-	Inline XBRL Taxonomy Extension Schema Document
*	CAL	-	Inline XBRL Taxonomy Calculation Linkbase Document
*	DEF	-	Inline XBRL Definition Linkbase Document
*	LAB	-	Inline XBRL Taxonomy Label Linkbase Document
*	PRE	-	Inline XBRL Taxonomy Presentation Linkbase Document
	(104) Cover Page Interactive Data File
*			Formatted as inline XBRL with applicable taxonomy extension information contained in Exhibits 101.

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THE SOUTHERN COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.

	THE SOUTHERN COMPANY
By	Thomas A. Fanning
	Chairman 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: April 26, 2023

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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	J. Jeffrey Peoples
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Moses H. Feagin
	Executive Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 26, 2023

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

Date: April 26, 2023

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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	Matthew P. Grice
	Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 26, 2023

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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: April 26, 2023

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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	James Y. Kerr II
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Grace A. Kolvereid
	Executive Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 26, 2023

141

EX-24.B2

Exhibit 24(b)2

Moses H. Feagin Executive Vice President, Chief Financial Officer & Treasurer 600 North 18th Street
Post Office Box 2641
Birmingham, Alabama 35291
Tel   205 257 1000

March 13, 2023

Daniel S. Tucker and Melissa K. Caen

Mr. Tucker and Ms. Caen:

As an officer of Alabama 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 March 31, 2023, June 30, 2023 and September 30, 2023 and any necessary or appropriate amendment or amendments to such reports or to the Company’s Annual Report on Form 10-K for the year ended December 31, 2022, 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/Moses H. Feagin

Moses H. Feagin

EX-24.C2

Exhibit 24(c)2

April 3, 2023

Aaron P. Abramovitz, Daniel S. Tucker and Melissa K. Caen

Gentlemen and Ms. Caen:

As an officer of Georgia 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 March 31, 2023, June 30, 2023 and September 30, 2023 and any necessary or appropriate amendment or amendments to such reports or to the Company’s Annual Report on Form 10-K for the year ended December 31, 2022, 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/Kimberly S. Greene

Kimberly S. Greene

EX-24.F2

Exhibit 24(f)2

April 4, 2023

Myra C. Bierria and Melissa K. Caen

Ms. Bierria and Ms. Caen:

As an officer of Southern Company Gas, 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 March 31, 2023, June 30, 2023 and September 30, 2023 and any necessary or appropriate amendment or amendments to such reports or to the Company’s Annual Report on Form 10-K for the year ended December 31, 2022, 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/James Y. Kerr II

James Y. Kerr II

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:  April 26, 2023

/s/Thomas A. Fanning

Thomas A. Fanning

Chairman 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: April 26, 2023

/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, J. Jeffrey Peoples, 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:  April 26, 2023

/s/J. Jeffrey Peoples

J. Jeffrey Peoples

Chairman, President and Chief Executive Officer

EX-31.B2

Exhibit 31(b)2

ALABAMA 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 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:  April 26, 2023

/s/Moses H. Feagin

Moses H. Feagin

Executive Vice President, Chief Financial Officer
and Treasurer

EX-31.C1

Exhibit 31(c)1

GEORGIA POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Kimberly S. Greene, 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:  April 26, 2023

/s/Kimberly S. Greene

Kimberly S. Greene

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:  April 26, 2023

/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:  April 26, 2023

/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, Matthew P. Grice, 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:  April 26, 2023

/s/Matthew P. Grice

Matthew P. Grice

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:   April 26, 2023

/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:  April 26, 2023

/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, James Y. Kerr II, 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:  April 26, 2023

/s/James Y. Kerr II

James Y. Kerr II

Chairman, President and Chief

 Executive Officer

EX-31.F2

Exhibit 31(f)2

SOUTHERN COMPANY GAS

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Grace A. Kolvereid, 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:  April 26, 2023

/s/Grace A. Kolvereid

Grace A. Kolvereid

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 March 31, 2023, 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 March 31, 2023, 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 March 31, 2023, 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 and
Chief Executive Officer

/s/Daniel S. Tucker

Daniel S. Tucker

Executive Vice President and
Chief Financial Officer

April 26, 2023

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 March 31, 2023, 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 March 31, 2023, 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 March 31, 2023, fairly presents, in all material respects, the financial condition and results of operations of Alabama Power Company.

/s/J. Jeffrey Peoples

J. Jeffrey Peoples

Chairman, President and Chief Executive Officer

/s/Moses H. Feagin

Moses H. Feagin

Executive Vice President,
Chief Financial Officer and Treasurer

April 26, 2023

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 March 31, 2023, 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 March 31, 2023, 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 March 31, 2023, fairly presents, in all material respects, the financial condition and results of operations of Georgia Power Company.

/s/Kimberly S. Greene

Kimberly S. Greene

Chairman, President and Chief Executive Officer

/s/Aaron P. Abramovitz

Aaron P. Abramovitz

Executive Vice President, Chief Financial Officer and Treasurer

April 26, 2023

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 March 31, 2023, 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 March 31, 2023, 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 March 31, 2023, 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/Matthew P. Grice

Matthew P. Grice

Vice President, Treasurer and
Chief Financial Officer

April 26, 2023

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 March 31, 2023, 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 March 31, 2023, 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 March 31, 2023, 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

April 26, 2023

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 March 31, 2023, 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 March 31, 2023, 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 March 31, 2023, fairly presents, in all material respects, the financial condition and results of operations of Southern Company Gas.

/s/James Y. Kerr II

James Y. Kerr II

Chairman, President and Chief Executive Officer

/s/Grace A. Kolvereid

Grace A. Kolvereid

Executive Vice President, Chief Financial

Officer and Treasurer

April 26, 2023

XML

Cover Page	3 Months Ended
	Mar. 31, 2023 shares
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2023
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)	1,090,402,540
Entity Central Index Key	0000092122
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q1
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
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
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 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
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues:
Total operating revenues	$ 6,480	$ 6,648
Operating Expenses:
Other operations and maintenance	1,482	1,516
Depreciation and amortization	1,111	892
Taxes other than income taxes	394	372
Gain on dispositions, net	(42)	(23)
Total operating expenses	5,262	5,264
Operating Income	1,218	1,384
Other Income and (Expense):
Allowance for equity funds used during construction	65	51
Earnings from equity method investments	48	46
Interest expense, net of amounts capitalized	(582)	(462)
Other income (expense), net	147	145
Total other income and (expense)	(322)	(220)
Earnings Before Income Taxes	896	1,164
Income taxes (benefit)	97	173
Net Income	799	991
Dividends on preferred stock of subsidiaries	0	4
Net loss attributable to noncontrolling interests	(63)	(45)
Net Income	$ 862	$ 1,032
Earnings per share -
Basic (in dollars per share)	$ 0.79	$ 0.97
Diluted (in dollars per share)	$ 0.79	$ 0.97
Average number of shares of common stock outstanding — (in millions)
Basic (in shares)	1,091	1,063
Diluted (in shares)	1,098	1,069
Retail electric revenues
Operating Revenues:
Total operating revenues	$ 3,599	$ 3,613
Wholesale Electric
Operating Revenues:
Total operating revenues	599	664
Other electric revenues
Operating Revenues:
Total operating revenues	190	177
Natural Gas
Operating Revenues:
Total operating revenues	1,875	2,058
Natural gas
Operating Expenses:
Total cost of sales	898	1,095
Alternative revenue programs
Operating Revenues:
Total operating revenues	12	0
Other revenues
Operating Revenues:
Total operating revenues	217	136
Operating Expenses:
Total cost of sales	127	69
Fuel
Operating Expenses:
Total cost of sales	1,050	1,111
Purchased power
Operating Expenses:
Total cost of sales	$ 242	$ 232

XML

Condensed Consolidated Statements of Income (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Total operating revenues	$ 6,480	$ 6,648
Natural Gas
Total operating revenues	1,875	2,058
Alternative revenue programs
Total operating revenues	$ 12	$ 0

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - Southern - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Comprehensive Income [Abstract]
Net income	$ 799	$ 991
Qualifying hedges:
Changes in fair value, net of tax	(63)	19
Reclassification adjustment for amounts included in net income, net of tax	19	20
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	0	3
Total other comprehensive income (loss)	(44)	42
Comprehensive Income	755	1,033
Dividends on preferred stock of subsidiaries	0	4
Comprehensive loss attributable to noncontrolling interests	(63)	(45)
Comprehensive Income	$ 818	$ 1,074

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Comprehensive Income [Abstract]
Changes in fair value, tax	$ (23)	$ 8
Qualifying hedges, reclassification adjustment, tax	7	6
Reclassification adjustment for amounts included in net income, tax	$ 0	$ 1

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) - Southern - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net income (loss)	$ 799	$ 991
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,233	989
Allowance for equity funds used during construction	(65)	(51)
Pension, postretirement, and other employee benefits	(126)	(123)
Settlement of asset retirement obligations	(113)	(87)
Stock based compensation expense	92	85
Natural gas cost under recovery – long-term	0	162
Retail fuel cost under recovery – long-term	454	(130)
Other, net	51	79
Changes in certain current assets and liabilities —
Receivables	319	(217)
Prepayments	(100)	(86)
Fossil fuel stock	(203)	39
Materials and supplies	(98)	(28)
Natural gas for sale, net of temporary LIFO liquidation	267	450
Other current assets	143	8
Accounts payable	(1,056)	132
Accrued taxes	(237)	(58)
Accrued compensation	(478)	(470)
Accrued interest	(127)	(128)
Natural gas cost over recovery	117	0
Other current liabilities	(28)	35
Net cash provided from operating activities	844	1,592
Investing Activities:
Property additions	(1,850)	(1,419)
Nuclear decommissioning trust fund purchases	(256)	(294)
Nuclear decommissioning trust fund sales	251	289
Proceeds from dispositions	103	91
Cost of removal, net of salvage	(135)	(227)
Construction payables	(140)	23
Other investing activities	(91)	(18)
Net cash used for investing activities	(2,118)	(1,555)
Financing Activities:
Increase in notes payable, net	187	137
Proceeds —
Long-term debt	1,979	700
Short-term borrowings	100	850
Common stock	15	38
Redemptions and repurchases —
Long-term debt	(575)	(977)
Short-term borrowings	(400)	(100)
Capital contributions from noncontrolling interests	21	73
Distributions to noncontrolling interests	(48)	(97)
Payment of common stock dividends	(742)	(702)
Other financing activities	(83)	(115)
Net cash provided from (used for) financing activities	454	(193)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(820)	(156)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	2,037	1,829
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,217	1,673
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	652	515
Income taxes, net	(9)	(8)
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	833	863
Right-of-use assets obtained under operating leases	26	3
Right-of-use assets obtained under finance leases	1	0
Reassessment of right-of-use assets under operating leases	$ 0	$ 40

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Cash Flows [Abstract]
Net cash paid for capitalized interest	$ 32	$ 23

XML

Condensed Consolidated Balance Sheets (Unaudited) - Southern - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash and cash equivalents	$ 1,053	$ 1,917
Receivables —
Customer accounts	1,890	2,128
Unbilled revenues	596	1,012
Deferred under recovered fuel clause revenues	1,702	2,056
Other accounts and notes	510	637
Accumulated provision for uncollectible accounts	(80)	(71)
Materials and supplies	1,756	1,664
Fossil fuel for generation	778	575
Natural gas for sale	216	438
Prepaid expenses	626	347
Assets from risk management activities, net of collateral	53	115
Regulatory assets – asset retirement obligations	342	332
Natural gas cost under recovery	0	108
Other regulatory assets	936	860
Other current assets	395	344
Total current assets	9,555	10,416
Property, Plant, and Equipment:
In service	118,690	117,529
Less: Accumulated depreciation	35,990	35,297
Plant in service, net of depreciation	82,700	82,232
Other utility plant, net	571	599
Nuclear fuel, at amortized cost	849	843
Construction work in progress	11,510	10,896
Total property, plant, and equipment	95,630	94,570
Other Property and Investments:
Goodwill	5,161	5,161
Nuclear decommissioning trusts, at fair value	2,245	2,145
Equity investments in unconsolidated subsidiaries	1,408	1,443
Other intangible assets, net of amortization	397	406
Miscellaneous property and investments	616	602
Total other property and investments	9,827	9,757
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,505	1,531
Deferred charges related to income taxes	876	866
Prepaid pension costs	2,384	2,290
Unamortized loss on reacquired debt	234	238
Under recovered fuel clause revenues	484	10
Regulatory assets – asset retirement obligations, deferred	5,701	5,764
Other regulatory assets, deferred	5,886	5,918
Other deferred charges and assets	1,456	1,485
Total deferred charges and other assets	19,744	20,148
Total Assets	134,756	134,891
Current Liabilities:
Securities due within one year	4,363	4,285
Notes payable	2,554	2,609
Accounts payable	2,365	3,525
Customer deposits	475	502
Accrued taxes —
Accrued income taxes	52	60
Other accrued taxes	435	764
Accrued interest	487	614
Accrued compensation	617	1,127
Asset retirement obligations	709	694
Liabilities from risk management activities, net of collateral	318	178
Operating lease obligations	199	197
Natural gas cost over recovery	117	0
Other regulatory liabilities	287	382
Other current liabilities	915	787
Total current liabilities	13,893	15,724
Long-term Debt	52,060	50,656
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	10,488	10,036
Deferred credits related to income taxes	5,107	5,235
Accumulated deferred ITCs	2,112	2,133
Employee benefit obligations	1,222	1,238
Operating lease obligations, deferred	1,374	1,388
Asset retirement obligations, deferred	10,209	10,146
Other cost of removal obligations	1,921	1,903
Other regulatory liabilities, deferred	690	733
Other deferred credits and liabilities	1,118	1,167
Total deferred credits and other liabilities	34,241	33,979
Total Liabilities	100,194	100,359
Total Stockholders' Equity	34,562	34,532
Total Liabilities and Stockholders' Equity	$ 134,756	$ 134,891

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Condensed Consolidated Balance Sheets (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Other intangible assets, amortization	$ 350	$ 340

XML

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, 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
Beginning balance (in shares) at Dec. 31, 2022		1,090
Beginning balance (in shares) at Dec. 31, 2022			(1)
Beginning balance at Dec. 31, 2022	34,532	$ 5,417	$ (53)	13,673	11,538	(167)	4,124
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	799				862		(63)
Other comprehensive income (loss)	(44)					(44)
Stock issued (in shares)		2
Stock issued	15	$ 4		11
Stock-based compensation	29			29
Cash dividends on common stock	(742)				(742)
Capital contributions from noncontrolling interests	21						21
Distributions to noncontrolling interests	(48)						(48)
Other	0		$ (2)	2
Ending balance (in shares) at Mar. 31, 2023		1,092
Ending balance (in shares) at Mar. 31, 2023			(1)
Ending balance at Mar. 31, 2023	$ 34,562	$ 5,421	$ (55)	$ 13,715	$ 11,658	$ (211)	$ 4,034

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - Southern (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Stockholders' Equity [Abstract]
Cash dividends (in dollars per share)	$ 0.68	$ 0.66

XML

Condensed Statements of Income (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues:
Total operating revenues	$ 6,480	$ 6,648
Operating Expenses:
Other operations and maintenance	1,482	1,516
Depreciation and amortization	1,111	892
Taxes other than income taxes	394	372
Total operating expenses	5,262	5,264
Operating Income	1,218	1,384
Other Income and (Expense):
Allowance for equity funds used during construction	65	51
Interest expense, net of amounts capitalized	(582)	(462)
Total other income (expense), net	147	145
Total other income and (expense)	(322)	(220)
Earnings Before Income Taxes	896	1,164
Income taxes (benefit)	97	173
Net income	799	991
Dividends on preferred stock of subsidiaries	0	4
Net Income	862	1,032
Retail electric revenues
Operating Revenues:
Total operating revenues	3,599	3,613
Wholesale Electric
Operating Revenues:
Total operating revenues	599	664
Other electric revenues
Operating Revenues:
Total operating revenues	190	177
Natural Gas
Operating Revenues:
Total operating revenues	1,875	2,058
Other revenues
Operating Revenues:
Total operating revenues	217	136
Operating Expenses:
Total cost of sales	127	69
Fuel
Operating Expenses:
Total cost of sales	1,050	1,111
Purchased power
Operating Expenses:
Total cost of sales	242	232
Alabama Power
Operating Revenues:
Total operating revenues	1,647	1,649
Operating Expenses:
Other operations and maintenance	424	409
Depreciation and amortization	345	215
Taxes other than income taxes	115	104
Total operating expenses	1,352	1,154
Operating Income	295	495
Other Income and (Expense):
Allowance for equity funds used during construction	21	16
Interest expense, net of amounts capitalized	(103)	(89)
Total other income (expense), net	40	36
Total other income and (expense)	(42)	(37)
Earnings Before Income Taxes	253	458
Income taxes (benefit)	(2)	107
Net income	255	351
Dividends on preferred stock of subsidiaries	0	4
Net Income	255	347
Alabama Power | Retail electric revenues
Operating Revenues:
Total operating revenues	1,381	1,379
Alabama Power | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	141	114
Alabama Power | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	19	65
Alabama Power | Other revenues
Operating Revenues:
Total operating revenues	106	91
Alabama Power | Fuel
Operating Expenses:
Total cost of sales	308	333
Alabama Power | Purchased power
Operating Expenses:
Total cost of sales	101	67
Alabama Power | Purchased power, affiliates
Operating Expenses:
Total cost of sales	$ 59	$ 26

XML

Condensed Statements of Comprehensive Income (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income	$ 799	$ 991
Qualifying hedges:
Changes in fair value, net of tax	(63)	19
Reclassification adjustment for amounts included in net income, net of tax	19	20
Total other comprehensive income (loss)	(44)	42
Comprehensive Income	755	1,033
Alabama Power
Net income	255	351
Qualifying hedges:
Changes in fair value, net of tax	0	(1)
Reclassification adjustment for amounts included in net income, net of tax	0	1
Total other comprehensive income (loss)	0	0
Comprehensive Income	$ 255	$ 351

XML

Condensed Statements of Comprehensive Income (Unaudited) - APC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Changes in fair value, tax	$ (23)	$ 8
Qualifying hedges, reclassification adjustment, tax	7	6
Alabama Power
Changes in fair value, tax	0	(1)
Qualifying hedges, reclassification adjustment, tax	$ 0	$ 0

XML

Condensed Statements of Cash Flows (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net income (loss)	$ 799	$ 991
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,233	989
Pension, postretirement, and other employee benefits	(126)	(123)
Settlement of asset retirement obligations	(113)	(87)
Other, net	51	79
Changes in certain current assets and liabilities —
Receivables	319	(217)
Fossil fuel stock	(203)	39
Prepayments	(100)	(86)
Other current assets	143	8
Accounts payable	(1,056)	132
Accrued taxes	(237)	(58)
Accrued compensation	(478)	(470)
Other current liabilities	(28)	35
Net cash provided from operating activities	844	1,592
Investing Activities:
Property additions	(1,850)	(1,419)
Nuclear decommissioning trust fund purchases	(256)	(294)
Nuclear decommissioning trust fund sales	251	289
Cost of removal, net of salvage	(135)	(227)
Change in construction payables, net	(140)	23
Other investing activities	(91)	(18)
Net cash used for investing activities	(2,118)	(1,555)
Financing Activities:
Increase in notes payable, net	187	137
Payment of common stock dividends	(742)	(702)
Other financing activities	(83)	(115)
Net cash provided from (used for) financing activities	454	(193)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(820)	(156)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	2,037	1,829
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,217	1,673
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	652	515
Income taxes, net	(9)	(8)
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	833	863
Right-of-use assets obtained under finance leases	1	0
Alabama Power
Operating Activities:
Net income (loss)	255	351
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	398	250
Deferred income taxes	(75)	35
Pension, postretirement, and other employee benefits	(51)	(48)
Settlement of asset retirement obligations	(52)	(38)
Retail fuel cost under recovery – long-term	100	(46)
Other, net	(3)	(27)
Changes in certain current assets and liabilities —
Receivables	90	(4)
Fossil fuel stock	(78)	23
Prepayments	(89)	(85)
Other current assets	(37)	(10)
Accounts payable	(400)	(237)
Accrued taxes	109	102
Accrued compensation	(102)	(99)
Other current liabilities	(35)	(13)
Net cash provided from operating activities	30	154
Investing Activities:
Property additions	(389)	(343)
Nuclear decommissioning trust fund purchases	(87)	(72)
Nuclear decommissioning trust fund sales	87	72
Cost of removal, net of salvage	(41)	(60)
Change in construction payables, net	(70)	39
Other investing activities	(9)	(1)
Net cash used for investing activities	(509)	(365)
Financing Activities:
Increase in notes payable, net	170	0
Proceeds — Senior notes	0	700
Other long-term debt	16	0
Senior notes	0	(550)
Capital contributions from parent company	325	625
Payment of common stock dividends	(285)	(254)
Other financing activities	(7)	(17)
Net cash provided from (used for) financing activities	219	504
Net Change in Cash, Cash Equivalents, and Restricted Cash	(260)	293
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	687	1,060
Cash, Cash Equivalents, and Restricted Cash at End of Period	427	1,353
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	138	110
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	111	188
Right-of-use assets obtained under operating leases	13	1
Right-of-use assets obtained under finance leases	$ 1	$ 0

XML

Condensed Statements of Cash Flows (Unaudited) - APC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net cash paid for capitalized interest	$ 32	$ 23
Alabama Power
Net cash paid for capitalized interest	$ 7	$ 4

XML

Condensed Balance Sheets (Unaudited) - APC - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash and cash equivalents	$ 1,053	$ 1,917
Receivables —
Customer accounts	1,890	2,128
Unbilled revenues	596	1,012
Other accounts and notes	510	637
Accumulated provision for uncollectible accounts	(80)	(71)
Fossil fuel for generation	778	575
Materials and supplies	1,756	1,664
Prepaid expenses	626	347
Other regulatory assets	936	860
Other current assets	395	344
Total current assets	9,555	10,416
Property, Plant, and Equipment:
In service	118,690	117,529
Less: Accumulated depreciation	35,990	35,297
Plant in service, net of depreciation	82,700	82,232
Other utility plant, net	571	599
Nuclear fuel, at amortized cost	849	843
Construction work in progress	11,510	10,896
Total property, plant, and equipment	95,630	94,570
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	2,245	2,145
Equity investments in unconsolidated subsidiaries	1,408	1,443
Miscellaneous property and investments	616	602
Total other property and investments	9,827	9,757
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,505	1,531
Deferred charges related to income taxes	876	866
Regulatory assets – asset retirement obligations, deferred	5,701	5,764
Other regulatory assets, deferred	5,886	5,918
Other deferred charges and assets	1,456	1,485
Total deferred charges and other assets	19,744	20,148
Total Assets	134,756	134,891
Current Liabilities:
Securities due within one year	4,363	4,285
Notes payable	2,554	2,609
Accounts payable —
Customer deposits	475	502
Accrued interest	487	614
Accrued compensation	617	1,127
Asset retirement obligations	709	694
Other regulatory liabilities	287	382
Other current liabilities	915	787
Total current liabilities	13,893	15,724
Long-term Debt	52,060	50,656
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	10,488	10,036
Deferred credits related to income taxes	5,107	5,235
Accumulated deferred ITCs	2,112	2,133
Employee benefit obligations	1,222	1,238
Operating lease obligations, deferred	1,374	1,388
Asset retirement obligations, deferred	10,209	10,146
Other regulatory liabilities, deferred	690	733
Other deferred credits and liabilities	1,118	1,167
Total deferred credits and other liabilities	34,241	33,979
Total Liabilities	100,194	100,359
Total Stockholders' Equity	34,562	34,532
Total Liabilities and Stockholders' Equity	134,756	134,891
Alabama Power
Current Assets:
Cash and cash equivalents	427	687
Receivables —
Customer accounts	446	431
Unbilled revenues	129	174
Affiliated	98	101
Other accounts and notes	86	153
Accumulated provision for uncollectible accounts	(15)	(14)
Fossil fuel for generation	307	229
Materials and supplies	586	557
Prepaid expenses	136	65
Other regulatory assets	485	474
Other current assets	48	67
Total current assets	2,733	2,924
Property, Plant, and Equipment:
In service	33,803	33,472
Less: Accumulated depreciation	10,664	10,470
Plant in service, net of depreciation	23,139	23,002
Other utility plant, net	571	599
Nuclear fuel, at amortized cost	238	239
Construction work in progress	1,510	1,526
Total property, plant, and equipment	25,458	25,366
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,170	1,127
Equity investments in unconsolidated subsidiaries	55	57
Miscellaneous property and investments	125	124
Total other property and investments	1,350	1,308
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	81	71
Deferred charges related to income taxes	253	250
Prepaid pension and other postretirement benefit costs	689	657
Regulatory assets – asset retirement obligations, deferred	1,827	1,845
Other regulatory assets, deferred	2,034	2,107
Other deferred charges and assets	454	442
Total deferred charges and other assets	5,338	5,372
Total Assets	34,879	34,970
Current Liabilities:
Securities due within one year	323	301
Notes payable	170	0
Accounts payable —
Affiliated	242	443
Other	380	641
Customer deposits	105	106
Accrued taxes	148	57
Accrued interest	78	120
Accrued compensation	133	229
Asset retirement obligations	334	330
Other regulatory liabilities	74	96
Other current liabilities	132	91
Total current liabilities	2,119	2,414
Long-term Debt	10,322	10,329
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,997	3,981
Deferred credits related to income taxes	1,836	1,925
Accumulated deferred ITCs	79	81
Employee benefit obligations	149	145
Operating lease obligations, deferred	75	67
Asset retirement obligations, deferred	3,940	3,957
Other regulatory liabilities, deferred	300	315
Other deferred credits and liabilities	75	69
Total deferred credits and other liabilities	10,451	10,540
Total Liabilities	22,892	23,283
Total Stockholders' Equity	11,987	11,687
Total Liabilities and Stockholders' Equity	$ 34,879	$ 34,970

XML

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, 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	1,032					347			347
Capital contributions from parent company						626		626
Cash dividends on common stock	(702)			(702)		(254)			(254)
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, 2022							31
Beginning balance at Dec. 31, 2022	34,532	5,417	13,673	11,538	(167)	11,687	$ 1,222	6,710	3,764	(9)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock	862					255			255
Capital contributions from parent company						330		330
Cash dividends on common stock	(742)			(742)		(285)			(285)
Ending balance (in shares) at Mar. 31, 2023							31
Ending balance at Mar. 31, 2023	$ 34,562	$ 5,421	$ 13,715	$ 11,658	$ (211)	$ 11,987	$ 1,222	$ 7,040	$ 3,734	$ (9)

XML

Condensed Statements of Income (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues:
Total operating revenues	$ 6,480	$ 6,648
Operating Expenses:
Other operations and maintenance	1,482	1,516
Depreciation and amortization	1,111	892
Taxes other than income taxes	394	372
Total operating expenses	5,262	5,264
Operating Income	1,218	1,384
Other Income and (Expense):
Allowance for equity funds used during construction	65	51
Interest expense, net of amounts capitalized	(582)	(462)
Other income (expense), net	147	145
Total other income and (expense)	(322)	(220)
Earnings Before Income Taxes	896	1,164
Income taxes (benefit)	97	173
Net Income	799	991
Retail electric revenues
Operating Revenues:
Total operating revenues	3,599	3,613
Wholesale Electric
Operating Revenues:
Total operating revenues	599	664
Other electric revenues
Operating Revenues:
Total operating revenues	190	177
Natural Gas
Operating Revenues:
Total operating revenues	1,875	2,058
Other revenues
Operating Revenues:
Total operating revenues	217	136
Operating Expenses:
Cost of Goods and Services Sold	127	69
Fuel
Operating Expenses:
Cost of Goods and Services Sold	1,050	1,111
Purchased power
Operating Expenses:
Cost of Goods and Services Sold	242	232
GEORGIA POWER CO
Operating Revenues:
Total operating revenues	2,176	2,208
Operating Expenses:
Other operations and maintenance	496	517
Depreciation and amortization	408	351
Taxes other than income taxes	131	125
Total operating expenses	1,766	1,768
Operating Income	410	440
Other Income and (Expense):
Allowance for equity funds used during construction	40	32
Interest expense, net of amounts capitalized	(146)	(107)
Other income (expense), net	45	50
Total other income and (expense)	(61)	(25)
Earnings Before Income Taxes	349	415
Income taxes (benefit)	53	30
Net Income	296	385
GEORGIA POWER CO | Retail electric revenues
Operating Revenues:
Total operating revenues	1,981	2,017
GEORGIA POWER CO | Wholesale Electric
Operating Revenues:
Total operating revenues	31	66
GEORGIA POWER CO | Other revenues
Operating Revenues:
Total operating revenues	164	125
GEORGIA POWER CO | Fuel
Operating Expenses:
Cost of Goods and Services Sold	402	419
GEORGIA POWER CO | Purchased power
Operating Expenses:
Cost of Goods and Services Sold	123	150
GEORGIA POWER CO | Purchased power, affiliates
Operating Expenses:
Cost of Goods and Services Sold	$ 206	$ 206

XML

Condensed Statements of Comprehensive Income (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income	$ 799	$ 991
Qualifying hedges:
Changes in fair value, net of tax	(63)	19
Reclassification adjustment for amounts included in net income, net of tax	19	20
Total other comprehensive income (loss)	(44)	42
Comprehensive Income	755	1,033
GEORGIA POWER CO
Net income	296	385
Qualifying hedges:
Changes in fair value, net of tax	(1)	9
Reclassification adjustment for amounts included in net income, net of tax	1	1
Total other comprehensive income (loss)	0	10
Comprehensive Income	$ 296	$ 395

XML

Condensed Statements of Comprehensive Income (Unaudited) - GPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Changes in fair value, tax	$ (23)	$ 8
Qualifying hedges, reclassification adjustment, tax	7	6
GEORGIA POWER CO
Changes in fair value, tax	0	3
Qualifying hedges, reclassification adjustment, tax	$ 0	$ 1

XML

Condensed Statements of Cash Flows (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net income (loss)	$ 799	$ 991
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,233	989
Allowance for equity funds used during construction	(65)	(51)
Pension, postretirement, and other employee benefits	(126)	(123)
Settlement of asset retirement obligations	(113)	(87)
Retail fuel cost under recovery – long-term	454	(130)
Other, net	51	79
Changes in certain current assets and liabilities —
Receivables	319	(217)
Fossil fuel stock	(203)	39
Materials and supplies	(98)	(28)
Other current assets	143	8
Accounts payable	(1,056)	132
Accrued taxes	(237)	(58)
Accrued compensation	(478)	(470)
Accrued interest	(127)	(128)
Other current liabilities	(28)	35
Net cash provided from operating activities	844	1,592
Investing Activities:
Property additions	(1,850)	(1,419)
Nuclear decommissioning trust fund purchases	(256)	(294)
Nuclear decommissioning trust fund sales	251	289
Cost of removal, net of salvage	(135)	(227)
Proceeds from dispositions	103	91
Other investing activities	(91)	(18)
Net cash used for investing activities	(2,118)	(1,555)
Financing Activities:
Increase in notes payable, net	187	137
Proceeds —
Short-term borrowings	100	850
Redemptions and repurchases —
Short-term borrowings	(400)	(100)
Payment of common stock dividends	(742)	(702)
Other financing activities	(83)	(115)
Net cash provided from (used for) financing activities	454	(193)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(820)	(156)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	2,037	1,829
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,217	1,673
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	652	515
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	833	863
Right-of-use assets obtained under operating leases	26	3
GEORGIA POWER CO
Operating Activities:
Net income (loss)	296	385
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	455	397
Deferred income taxes	57	(6)
Allowance for equity funds used during construction	(40)	(32)
Pension, postretirement, and other employee benefits	(64)	(63)
Settlement of asset retirement obligations	(54)	(41)
Storm damage accruals	8	53
Retail fuel cost under recovery – long-term	354	(84)
Other, net	(40)	(54)
Changes in certain current assets and liabilities —
Receivables	(136)	0
Fossil fuel stock	(107)	18
Materials and supplies	(46)	(11)
Other current assets	6	(20)
Accounts payable	(293)	39
Accrued taxes	(266)	(78)
Accrued compensation	(85)	(79)
Customer refunds	(103)	2
Accrued interest	(23)	(43)
Other current liabilities	28	(22)
Net cash provided from operating activities	(53)	361
Investing Activities:
Property additions	(1,042)	(749)
Nuclear decommissioning trust fund purchases	(169)	(221)
Nuclear decommissioning trust fund sales	164	217
Cost of removal, net of salvage	(64)	(140)
Change in construction payables, net of joint owner portion	(27)	14
Proceeds from dispositions	56	56
Other investing activities	(35)	14
Net cash used for investing activities	(1,117)	(809)
Financing Activities:
Increase in notes payable, net	465	410
Proceeds —
Revenue bonds	229	0
Short-term borrowings	100	450
Redemptions and repurchases —
Senior notes	0	(400)
FFB loan	(21)	(24)
Short-term borrowings	(200)	0
Capital contributions from parent company	750	445
Payment of common stock dividends	(464)	(423)
Other financing activities	(9)	(17)
Net cash provided from (used for) financing activities	850	441
Net Change in Cash, Cash Equivalents, and Restricted Cash	(320)	(7)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	480	33
Cash, Cash Equivalents, and Restricted Cash at End of Period	160	26
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	159	139
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	548	459
Right-of-use assets obtained under operating leases	$ 3	$ 1

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Condensed Statements of Cash Flows (Unaudited) - GPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net cash paid for capitalized interest	$ 32	$ 23
GEORGIA POWER CO
Net cash paid for capitalized interest	$ 21	$ 16

XML

Condensed Balance Sheets (Unaudited) - GPC - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash and cash equivalents	$ 1,053	$ 1,917
Receivables —
Customer accounts	1,890	2,128
Unbilled revenues	596	1,012
Other accounts and notes	510	637
Fossil fuel for generation	778	575
Materials and supplies	1,756	1,664
Regulatory assets – asset retirement obligations	342	332
Assets from risk management activities	53	115
Other regulatory assets	936	860
Other current assets	395	344
Total current assets	9,555	10,416
Property, Plant, and Equipment:
In service	118,690	117,529
Less: Accumulated depreciation	35,990	35,297
Plant in service, net of depreciation	82,700	82,232
Nuclear fuel, at amortized cost	849	843
Construction work in progress	11,510	10,896
Total property, plant, and equipment	95,630	94,570
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	2,245	2,145
Equity investments in unconsolidated subsidiaries	1,408	1,443
Miscellaneous property and investments	616	602
Total other property and investments	9,827	9,757
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,505	1,531
Deferred charges related to income taxes	876	866
Prepaid pension costs	2,384	2,290
Deferred under recovered fuel clause revenues	1,702	2,056
Regulatory assets – asset retirement obligations, deferred	5,701	5,764
Other regulatory assets, deferred	5,886	5,918
Other deferred charges and assets	1,456	1,485
Total deferred charges and other assets	19,744	20,148
Total Assets	134,756	134,891
Current Liabilities:
Securities due within one year	4,363	4,285
Notes payable	2,554	2,609
Accounts payable —
Customer deposits	475	502
Accrued interest	487	614
Accrued compensation	617	1,127
Operating lease obligations	199	197
Asset retirement obligations	709	694
Other regulatory liabilities	287	382
Other current liabilities	915	787
Total current liabilities	13,893	15,724
Long-term Debt	52,060	50,656
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	10,488	10,036
Deferred credits related to income taxes	5,107	5,235
Accumulated deferred ITCs	2,112	2,133
Employee benefit obligations	1,222	1,238
Operating lease obligations, deferred	1,374	1,388
Asset retirement obligations, deferred	10,209	10,146
Other deferred credits and liabilities	1,118	1,167
Total deferred credits and other liabilities	34,241	33,979
Total Liabilities	100,194	100,359
Total Stockholders' Equity	34,562	34,532
Total Liabilities and Stockholders' Equity	134,756	134,891
GEORGIA POWER CO
Current Assets:
Cash and cash equivalents	0	364
Receivables —
Customer accounts	597	735
Unbilled revenues	197	309
Under recovered fuel clause revenues	447	0
Joint owner accounts	100	128
Affiliated	59	53
Other accounts and notes	45	62
Fossil fuel for generation	399	291
Materials and supplies	774	729
Regulatory assets – asset retirement obligations	166	158
Other regulatory assets	377	324
Other current assets	264	246
Total current assets	3,425	3,399
Property, Plant, and Equipment:
In service	42,465	41,879
Less: Accumulated depreciation	13,383	13,115
Plant in service, net of depreciation	29,082	28,764
Nuclear fuel, at amortized cost	611	604
Construction work in progress	8,639	8,103
Total property, plant, and equipment	38,332	37,471
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,075	1,018
Equity investments in unconsolidated subsidiaries	50	51
Miscellaneous property and investments	116	107
Total other property and investments	1,241	1,176
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	974	1,007
Deferred charges related to income taxes	592	583
Prepaid pension costs	771	738
Deferred under recovered fuel clause revenues	1,702	2,056
Regulatory assets – asset retirement obligations, deferred	3,635	3,671
Other regulatory assets, deferred	2,576	2,522
Other deferred charges and assets	489	540
Total deferred charges and other assets	10,739	11,117
Total Assets	53,737	53,163
Current Liabilities:
Securities due within one year	901	901
Notes payable	1,965	1,600
Accounts payable —
Affiliated	606	928
Other	1,099	1,076
Customer deposits	251	252
Accrued taxes	222	508
Accrued interest	133	157
Accrued compensation	133	254
Operating lease obligations	154	151
Asset retirement obligations	308	295
Other regulatory liabilities	47	170
Other current liabilities	426	286
Total current liabilities	6,245	6,578
Long-term Debt	14,219	14,009
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,818	3,707
Deferred credits related to income taxes	2,220	2,244
Accumulated deferred ITCs	316	319
Employee benefit obligations	310	318
Operating lease obligations, deferred	840	851
Asset retirement obligations, deferred	5,820	5,739
Other deferred credits and liabilities	506	540
Total deferred credits and other liabilities	13,830	13,718
Total Liabilities	34,294	34,305
Total Stockholders' Equity	19,443	18,858
Total Liabilities and Stockholders' Equity	$ 53,737	$ 53,163

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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, 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	991					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)
Other	(7)		(7)	(2)
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, 2022							9
Beginning balance at Dec. 31, 2022	34,532	5,417	13,673	11,538	(167)	18,858	$ 398	15,626	2,846	(12)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	799					296			296
Capital contributions from parent company						752		752
Other comprehensive income (loss)	(44)				(44)
Cash dividends on common stock	(742)			(742)		(464)			(464)
Other	0		(2)			(1)			(1)
Ending balance (in shares) at Mar. 31, 2023							9
Ending balance at Mar. 31, 2023	$ 34,562	$ 5,421	$ 13,715	$ 11,658	$ (211)	$ 19,443	$ 398	$ 16,378	$ 2,679	$ (12)

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Condensed Statements of Common Stockholders' Equity (Unaudited) - GPC (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Stockholders' Equity [Abstract]
Cash dividends (in dollars per share)	$ 0.68	$ 0.66

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Condensed Statements of Income (Unaudited) - MPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues:
Total operating revenues	$ 6,480	$ 6,648
Operating Expenses:
Other operations and maintenance	1,482	1,516
Depreciation and amortization	1,111	892
Taxes other than income taxes	394	372
Total operating expenses	5,262	5,264
Operating Income	1,218	1,384
Other Income and (Expense):
Interest expense, net of amounts capitalized	(582)	(462)
Other income (expense), net	147	145
Total other income and (expense)	(322)	(220)
Earnings Before Income Taxes	896	1,164
Income taxes (benefit)	97	173
Net Income	799	991
Retail electric revenues
Operating Revenues:
Total operating revenues	3,599	3,613
Wholesale Electric
Operating Revenues:
Total operating revenues	599	664
Other electric revenues
Operating Revenues:
Total operating revenues	190	177
Natural Gas
Operating Revenues:
Total operating revenues	1,875	2,058
Other revenues
Operating Revenues:
Total operating revenues	217	136
Operating Expenses:
Total cost of sales	127	69
Mississippi Power
Operating Revenues:
Total operating revenues	390	335
Operating Expenses:
Other operations and maintenance	82	76
Depreciation and amortization	47	45
Taxes other than income taxes	32	29
Total operating expenses	312	282
Operating Income	78	53
Other Income and (Expense):
Interest expense, net of amounts capitalized	(16)	(13)
Other income (expense), net	9	10
Total other income and (expense)	(7)	(3)
Earnings Before Income Taxes	71	50
Income taxes (benefit)	13	8
Net Income	58	42
Mississippi Power | Retail electric revenues
Operating Revenues:
Total operating revenues	236	217
Mississippi Power | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	68	68
Mississippi Power | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	75	42
Mississippi Power | Other revenues
Operating Revenues:
Total operating revenues	11	8
Mississippi Power | Fuel and purchased power
Operating Expenses:
Total cost of sales	$ 151	$ 132

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Condensed Statements of Cash Flows (Unaudited) - MPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net income (loss)	$ 799	$ 991
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,233	989
Settlement of asset retirement obligations	(113)	(87)
Other, net	51	79
Changes in certain current assets and liabilities —
Receivables	319	(217)
Other current assets	143	8
Accounts payable	(1,056)	132
Accrued taxes	(237)	(58)
Accrued compensation	(478)	(470)
Other current liabilities	(28)	35
Net cash provided from operating activities	844	1,592
Investing Activities:
Property additions	(1,850)	(1,419)
Construction payables	(140)	23
Other investing activities	(91)	(18)
Net cash used for investing activities	(2,118)	(1,555)
Financing Activities:
Increase in notes payable, net	187	137
Payment of common stock dividends	(742)	(702)
Other financing activities	(83)	(115)
Net cash provided from (used for) financing activities	454	(193)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(820)	(156)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	2,037	1,829
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,217	1,673
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	652	515
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	833	863
Right-of-use assets obtained under operating leases	26	3
Mississippi Power
Operating Activities:
Net income (loss)	58	42
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	58	55
Settlement of asset retirement obligations	(3)	(5)
Other, net	(5)	17
Changes in certain current assets and liabilities —
Receivables	73	(7)
Retail fuel cost under recovery	(23)	(11)
Other current assets	(1)	(11)
Accounts payable	(74)	(9)
Accrued taxes	(62)	(63)
Accrued compensation	(17)	(18)
Other current liabilities	(7)	(6)
Net cash provided from operating activities	(3)	(16)
Investing Activities:
Property additions	(94)	(45)
Construction payables	(9)	(8)
Payments pursuant to LTSAs	(8)	(8)
Other investing activities	(6)	(7)
Net cash used for investing activities	(117)	(68)
Financing Activities:
Increase in notes payable, net	126	25
Capital contributions from parent company	0	50
Payment of common stock dividends	(46)	(43)
Other financing activities	(1)	0
Net cash provided from (used for) financing activities	79	32
Net Change in Cash, Cash Equivalents, and Restricted Cash	(41)	(52)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	59	61
Cash, Cash Equivalents, and Restricted Cash at End of Period	18	9
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	25	22
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	13	17
Right-of-use assets obtained under operating leases	$ 1	$ 0

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Condensed Balance Sheets (Unaudited) - MPC - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash and cash equivalents	$ 1,053	$ 1,917
Receivables —
Customer accounts	1,890	2,128
Unbilled revenues	596	1,012
Other accounts and notes	510	637
Fossil fuel for generation	778	575
Materials and supplies	1,756	1,664
Assets from risk management activities	53	115
Other regulatory assets	936	860
Other current assets	395	344
Total current assets	9,555	10,416
Property, Plant, and Equipment:
In service	118,690	117,529
Less: Accumulated depreciation	35,990	35,297
Plant in service, net of depreciation	82,700	82,232
Construction work in progress	11,510	10,896
Total property, plant, and equipment	95,630	94,570
Other Property and Investments:
Total other property and investments	9,827	9,757
Deferred Charges and Other Assets:
Deferred charges related to income taxes	876	866
Regulatory assets – asset retirement obligations, deferred	5,701	5,764
Other regulatory assets, deferred	5,886	5,918
Other deferred charges and assets	1,456	1,485
Total deferred charges and other assets	19,744	20,148
Total Assets	134,756	134,891
Current Liabilities:
Securities due within one year	4,363	4,285
Notes payable	2,554	2,609
Accounts payable —
Accrued compensation	617	1,127
Asset retirement obligations	709	694
Other regulatory liabilities	287	382
Other current liabilities	915	787
Total current liabilities	13,893	15,724
Long-term Debt	52,060	50,656
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	10,488	10,036
Deferred credits related to income taxes	5,107	5,235
Employee benefit obligations	1,222	1,238
Asset retirement obligations, deferred	10,209	10,146
Other cost of removal obligations	1,921	1,903
Other regulatory liabilities, deferred	690	733
Other deferred credits and liabilities	1,118	1,167
Total deferred credits and other liabilities	34,241	33,979
Total Liabilities	100,194	100,359
Total Liabilities and Stockholders' Equity	134,756	134,891
Mississippi Power
Current Assets:
Cash and cash equivalents	18	59
Receivables —
Customer accounts	69	47
Unbilled revenues	37	47
Affiliated	26	82
Other accounts and notes	29	35
Fossil fuel for generation	51	44
Materials and supplies	80	80
Other regulatory assets	80	72
Other current assets	13	38
Total current assets	403	504
Property, Plant, and Equipment:
In service	5,319	5,254
Less: Accumulated depreciation	1,723	1,689
Plant in service, net of depreciation	3,596	3,565
Construction work in progress	225	208
Total property, plant, and equipment	3,821	3,773
Other Property and Investments:
Total other property and investments	165	167
Deferred Charges and Other Assets:
Deferred charges related to income taxes	29	30
Prepaid pension costs	114	109
Regulatory assets – asset retirement obligations, deferred	239	239
Other regulatory assets, deferred	253	249
Accumulated deferred income taxes	103	107
Other deferred charges and assets	89	94
Total deferred charges and other assets	827	828
Total Assets	5,216	5,272
Current Liabilities:
Securities due within one year	1	1
Notes payable	126	0
Accounts payable —
Affiliated	69	121
Other	75	106
Accrued taxes	62	124
Accrued compensation	20	37
Asset retirement obligations	35	37
Other regulatory liabilities	25	43
Other current liabilities	81	85
Total current liabilities	494	554
Long-term Debt	1,544	1,544
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	470	466
Deferred credits related to income taxes	247	253
Employee benefit obligations	69	69
Asset retirement obligations, deferred	143	142
Other cost of removal obligations	196	196
Other regulatory liabilities, deferred	84	96
Other deferred credits and liabilities	26	21
Total deferred credits and other liabilities	1,235	1,243
Total Liabilities	3,273	3,341
Total common stockholders' equity	1,943	1,931
Total Liabilities and Stockholders' Equity	$ 5,216	$ 5,272

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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)
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)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,032					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)
Beginning balance (in shares) at Dec. 31, 2022							1
Beginning balance at Dec. 31, 2022	34,532	5,417	13,673	11,538	(167)	1,931	$ 38	4,652	(2,759)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	862					58			58
Cash dividends on common stock	(742)			(742)		(46)			(46)
Other	0		2
Ending balance (in shares) at Mar. 31, 2023							1
Ending balance at Mar. 31, 2023	$ 34,562	$ 5,421	$ 13,715	$ 11,658	$ (211)	$ 1,943	$ 38	$ 4,652	$ (2,747)

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Condensed Consolidated Statements of Income (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues:
Total operating revenues	$ 6,480	$ 6,648
Operating Expenses:
Other operations and maintenance	1,482	1,516
Depreciation and amortization	1,111	892
Taxes other than income taxes	394	372
Gain on dispositions, net	(42)	(23)
Total operating expenses	5,262	5,264
Operating Income	1,218	1,384
Other Income and (Expense):
Interest expense, net of amounts capitalized	(582)	(462)
Other income (expense), net	147	145
Total other income and (expense)	(322)	(220)
Earnings Before Income Taxes	896	1,164
Income taxes (benefit)	97	173
Net Income	799	991
Net loss attributable to noncontrolling interests	(63)	(45)
Retail electric revenues
Operating Revenues:
Total operating revenues	3,599	3,613
Wholesale Electric
Operating Revenues:
Total operating revenues	599	664
Other electric revenues
Operating Revenues:
Total operating revenues	190	177
Natural Gas
Operating Revenues:
Total operating revenues	1,875	2,058
Other revenues
Operating Revenues:
Total operating revenues	217	136
Operating Expenses:
Total cost of sales	127	69
Fuel
Operating Expenses:
Total cost of sales	1,050	1,111
Purchased power
Operating Expenses:
Total cost of sales	242	232
SOUTHERN POWER CO
Operating Revenues:
Total operating revenues	508	539
Operating Expenses:
Other operations and maintenance	107	105
Depreciation and amortization	128	120
Taxes other than income taxes	13	13
Gain on dispositions, net	(20)	(2)
Total operating expenses	445	489
Operating Income	63	50
Other Income and (Expense):
Interest expense, net of amounts capitalized	(33)	(37)
Other income (expense), net	2	2
Total other income and (expense)	(31)	(35)
Earnings Before Income Taxes	32	15
Income taxes (benefit)	(7)	(12)
Net Income	39	27
Net loss attributable to noncontrolling interests	(63)	(45)
Net Income	102	72
SOUTHERN POWER CO | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	362	426
SOUTHERN POWER CO | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	135	105
SOUTHERN POWER CO | Other revenues
Operating Revenues:
Total operating revenues	11	8
SOUTHERN POWER CO | Fuel
Operating Expenses:
Total cost of sales	191	232
SOUTHERN POWER CO | Purchased power
Operating Expenses:
Total cost of sales	$ 26	$ 21

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income	$ 799	$ 991
Qualifying hedges:
Changes in fair value, net of tax	(63)	19
Reclassification adjustment for amounts included in net income, net of tax	19	20
Total other comprehensive income (loss)	(44)	42
Comprehensive Income	755	1,033
Comprehensive loss attributable to noncontrolling interests	(63)	(45)
Comprehensive Income	818	1,074
SOUTHERN POWER CO
Net income	39	27
Qualifying hedges:
Changes in fair value, net of tax	(8)	(17)
Reclassification adjustment for amounts included in net income, net of tax	1	22
Total other comprehensive income (loss)	(7)	5
Comprehensive Income	32	32
Comprehensive loss attributable to noncontrolling interests	(63)	(45)
Comprehensive Income	$ 95	$ 77

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Changes in fair value, tax	$ (23)	$ 8
Qualifying hedges, reclassification adjustment, tax	7	6
SOUTHERN POWER CO
Changes in fair value, tax	(3)	(6)
Qualifying hedges, reclassification adjustment, tax	$ 0	$ 7

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Condensed Consolidated Statements of Cash Flows (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net income (loss)	$ 799	$ 991
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,233	989
Other, net	51	79
Changes in certain current assets and liabilities —
Receivables	319	(217)
Other current assets	143	8
Accounts payable	(1,056)	132
Accrued compensation	(478)	(470)
Other current liabilities	(28)	35
Net cash provided from operating activities	844	1,592
Investing Activities:
Property additions	(1,850)	(1,419)
Other investing activities	(91)	(18)
Net cash used for investing activities	(2,118)	(1,555)
Financing Activities:
Capital contributions from noncontrolling interests	21	73
Distributions to noncontrolling interests	(48)	(97)
Payment of common stock dividends	(742)	(702)
Other financing activities	(83)	(115)
Net cash provided from (used for) financing activities	454	(193)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(820)	(156)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	2,037	1,829
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,217	1,673
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	652	515
Income taxes, net	(9)	(8)
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	833	863
Reassessment of right-of-use assets under operating leases	0	40
SOUTHERN POWER CO
Operating Activities:
Net income (loss)	39	27
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	133	126
Deferred income taxes	3	12
Amortization of investment tax credits	(15)	(15)
Gain on dispositions, net	(20)	(2)
Other, net	(14)	(3)
Changes in certain current assets and liabilities —
Receivables	120	11
Prepaid income taxes	15	(8)
Other current assets	(13)	0
Accounts payable	(92)	(21)
Accrued compensation	(13)	(13)
Other current liabilities	(8)	3
Net cash provided from operating activities	135	117
Investing Activities:
Property additions	(11)	(19)
Proceeds from dispositions	46	29
Change in construction payables	(15)	(31)
Payments pursuant to LTSAs	(16)	(15)
Other investing activities	0	(1)
Net cash used for investing activities	4	(37)
Financing Activities:
Decrease in notes payable, net	(59)	(3)
Capital contributions from noncontrolling interests	21	73
Distributions to noncontrolling interests	(48)	(97)
Payment of common stock dividends	(63)	(49)
Other financing activities	3	0
Net cash provided from (used for) financing activities	(146)	(76)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(7)	4
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	133	135
Cash, Cash Equivalents, and Restricted Cash at End of Period	126	139
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	30	29
Income taxes, net	(9)	(8)
Noncash transactions —
Noncash transactions — Accrued property additions at end of period	12	46
Reassessment of right-of-use assets under operating leases	$ 0	$ 40

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Condensed Consolidated Statements of Cash Flows (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net cash paid for capitalized interest	$ 32	$ 23

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Condensed Consolidated Balance Sheets (Unaudited) - SPC - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash and cash equivalents	$ 1,053	$ 1,917
Receivables —
Customer accounts	1,890	2,128
Other accounts and notes	510	637
Materials and supplies	1,756	1,664
Other current assets	395	344
Total current assets	9,555	10,416
Property, Plant, and Equipment:
In service	118,690	117,529
Less: Accumulated depreciation	35,990	35,297
Plant in service, net of depreciation	82,700	82,232
Construction work in progress	11,510	10,896
Total property, plant, and equipment	95,630	94,570
Other Property and Investments:
Equity investments in unconsolidated subsidiaries	1,408	1,443
Total other property and investments	9,827	9,757
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,505	1,531
Other deferred charges and assets	1,456	1,485
Total deferred charges and other assets	19,744	20,148
Total Assets	134,756	134,891
Current Liabilities:
Securities due within one year	4,363	4,285
Notes payable	2,554	2,609
Accounts payable —
Accrued interest	487	614
Other current liabilities	915	787
Total current liabilities	13,893	15,724
Long-term Debt	52,060	50,656
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	10,488	10,036
Accumulated deferred ITCs	2,112	2,133
Operating lease obligations, deferred	1,374	1,388
Other deferred credits and liabilities	1,118	1,167
Total deferred credits and other liabilities	34,241	33,979
Total Liabilities	100,194	100,359
Total Stockholders' Equity (See accompanying statements)	34,562	34,532
Total Liabilities and Stockholders' Equity	134,756	134,891
SOUTHERN POWER CO
Current Assets:
Cash and cash equivalents	123	131
Receivables —
Customer accounts	133	226
Affiliated	39	51
Other accounts and notes	71	70
Materials and supplies	85	88
Prepaid income taxes	291	5
Other current assets	59	50
Total current assets	801	621
Property, Plant, and Equipment:
In service	14,635	14,658
Less: Accumulated depreciation	3,760	3,661
Plant in service, net of depreciation	10,875	10,997
Construction work in progress	43	41
Total property, plant, and equipment	10,918	11,038
Other Property and Investments:
Intangible assets, net of amortization	258	263
Equity investments in unconsolidated subsidiaries	0	49
Net investment in sales-type leases	152	154
Total other property and investments	410	466
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	487	489
Prepaid LTSAs	208	193
Other deferred charges and assets	310	274
Total deferred charges and other assets	1,005	956
Total Assets	13,134	13,081
Current Liabilities:
Securities due within one year	291	290
Notes payable	165	225
Accounts payable —
Affiliated	71	139
Other	31	67
Accrued taxes	22	24
Accrued interest	27	28
Other current liabilities	90	111
Total current liabilities	697	884
Long-term Debt	2,700	2,689
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	581	279
Accumulated deferred ITCs	1,541	1,556
Operating lease obligations, deferred	510	514
Other deferred credits and liabilities	247	243
Total deferred credits and other liabilities	2,879	2,592
Total Liabilities	6,276	6,165
Total Stockholders' Equity (See accompanying statements)	6,858	6,916
Total Liabilities and Stockholders' Equity	$ 13,134	$ 13,081

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Condensed Consolidated Balance Sheets (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Other intangible assets, amortization	$ 350	$ 340
SOUTHERN POWER CO
Other intangible assets, amortization	$ 134	$ 129

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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, 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	991					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)
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, 2022	34,532	13,673	11,538	(167)	4,124	6,916	2,792	1,069	1,741	(18)	4,124
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	799					39	102		102		(63)
Other comprehensive income (loss)	(44)			(44)		(7)	(7)			(7)
Cash dividends on common stock	(742)		(742)			(63)	(63)		(63)
Capital contributions from noncontrolling interests	21				21	21					21
Distributions to noncontrolling interests	(48)				(48)	(48)					(48)
Ending balance at Mar. 31, 2023	$ 34,562	$ 13,715	$ 11,658	$ (211)	$ 4,034	$ 6,858	$ 2,824	$ 1,069	$ 1,780	$ (25)	$ 4,034

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Condensed Consolidated Statements of Income (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues:
Total operating revenues	$ 6,480	$ 6,648
Operating Expenses:
Other operations and maintenance	1,482	1,516
Depreciation and amortization	1,111	892
Taxes other than income taxes	394	372
Gain on dispositions, net	(42)	(23)
Total operating expenses	5,262	5,264
Operating Income	1,218	1,384
Other Income and (Expense):
Earnings from equity method investments	48	46
Interest expense, net of amounts capitalized	(582)	(462)
Other income (expense), net	147	145
Total other income and (expense)	(322)	(220)
Earnings Before Income Taxes	896	1,164
Income taxes (benefit)	97	173
Net Income	799	991
Retail electric revenues
Operating Revenues:
Total operating revenues	3,599	3,613
Wholesale Electric
Operating Revenues:
Total operating revenues	599	664
Other electric revenues
Operating Revenues:
Total operating revenues	190	177
Natural Gas
Operating Revenues:
Total operating revenues	1,875	2,058
Natural gas
Operating Expenses:
Total cost of sales	898	1,095
Alternative revenue programs
Operating Revenues:
Total operating revenues	12	0
Other revenues
Operating Revenues:
Total operating revenues	217	136
Operating Expenses:
Total cost of sales	127	69
SOUTHERN Co GAS
Operating Revenues:
Total operating revenues	$ 1,875	$ 2,058
Operating Expenses:
Cost, Product and Service [Extensible Enumeration]	Natural gas	Natural gas
Other operations and maintenance	$ 305	$ 305
Depreciation and amortization	141	137
Taxes other than income taxes	102	100
Total operating expenses	1,446	1,637
Operating Income	429	421
Other Income and (Expense):
Earnings from equity method investments	45	40
Interest expense, net of amounts capitalized	(76)	(61)
Other income (expense), net	14	16
Total other income and (expense)	(17)	(5)
Earnings Before Income Taxes	412	416
Income taxes (benefit)	103	97
Net Income	309	319
SOUTHERN Co GAS | Natural gas
Operating Revenues:
Total operating revenues	1,875	2,058
Operating Expenses:
Total cost of sales	$ 898	$ 1,095

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Condensed Consolidated Statements of Income (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
SOUTHERN Co GAS
Revenue taxes collected	$ 66	$ 71

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net income	$ 799	$ 991
Qualifying hedges:
Changes in fair value, net of tax	(63)	19
Reclassification adjustment for amounts included in net income, net of tax	19	20
Total other comprehensive income (loss)	(44)	42
Comprehensive Income	755	1,033
SOUTHERN Co GAS
Net income	309	319
Qualifying hedges:
Changes in fair value, net of tax	(24)	26
Reclassification adjustment for amounts included in net income, net of tax	14	(6)
Total other comprehensive income (loss)	(10)	20
Comprehensive Income	$ 299	$ 339

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Changes in fair value, tax	$ (23)	$ 8
Qualifying hedges, reclassification adjustment, tax	7	6
SOUTHERN Co GAS
Changes in fair value, tax	(10)	10
Qualifying hedges, reclassification adjustment, tax	$ 6	$ (2)

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Condensed Consolidated Statements of Cash Flows (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net income (loss)	$ 799	$ 991
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	1,233	989
Natural gas cost under recovery – long-term	0	162
Other, net	51	79
Changes in certain current assets and liabilities —
Receivables	319	(217)
Natural gas for sale, net of temporary LIFO liquidation	267	450
Other current assets	143	8
Accounts payable	(1,056)	132
Accrued taxes	(237)	(58)
Other current liabilities	(28)	35
Net cash provided from operating activities	844	1,592
Investing Activities:
Property additions	(1,850)	(1,419)
Cost of removal, net of salvage	(135)	(227)
Construction payables	(140)	23
Other investing activities	(91)	(18)
Net cash used for investing activities	(2,118)	(1,555)
Financing Activities:
Short-term borrowings	(400)	(100)
Payment of common stock dividends	(742)	(702)
Other financing activities	(83)	(115)
Net cash provided from (used for) financing activities	454	(193)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(820)	(156)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	2,037	1,829
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,217	1,673
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	652	515
Noncash transactions — Accrued property additions at end of period	833	863
SOUTHERN Co GAS
Operating Activities:
Net income (loss)	309	319
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	141	137
Deferred income taxes	27	5
Mark-to-market adjustments	13	(38)
Natural gas cost under recovery – long-term	0	162
Other, net	(15)	41
Changes in certain current assets and liabilities —
Receivables	266	(115)
Natural gas for sale, net of temporary LIFO liquidation	267	450
Prepaid income taxes	33	34
Other current assets	90	(1)
Accounts payable	(303)	(23)
Accrued taxes	36	54
Natural gas cost over recovery	117	0
Other current liabilities	(3)	(1)
Net cash provided from operating activities	978	1,024
Investing Activities:
Property additions	(299)	(247)
Cost of removal, net of salvage	(24)	(20)
Construction payables	(53)	(5)
Other investing activities	(3)	1
Net cash used for investing activities	(379)	(271)
Financing Activities:
Decrease in notes payable, net	(448)	(577)
Short-term borrowings	(200)	(100)
Capital contributions from parent company	192	39
Payment of common stock dividends	(146)	(130)
Other financing activities	9	0
Net cash provided from (used for) financing activities	(593)	(768)
Net Change in Cash, Cash Equivalents, and Restricted Cash	6	(15)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	83	48
Cash, Cash Equivalents, and Restricted Cash at End of Period	89	33
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	76	55
Noncash transactions — Accrued property additions at end of period	$ 124	$ 107

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Condensed Consolidated Statements of Cash Flows (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net cash paid for capitalized interest	$ 32	$ 23
SOUTHERN Co GAS
Net cash paid for capitalized interest	$ 4	$ 2

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Condensed Consolidated Balance Sheets (Unaudited) - GAS - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash and cash equivalents	$ 1,053	$ 1,917
Receivables —
Customer accounts	1,890	2,128
Unbilled revenues	596	1,012
Other accounts and notes	510	637
Accumulated provision for uncollectible accounts	(80)	(71)
Natural gas for sale	216	438
Prepaid expenses	626	347
Natural gas cost under recovery	0	108
Other regulatory assets	936	860
Other current assets	395	344
Total current assets	9,555	10,416
Property, Plant, and Equipment:
In service	118,690	117,529
Less: Accumulated depreciation	35,990	35,297
Plant in service, net of depreciation	82,700	82,232
Construction work in progress	11,510	10,896
Total property, plant, and equipment	95,630	94,570
Other Property and Investments:
Goodwill	5,161	5,161
Equity investments in unconsolidated subsidiaries	1,408	1,443
Other intangible assets, net of amortization	397	406
Miscellaneous property and investments	616	602
Total other property and investments	9,827	9,757
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,505	1,531
Prepaid pension costs	2,384	2,290
Other regulatory assets, deferred	5,886	5,918
Other deferred charges and assets	1,456	1,485
Total deferred charges and other assets	19,744	20,148
Total Assets	134,756	134,891
Current Liabilities:
Securities due within one year	4,363	4,285
Notes payable	2,554	2,609
Accounts payable —
Customer deposits	475	502
Accrued interest	487	614
Accrued compensation	617	1,127
Natural gas cost over recovery	117	0
Other regulatory liabilities	287	382
Other current liabilities	915	787
Total current liabilities	13,893	15,724
Long-term Debt	52,060	50,656
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	10,488	10,036
Deferred credits related to income taxes	5,107	5,235
Employee benefit obligations	1,222	1,238
Operating lease obligations, deferred	1,374	1,388
Other cost of removal obligations	1,921	1,903
Other deferred credits and liabilities	1,118	1,167
Total deferred credits and other liabilities	34,241	33,979
Total Liabilities	100,194	100,359
Total Stockholders' Equity	34,562	34,532
Total Liabilities and Stockholders' Equity	134,756	134,891
SOUTHERN Co GAS
Current Assets:
Cash and cash equivalents	88	81
Receivables —
Customer accounts	586	616
Unbilled revenues	218	453
Other accounts and notes	73	76
Accumulated provision for uncollectible accounts	(58)	(50)
Natural gas for sale	216	438
Prepaid expenses	74	93
Natural gas cost under recovery	0	108
Other regulatory assets	126	119
Other current assets	118	104
Total current assets	1,441	2,038
Property, Plant, and Equipment:
In service	19,918	19,723
Less: Accumulated depreciation	5,350	5,276
Plant in service, net of depreciation	14,568	14,447
Construction work in progress	996	909
Total property, plant, and equipment	15,564	15,356
Other Property and Investments:
Goodwill	5,015	5,015
Equity investments in unconsolidated subsidiaries	1,282	1,276
Other intangible assets, net of amortization	23	26
Miscellaneous property and investments	29	28
Total other property and investments	6,349	6,345
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	55	57
Prepaid pension costs	190	183
Other regulatory assets, deferred	478	497
Other deferred charges and assets	145	145
Total deferred charges and other assets	868	882
Total Assets	24,222	24,621
Current Liabilities:
Securities due within one year	401	400
Notes payable	120	768
Accounts payable —
Affiliated	91	104
Other	361	701
Customer deposits	99	125
Accrued taxes	113	77
Accrued interest	69	67
Accrued compensation	68	105
Temporary LIFO liquidation	45	0
Natural gas cost over recovery	117	0
Other regulatory liabilities	104	36
Other current liabilities	208	187
Total current liabilities	1,796	2,570
Long-term Debt	7,055	7,042
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,583	1,560
Deferred credits related to income taxes	781	788
Employee benefit obligations	112	120
Operating lease obligations, deferred	50	51
Other cost of removal obligations	1,725	1,707
Accrued environmental remediation	200	207
Other deferred credits and liabilities	167	179
Total deferred credits and other liabilities	4,618	4,612
Total Liabilities	13,469	14,224
Total Stockholders' Equity	10,753	10,397
Total Liabilities and Stockholders' Equity	$ 24,222	$ 24,621

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Condensed Consolidated Balance Sheets (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Other intangible assets, amortization	$ 350	$ 340
SOUTHERN Co GAS
Other intangible assets, amortization	$ 159	$ 156

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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, 2021	$ 32,276	$ 11,950	$ 10,929	$ (237)	$ 9,916	$ 10,024	$ (132)	$ 24
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	991				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)
Other	7	7	2
Ending balance at Mar. 31, 2022	32,629	11,994	11,261	(195)	10,175	10,074	57	44
Beginning balance at Dec. 31, 2022	34,532	13,673	11,538	(167)	10,397	10,445	(79)	31
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	799				309		309
Capital contributions from parent company					203	203
Other comprehensive income (loss)	(44)			(44)	(10)			(10)
Cash dividends on common stock	(742)		(742)		(146)		(146)
Other	0	2			0	1	(1)
Ending balance at Mar. 31, 2023	$ 34,562	$ 13,715	$ 11,658	$ (211)	$ 10,753	$ 10,649	$ 83	$ 21

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Introduction

3 Months Ended

Mar. 31, 2023

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, 2022 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 March 31, 2023 and 2022. 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 March 31, 2023 and December 31, 2022 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,161
Southern Company Gas:
Gas distribution operations	$	4,034
Gas marketing services	981
Southern Company Gas total	$	5,015

Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if impairment indicators arise.

Other intangible assets were as follows:

	At March 31, 2023						At December 31, 2022
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Subject to amortization:
Customer relationships	$	212	$	(164)	$	48	$	212	$	(162)	$	50
Trade names	64		(47)		17		64		(44)		20
PPA fair value adjustments	390		(134)		256		390		(129)		261
Other	6		(5)		1		5		(5)		—
Total subject to amortization	$	672	$	(350)	$	322	$	671	$	(340)	$	331
Not subject to amortization:
FCC licenses	75		—		75		75		—		75
Total other intangible assets	$	747	$	(350)	$	397	$	746	$	(340)	$	406
Southern Power(*)
PPA fair value adjustments	$	390	$	(134)	$	256	$	390	$	(129)	$	261
Southern Company Gas(*)
Gas marketing services
Customer relationships	$	156	$	(140)	$	16	$	156	$	(139)	$	17
Trade names	26		(19)		7		26		(17)		9
Total other intangible assets	$	182	$	(159)	$	23	$	182	$	(156)	$	26

(*) All subject to amortization.

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2023		March 31, 2022
	(in millions)
Southern Company(a)	$	10	$	10
Southern Power(b)	5		5
Southern Company Gas	3		3

(a)Includes $5 million recorded as a reduction to operating revenues for both periods presented.

(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		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
At March 31, 2023
Cash and cash equivalents	$	1,053	$	—	$	123	$	88
Restricted cash(a):
Other current assets	117		115		—		2
Other deferred charges and assets	47		45		3		—
Total cash, cash equivalents, and restricted cash(b)	$	1,217	$	160	$	126	$	89
At December 31, 2022
Cash and cash equivalents	$	1,917	$	364	$	131	$	81
Restricted cash(a):
Other current assets	62		60		—		2
Other deferred charges and assets	58		56		3		—
Total cash, cash equivalents, and restricted cash(b)	$	2,037	$	480	$	133	$	83

(a)For Georgia Power, reflects $116 million at both March 31, 2023 and December 31, 2022 related to proceeds from the issuance of solid waste disposal facility revenue bonds in 2022 and $44 million at March 31, 2023 related to funds from a Georgia Housing and Finance Authority (GHFA) rental assistance program used to offset qualifying customers' past due balances, which expired on March 31, 2023 and will be returned to the GHFA. For Southern Power, reflects $3 million at both March 31, 2023 and December 31, 2022 held to fund estimated construction completion costs at the Deuel Harvest wind facility. 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 March 31, 2023 is expected to be restored prior to year-end.

Storm Damage Reserves

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

Storm damage reserve activity for the traditional electric operating companies during the three months ended March 31, 2023 was as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power
	(in millions)
Balance at December 31, 2022	$	216	$	97	$	83	$	36
Accrual	13		3		8		2
Weather-related damages	(43)		(12)		(31)		—
Balance at March 31, 2023	$	186	$	88	$	60	$	38

Asset Retirement Obligations

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

Following initial criticality on March 6, 2023, Georgia Power recorded AROs of approximately $90 million related to Plant Vogtle Unit 3. See Note (B) under "Georgia Power – Nuclear Construction" for additional information on construction and start-up of Plant Vogtle Units 3 and 4.

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Regulatory Matters

3 Months Ended

Mar. 31, 2023

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 March 31, 2023 and December 31, 2022 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2023		December 31, 2022
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, current	$	23	$	47
	Other regulatory assets, deferred	18		—
Rate CNP PPA	Other regulatory assets, current	17		18
	Other regulatory assets, deferred	100		102
Retail Energy Cost Recovery	Other regulatory assets, current	101		102
	Other regulatory assets, deferred	420		520
Georgia Power
Fuel Cost Recovery(*)	Receivables – under recovered fuel clause revenues	$	447	$	—
	Deferred under recovered fuel clause revenues	1,702		2,056
Mississippi Power
Fuel Cost Recovery	Receivables – customer accounts, net	$	25	$	1
Ad Valorem Tax	Other regulatory assets, current	9		12
	Other regulatory assets, deferred	19		19
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	—	$	108
	Natural gas cost over recovery	117		—

(*)See "Georgia Power – Fuel Cost Recovery" herein for additional information.

Alabama Power

Certificates of Convenience and Necessity

In 2020, the Alabama PSC approved a certificate of convenience and necessity authorizing Alabama Power's construction of Plant Barry Unit 8 and the recovery of estimated actual in-service costs of $652 million. At March 31, 2023, project expenditures associated with Plant Barry Unit 8 totaled approximately $541 million, of which $536 million and $5 million was included in CWIP and property, plant, and equipment in service, respectively. The unit is expected to be placed in service in November 2023. The ultimate outcome of this matter cannot be determined at this time.

Rate CNP New Plant

On March 24, 2023, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover costs associated with the acquisition of the Central Alabama Generating Station. The filing reflected an annual increase in retail revenues of $78 million effective with June 2023 billings. Through May 2023, Alabama Power expects to recover substantially all costs associated with the Central Alabama Generating Station through Rate RSE, offset by revenues from 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.

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. On April 4, 2023, the Alabama PSC approved two new solar PPAs totaling 160 MWs. Alabama Power has procured solar capacity totaling approximately 490 MWs under the RGC.

Georgia Power

Fuel Cost Recovery

On February 28, 2023, Georgia Power filed a request with the Georgia PSC to increase fuel rates. On April 13, 2023, Georgia Power and the staff of the Georgia PSC reached a stipulated agreement that includes the following terms: (i) Georgia Power would update fuel rates from the original request for revised fuel costs and to reflect a three-year recovery period, starting June 1, 2023, for $2.2 billion of the under recovered fuel balance and (ii) Georgia Power would be required to file its next fuel case no later than February 28, 2026. On April 24, 2023, Georgia Power filed an updated request reflecting a 54% increase in fuel rates effective June 1, 2023, which is expected to increase annual billings by approximately $1.1 billion and includes recovery of the under recovered fuel balance described above. Changes in fuel rates have no significant effect on Georgia Power's net income but do impact the related operating cash flows. Georgia Power expects the Georgia PSC to make a final decision on this matter on May 16, 2023. The ultimate outcome of this matter cannot be determined at this time.

Integrated Resource Plans

In August 2022, Restore Chattooga Gorge Coalition (RCG) filed a petition in the Superior Court of Fulton County, Georgia against Georgia Power and the Georgia PSC. The petition challenges Georgia Power's plan to expend $115 million to modernize Plant Tugalo, as approved in the 2019 IRP, and seeks judicial review of the Georgia PSC's order in the 2022 IRP proceeding with respect to the denial of RCG's challenge to the modernization plan. In November 2022, Georgia Power and the Georgia PSC both filed motions to dismiss the RCG petition. The ultimate outcome of this matter 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 currently 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 second quarter 2023 and the first quarter 2024, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,553
Construction contingency estimate	40
Total project capital cost forecast(a)(b)	10,593
Net investment at March 31, 2023(b)	(9,747)
Remaining estimate to complete	$	846

(a)Includes approximately $610 million of costs that are not shared with the other Vogtle Owners, including $33 million of construction monitoring costs approved for recovery by the Georgia PSC in its nineteenth VCM order, and approximately $407 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 $418 million, of which $334 million had been accrued through March 31, 2023.

(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 $3.5 billion, of which $3.3 billion had been incurred through March 31, 2023.

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 start-up testing and related test results, engineering support, commodity installation, system turnovers, 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 plans. As of March 31, 2023, 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. Future COVID-19 variants could further disrupt or delay construction and testing activities.

On March 6, 2023, Unit 3 achieved self-sustaining nuclear fission, commonly referred to as initial criticality, and, on April 1, 2023, the generator successfully synchronized to the power grid and generated electricity for the first time. Operators continue to perform tests at various power levels to help ensure the reactor performs as designed, and Southern Nuclear continues to remediate various equipment and component issues as they are identified. Based on the expected duration of start-up testing, Unit 3 is projected to be placed in service during May or June 2023. Hot functional testing for Unit 4 commenced on March 20, 2023, with fuel load projected to occur in the third quarter 2023. Unit 4 is projected to be placed in service during late fourth quarter 2023 or the first quarter 2024.

During the first quarter 2023, established construction contingency totaling $20 million was assigned to the base capital cost forecast for costs primarily associated with additional craft and support resources.

The projected schedule for Unit 3 primarily depends on the progression of pre-operational testing and start-up, which may be impacted by further equipment, component, and/or other operational challenges. The projected schedule for Unit 4 primarily depends on potential impacts arising from Unit 4 testing activities overlapping with Unit 3 start-up and commissioning; maintaining overall construction productivity and production levels, particularly in subcontractor scopes of work; and maintaining appropriate levels of craft laborers. As Unit 4 completes construction and transitions further into testing, ongoing and potential future challenges include the duration of hot functional testing; the timeframe and duration of other testing; the pace and quality of remaining commodities installation; the completion of documentation to support ITAAC submittals; the pace of remaining work package closures and system turnovers; and the availability of craft, supervisory, and technical support resources. Ongoing or future challenges for both units also include management of contractors and vendors; subcontractor performance; and/or related cost escalation. New challenges also may continue to arise, as Unit 3 completes start-up and commissioning and Unit 4 moves further into 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). These challenges may result in further schedule delays and/or cost increases.

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. 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. With the receipt of the NRC's 103(g) finding in August 2022, Unit 3 is now subject to the NRC's operating reactor oversight process and must meet applicable technical and operational requirements contained in its operating license. Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC documentation and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel for Unit 4, may arise, which may result in additional license amendment requests or require other resolution. If any license amendment requests or other licensing-based compliance issues, including inspections and ITAACs for Unit 4, 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 second quarter 2023 for Unit 3 or the first quarter 2024 for Unit 4, including the joint owner cost sharing and tender impacts described below, is estimated to result in additional base capital costs for Georgia Power of up to $15 million per month for Unit 3 and $35 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, of which Georgia Power's share is $8.4 billion (VCM 19 Forecast Amount), 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 VCM 19 Forecast Amount (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 VCM 19 Forecast Amount (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. The Global Amendments provide that if the EAC is revised and exceeds the VCM 19 Forecast Amount 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 VCM 19 Forecast Amount 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 (Project 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 and all the Vogtle Owners 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. The other Vogtle Owners notified Georgia Power that they believe the project capital cost forecast approved by the Vogtle Owners in February 2022 triggered the tender provisions. In June 2022 and July 2022, OPC and Dalton, respectively, notified Georgia Power of their purported exercises of their tender options. Georgia Power did not accept these purported tender exercises.

In June 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 had 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. In July 2022, Georgia Power filed its answers in the lawsuits filed by MEAG Power and OPC 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. In September 2022, Dalton filed complaints in each of these lawsuits. Also in September 2022, Georgia Power and MEAG Power reached an agreement to resolve their dispute regarding the proper interpretation of the cost-sharing and tender provisions of the Global Amendments. Under the terms of the agreement, among other items, (i) MEAG Power will not exercise its tender option and will retain its full ownership interest in Plant Vogtle Units 3 and 4; (ii) Georgia Power will reimburse a portion of MEAG Power's costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs, which payments will total approximately $92 million based on the current project capital cost forecast; and (iii) Georgia Power will reimburse 20% of MEAG Power's costs of construction with respect to any amounts over the current project capital cost forecast, with no further adjustment for force majeure costs. In addition, MEAG Power agreed to vote to continue construction upon occurrence of a Project Adverse Event unless the commercial operation date of either of Plant Vogtle Unit 3 or Unit 4 is not projected to occur by December 31, 2025. In October 2022, MEAG Power and Georgia Power filed a notice of settlement and voluntary dismissal of their pending litigation, including Georgia Power's counterclaim, and Dalton dismissed its related complaint.

Georgia Power recorded pre-tax charges to income through the fourth quarter 2022 of $407 million ($304 million after tax) associated with the cost-sharing and tender provisions of the Global Amendments, including the settlement with MEAG Power. This total is included in the total project capital cost forecast and will not be recovered from retail customers. The settlement with MEAG Power does not resolve the separate pending litigation with OPC, including Dalton's associated complaint, described above. Georgia Power may be required to record further pre-tax charges to income of up to approximately $345 million associated with the cost-sharing and tender provisions of the Global Amendments for OPC and Dalton based on the current project capital cost forecast.

Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%. Georgia Power believes the increases in the total project capital cost forecast through December 31, 2022 triggered the tender provisions, but Georgia Power disagrees with OPC and Dalton on the tender provisions trigger date. Valid notices of tender from OPC and Dalton would require Georgia Power to pay 100% of their respective remaining shares of the costs

necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest will 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 March 31, 2023, Georgia Power had recovered approximately $2.9 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 December 2022, the Georgia PSC approved Georgia Power's filing to increase the NCCR tariff by $36 million annually, effective January 1, 2023.

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 at that time) 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 $300 million in 2022 and are estimated to have negative earnings impacts of approximately $270 million in 2023 and $60 million in 2024. 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 also has reviewed two additional VCM reports, which reflected $1.1 billion of additional construction capital costs incurred through June 30, 2022. Georgia Power filed its twenty-eighth VCM report with the Georgia PSC on February 16, 2023, which reflected the revised capital cost forecast described above and $461 million of construction capital costs incurred from July 1, 2022 through December 31, 2022.

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

Mississippi Power

Performance Evaluation Plan

On March 15, 2023, Mississippi Power submitted its annual retail PEP filing for 2023 to the Mississippi PSC indicating no change in retail rates. The ultimate outcome of this matter cannot be determined at this time.

Ad Valorem Tax Adjustment

On March 31, 2023, Mississippi Power submitted its annual ad valorem tax adjustment filing for 2023, which requested a $7 million annual decrease in revenues. The ultimate outcome of this matter cannot be determined at this time.

Environmental Compliance Overview Plan

On April 4, 2023, the Mississippi PSC approved Mississippi Power's annual ECO Plan filing, resulting in a $3 million annual increase in revenues effective with the first billing cycle of May 2023.

System Restoration Rider

On April 4, 2023, the Mississippi PSC approved Mississippi Power's annual SRR filing, which indicated no change in retail rates. Mississippi Power's minimum annual SRR accrual was increased from $8 million to $12 million.

Southern Company Gas

Infrastructure Replacement Programs and Capital Projects

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first three months of 2023 were as follows:

Utility	Program	Three Months Ended March 31, 2023
		(in millions)
Nicor Gas	Investing in Illinois	$	62
Virginia Natural Gas	SAVE	20
Atlanta Gas Light	System Reinforcement Rider	32
Chattanooga Gas	Pipeline Replacement Program	1
Total		$	115

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Contingencies

3 Months Ended

Mar. 31, 2023

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.

Alabama Power

In September 2022, Mobile Baykeeper filed a citizen suit in the U.S. District Court for the Southern District of Alabama alleging that Alabama Power's plan to close the Plant Barry ash pond utilizing a closure-in-place methodology violates the Resource Conservation and Recovery Act (RCRA) and regulations governing CCR. Among other relief requested, Mobile Baykeeper seeks a declaratory judgment that the RCRA and regulations governing CCR are being violated, preliminary and injunctive relief to prevent implementation of Alabama Power's closure plan and the development of a closure plan that satisfies regulations governing CCR requirements. On December 19, 2022, Alabama Power filed a motion to dismiss the case. On January 31, 2023, the EPA issued a Notice of Potential Violations associated with Alabama Power's plan to close the Plant Barry ash pond. Alabama Power submitted responses on March 20, 2023, March 24, 2023, and April 3, 2023 affirming its position that it is in compliance with CCR requirements. The ultimate outcome of these matters cannot be determined at this time but could have an impact on Alabama Power's ARO estimates. See Note 6 to the financial statements in Item 8 of the Form 10-K for a discussion of Alabama Power's ARO liabilities.

Georgia Power

Municipal Franchise Fees

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, which was denied on January 27, 2023. On February 6, 2023, the plaintiffs filed a motion for reconsideration with the Georgia Supreme Court, which was denied on February 16, 2023. This matter is now concluded.

Plant Scherer

In July 2020, a group of individual plaintiffs filed a complaint, which was amended in December 2022, in the Superior Court of Fulton County, Georgia against Georgia Power alleging that the construction and operation of Plant Scherer has impacted groundwater 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 December 2022, the Superior Court of Fulton County, Georgia granted Georgia Power's motion to transfer the case to the Superior Court of Monroe County, Georgia.

In October 2021 and February 2022, a total of seven 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 sought an unspecified amount of monetary damages including punitive damages. In November 2021 and March 2022, Georgia Power removed these cases to the U.S. District Court for the Middle District of Georgia. In November 2022, the plaintiffs voluntarily dismissed their complaints without prejudice. Georgia Power anticipates that these plaintiffs will refile their complaints.

On January 9, 2023, an additional complaint was filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that the construction and operation of Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries. The plaintiff sought an unspecified amount of monetary damages, including punitive damages. On January 19, 2023, Georgia Power filed a notice to remove the case to the U.S. District Court for the Middle District of Georgia. On February 21, 2023, the plaintiff voluntarily dismissed the complaint without prejudice. Georgia Power anticipates that this plaintiff will refile the complaint.

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. In March 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. In May 2022, the U.S. Court of Appeals for the Fifth Circuit denied a petition by Mississippi Power for a rehearing en banc and remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. In June 2022, Mississippi Power filed with the trial court a motion to dismiss the complaint with prejudice, which was granted on March 15, 2023. On March 28, 2023, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. 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 $15 million at both March 31, 2023 and December 31, 2022. 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 $243 million and $256 million at March 31, 2023 and December 31, 2022, 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

Traditional Electric Operating Companies

In April 2019, Bellsouth Telecommunications d/b/a AT&T Alabama (AT&T) filed a complaint against Alabama Power with the FCC alleging that the pole rental rate AT&T is required to pay pursuant to the parties' joint use agreement is unjust and unreasonable under federal law. The complaint sought a new rate and approximately $87 million in refunds of alleged overpayments for the preceding six years. In August 2019, the FCC stayed the case in favor of arbitration, which AT&T has not pursued. The ultimate outcome of this matter cannot be determined at this time, but an adverse outcome could have a material impact on the financial statements of Southern Company and Alabama Power. Georgia Power and Mississippi Power have joint use agreements with other AT&T affiliates.

Mississippi PowerIn August 2022, the Mississippi Department of Revenue (Mississippi DOR) completed an audit of sales and use taxes paid by Mississippi Power from 2016 to 2019 and entered a final assessment, indicating a total amount due of $28 million, including associated penalties and interest. Additional interest of approximately $1 million was estimated through March 31, 2023. Mississippi Power does not agree with the audit findings and, in October 2022, filed an administrative appeal with the Mississippi DOR. See Note 3 to the financial statements in Item 8 of the Form 10-K under "Other Matters – Mississippi Power – Department of Revenue Audit" for information regarding a Mississippi PSC accounting order related to the tax audit proceeding. The ultimate outcome of this matter cannot be determined at this time

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Revenue from Contracts with Customers and Lease Income

3 Months Ended

Mar. 31, 2023

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 months ended March 31, 2023 and 2022:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2023
Operating revenues
Retail electric revenues
Residential	$	1,525	$	659	$	801	$	65	$	—	$	—
Commercial	1,251		430		753		68		—		—
Industrial	789		398		313		78		—		—
Other	27		3		22		2		—		—
Total retail electric revenues	3,592		1,490		1,889		213		—		—
Natural gas distribution revenues
Residential	896		—		—		—		—		896
Commercial	232		—		—		—		—		232
Transportation	319		—		—		—		—		319
Industrial	23		—		—		—		—		23
Other	117		—		—		—		—		117
Total natural gas distribution revenues	1,587		—		—		—		—		1,587
Wholesale electric revenues
PPA energy revenues	284		72		12		4		202		—
PPA capacity revenues	190		60		11		32		89		—
Non-PPA revenues	36		20		3		107		103		—
Total wholesale electric revenues	510		152		26		143		394		—
Other natural gas revenues
Gas marketing services	231		—		—		—		—		231
Other natural gas revenues	11		—		—		—		—		11
Total natural gas revenues	242		—		—		—		—		242
Other revenues	310		54		132		11		11		—
Total revenue from contracts with customers	6,241		1,696		2,047		367		405		1,829
Other revenue sources(*)	239		(49)		129		23		103		46
Total operating revenues	$	6,480	$	1,647	$	2,176	$	390	$	508	$	1,875

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Operating revenues
Retail electric revenues
Residential	$	1,525	$	634	$	821	$	70	$	—	$	—
Commercial	1,178		375		738		65		—		—
Industrial	727		323		334		70		—		—
Other	26		4		20		2		—		—
Total retail electric revenues	3,456		1,336		1,913		207		—		—
Natural gas distribution revenues
Residential	1,016		—		—		—		—		1,016
Commercial	270		—		—		—		—		270
Transportation	337		—		—		—		—		337
Industrial	32		—		—		—		—		32
Other	129		—		—		—		—		129
Total natural gas distribution revenues	1,784		—		—		—		—		1,784
Wholesale electric revenues
PPA energy revenues	342		59		32		3		251		—
PPA capacity revenues	134		39		12		3		81		—
Non-PPA revenues	58		64		9		102		73		—
Total wholesale electric revenues	534		162		53		108		405		—
Other natural gas revenues
Gas marketing services	243		—		—		—		—		243
Other natural gas revenues	16		—		—		—		—		16
Total natural gas revenues	259		—		—		—		—		259
Other revenues	225		48		95		9		8		—
Total revenue from contracts with customers	6,258		1,546		2,061		324		413		2,043
Other revenue sources(*)	390		103		147		11		126		15
Total operating revenues	$	6,648	$	1,649	$	2,208	$	335	$	539	$	2,058

(*)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.

Contract Balances

The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers at March 31, 2023 and December 31, 2022:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At March 31, 2023	$	2,433	$	622	$	672	$	79	$	119	$	853
At December 31, 2022	3,123		696		922		92		237		1,107
Contract Assets
At March 31, 2023	$	160	$	3	$	74	$	—	$	—	$	19
At December 31, 2022	156		2		89		—		—		—
Contract Liabilities
At March 31, 2023	$	61	$	2	$	14	$	1	$	1	$	—
At December 31, 2022	45		4		9		—		1		—

Contract assets for Georgia Power primarily relate 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 primarily relate to cash collections recognized in advance of revenue for unregulated service agreements. At March 31, 2023, Southern Company Gas' contract assets relate to work performed on an energy efficiency enhancement and upgrade contract with the U.S. General Services Administration. Southern Company Gas receives cash advances from a third-party financial institution to fund work performed, of which approximately $30 million had been received at March 31, 2023. These advances have been accounted for as long-term debt on the balance sheets. See Note 1 to the financial statements under "Affiliate Transactions" in Item 8 of the Form 10-K for additional information regarding the construction contract. At March 31, 2023 and December 31, 2022, Southern Company's unregulated distributed generation business had contract assets of $64 million and $65 million, respectively, and contract liabilities of $44 million and $32 million, respectively, for outstanding performance obligations.

Revenues recognized in the three months ended March 31, 2023, which were included in contract liabilities at December 31, 2022, were $19 million for Southern Company and immaterial for the other Registrants.

Remaining Performance Obligations

The Subsidiary Registrants may enter into long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. For Alabama Power, Georgia Power, 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 primarily relate to the U.S. General Services Administration contract described above. 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 March 31, 2023 are expected to be recognized as follows:

	2023 (remaining)		2024		2025		2026		2027		Thereafter
	(in millions)
Southern Company	$	632	$	553	$	347	$	315	$	319	$	2,089
Alabama Power	17		7		6		—		—		—
Georgia Power	68		60		25		13		14		23
Southern Power	268		345		302		303		310		2,077
Southern Company Gas	15		29		—		—		—		—

Lease Income

Lease income for the three months ended March 31, 2023 and 2022 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended March 31, 2023
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	49		18		7		1		21		9
Variable lease income	69		—		—		—		75		—
Total lease income	$	124	$	18	$	7	$	5	$	98	$	9
For the Three Months Ended March 31, 2022
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	51		20		8		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	141	$	20	$	8	$	4	$	113	$	9

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

3 Months Ended

Mar. 31, 2023

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 March 31, 2023 and December 31, 2022, SP Solar had total assets of $5.8 billion and $5.9 billion, respectively, total liabilities of $0.4 billion, and noncontrolling interests of $1.0 billion and $1.1 billion, respectively. 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 March 31, 2023 and December 31, 2022, SP Wind had total assets of $2.2 billion, total liabilities of $172 million and $169 million, respectively, and noncontrolling interests of $39 million. 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 March 31, 2023 and December 31, 2022, the other VIEs had total assets of $1.8 billion, total liabilities of $0.2 billion, and noncontrolling interests of $0.8 billion. 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 December 31, 2022, Southern Power had equity method investments in wind and battery energy storage projects totaling $49 million. During the first quarter 2023, Southern Power sold its remaining equity method investments in the projects and received proceeds of $50 million. Earnings (loss) from these investments, including the gains associated with the sales, were immaterial for the three months ended March 31, 2023 and 2022.

Southern Company Gas

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at March 31, 2023 and December 31, 2022 and related earnings from those investments for the three months ended March 31, 2023 and 2022 were as follows:

Investment Balance	March 31, 2023		December 31, 2022
	(in millions)
SNG	$	1,249	$	1,243
Other	33		33
Total	$	1,282	$	1,276

	Three Months Ended March 31,
Earnings from Equity Method Investments	2023		2022
	(in millions)
SNG	$	44	$	39
Other	1		1
Total	$	45	$	40

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Financing and Leases

3 Months Ended

Mar. 31, 2023

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 March 31, 2023, 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		225		—
Southern Power(a)	—		—		—		600		600		587		—
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	$	7,564	$	280

(a)Does not include Southern Power Company's $75 million and $100 million continuing letter of credit facilities for standby letters of credit, expiring in 2025 and 2026, respectively, of which $9 million and $16 million, respectively, was unused at March 31, 2023. In March 2023, Southern Power amended the $100 million letter of credit facility, which, among other things, extended the expiration date from 2025 to 2026 and increased the amount from $75 million. 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 under a $250 million credit arrangement expiring in 2023.

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 March 31, 2023, 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 March 31, 2023 was approximately $1.7 billion (comprised of approximately $789 million at Alabama Power, $819 million at Georgia Power, and $69 million at Mississippi Power). In addition, at March 31, 2023, Alabama Power and Georgia Power had approximately $120 million and $285 million, respectively, of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

Convertible Senior Notes

In February 2023, Southern Company issued $1.5 billion aggregate principal amount of Series 2023A 3.875% Convertible Senior Notes due December 15, 2025 (Series 2023A Convertible Senior Notes). In March 2023, Southern Company issued an additional $225 million aggregate principal amount of the Series 2023A Convertible Senior Notes upon the exercise by the initial purchasers of their over-allotment option.

Interest on the Series 2023A Convertible Senior Notes is payable semiannually, beginning June 15, 2023. The Series 2023A Convertible Senior Notes will mature on December 15, 2025, unless earlier converted or repurchased, but are not redeemable at the option of Southern Company. The Series 2023A Convertible Senior Notes are direct, unsecured, and unsubordinated obligations of Southern Company, ranking equally with all of Southern Company's other unsecured and unsubordinated indebtedness from time to time outstanding, and are effectively subordinated to all secured indebtedness of Southern Company.

Holders may convert their Series 2023A Convertible Senior Notes at their option prior to the close of business on the business day preceding September 15, 2025, but only under the following circumstances:

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

•during the five business day period after any 10 consecutive trading day period (Measurement Period) in which the trading price per $1,000 principal amount of Series 2023A Convertible Senior Notes for each trading day of the Measurement Period was less than 98% of the product of the last reported sale price of the common stock and the conversion rate on each such trading day; or

•upon the occurrence of certain corporate events specified in the indenture governing the Series 2023A Convertible Senior Notes.

On or after September 15, 2025, a holder may convert all or any portion of its Series 2023A Convertible Senior Notes at any time prior to the close of business on the second scheduled trading day immediately preceding the maturity date regardless of the foregoing conditions.

Southern Company will settle conversions of the Series 2023A Convertible Senior Notes by paying cash up to the aggregate principal amount of the Series 2023A Convertible Senior Notes to be converted and paying or delivering, as the case may be, cash, shares of common stock or a combination of cash and shares of common stock, at Southern Company's election, in respect of the remainder, if any, of Southern Company's conversion obligation in excess of the aggregate principal amount of the Series 2023A Convertible Senior Notes being converted. The Series 2023A Convertible Senior Notes are initially convertible at a rate of 11.8818 shares of common stock per $1,000 principal amount converted, which is approximately equal to $84.16 per share of common stock. The conversion rate will be subject to adjustment upon the occurrence of certain specified events but will not be adjusted for accrued and unpaid interest. In addition, upon the occurrence of a make-whole fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes), Southern Company will, in certain circumstances, increase the conversion rate by a number of additional shares of common stock for conversions in connection with the make-whole fundamental change.

Upon the occurrence of a fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes), holders of the Series 2023A Convertible Senior Notes may require Southern Company to purchase all or a portion of their Series 2023A Convertible Senior Notes, in principal amounts equal to $1,000 or an integral multiple thereof, for cash at a price equal to 100% of the principal amount of the Series 2023A Convertible Senior Notes to be purchased plus any accrued and unpaid interest.

Earnings per Share

For Southern Company, the only difference in computing basic and diluted earnings per share (EPS) is attributable to awards outstanding under stock-based compensation plans and the Series 2023A Convertible Senior Notes. EPS dilution resulting from stock-based compensation plans is determined using the treasury stock method and EPS dilution resulting from the Series 2023A Convertible Senior Notes is determined using the net share settlement method. See Note 12 to the financial statements in Item 8 of the Form 10-K and "Convertible Senior Notes" herein for additional information. Shares used to compute diluted EPS were as follows:

	Three Months Ended March 31,
	2023	2022
	(in millions)
As reported shares	1,091	1,063
Effect of stock-based compensation	7	6
Diluted shares	1,098	1,069

For the three months ended March 31, 2023, there were no anti-dilutive shares. For the three months ended March 31, 2022, an immaterial number of stock-based compensation awards was excluded from the diluted EPS calculation because the awards were anti-dilutive.

For both periods presented, there was no dilution resulting from the Series 2023A Convertible Senior Notes.

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. In June 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. Subsequently, the lessee failed to make the semi-annual lease payment due in December 2022. As a result, the Southern Holdings subsidiary was unable to make its corresponding payment to the holders of the underlying non-recourse debt related to the generation assets. The parties to the lease have entered into a forbearance agreement which suspends the related contractual rights of the parties while they continue restructuring negotiations, 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. Southern Company will continue to monitor the operational performance of the underlying assets and evaluate the ability of the lessee to continue to make the required lease payments and meet its obligations associated with a future closure or retirement of the generation assets and associated properties, including the dry ash landfill.

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Income Taxes

3 Months Ended

Mar. 31, 2023

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

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 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 10.8% for the three months ended March 31, 2023 compared to 14.9% for the corresponding period in 2022. The effective tax rate decrease was primarily due to an increase in the flowback of certain excess deferred income taxes at Alabama Power in 2023, partially offset by the flowback of certain excess deferred income taxes ending in 2022 at Georgia Power.

Alabama Power

Alabama Power's effective tax benefit rate was (0.8)% for the three months ended March 31, 2023 compared to an effective tax rate of 23.3% for the corresponding period in 2022. The effective tax rate decrease was primarily due to an increase in the flowback of certain excess deferred income taxes in 2023. See Note 2 to the financial statements under "Alabama Power – Excess Accumulated Deferred Income Tax Accounting Order" in Item 8 of the Form 10-K for additional information.

Georgia Power

Georgia Power's effective tax rate was 15.1% for the three months ended March 31, 2023 compared to 7.3% for the corresponding period in 2022. The effective tax rate increase was primarily due to the flowback of certain excess deferred income taxes ending in 2022.

Southern Power

Southern Power's effective tax benefit rate was (20.7)% for the three months ended March 31, 2023 compared to (80.0)% for the corresponding period in 2022. The effective tax rate increase was primarily due to higher pre-tax earnings and the impacts of noncontrolling interests.

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Retirement Benefits

3 Months Ended

Mar. 31, 2023

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, 2023. 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.

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 months ended March 31, 2023 and 2022 are presented in the following tables.

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2023
Pension Plans
Service cost	$	69	$	16	$	17	$	3	$	2	$	6
Interest cost	156		36		48		7		2		11
Expected return on plan assets	(307)		(74)		(96)		(14)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net (gain) loss	8		2		3		—		—		(1)
Net periodic pension income	$	(74)	$	(20)	$	(28)	$	(4)	$	—	$	(3)
Postretirement Benefits
Service cost	$	4	$	1	$	1	$	—	$	—	$	—
Interest cost	18		4		6		1		—		2
Expected return on plan assets	(21)		(8)		(7)		(1)		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net gain	(3)		(1)		(1)		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(2)	$	(4)	$	(1)	$	—	$	—	$	1

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Pension Plans
Service cost	$	103	$	25	$	26	$	4	$	2	$	9
Interest cost	102		24		31		5		2		7
Expected return on plan assets	(316)		(77)		(99)		(15)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	60		16		18		3		1		2
Net periodic pension cost (income)	$	(51)	$	(12)	$	(24)	$	(3)	$	1	$	(1)
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	10		3		4		—		—		1
Expected return on plan assets	(20)		(8)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1

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Fair Value Measurements

3 Months Ended

Mar. 31, 2023

Fair Value Disclosures [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS

At March 31, 2023, 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 March 31, 2023	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)	$	4	$	100	$	—	$	—	$	104
Interest rate derivatives	—		2		—		—		2
Investments in trusts:(b)(c)
Domestic equity	680		192		—		—		872
Foreign equity	138		162		—		—		300
U.S. Treasury and government agency securities	—		316		—		—		316
Municipal bonds	—		48		—		—		48
Pooled funds – fixed income	—		7		—		—		7
Corporate bonds	—		403		—		—		403
Mortgage and asset backed securities	—		90		—		—		90
Private equity	—		—		—		160		160
Cash and cash equivalents	2		—		—		—		2
Other	40		12		—		9		61
Cash equivalents	433		13		—		—		446
Other investments	9		29		8		—		46
Total	$	1,306	$	1,374	$	8	$	169	$	2,857
Liabilities:
Energy-related derivatives(a)	$	40	$	354	$	—	$	—	$	394
Interest rate derivatives	—		261		—		—		261
Foreign currency derivatives	—		218		—		—		218
Contingent consideration	—		—		12		—		12
Other	—		13		—		—		13
Total	$	40	$	846	$	12	$	—	$	898

	Fair Value Measurements Using:
At March 31, 2023	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	$	—	$	32	$	—	$	—	$	32
Nuclear decommissioning trusts:(b)
Domestic equity	404		185		—		—		589
Foreign equity	138		—		—		—		138
U.S. Treasury and government agency securities	—		19		—		—		19
Municipal bonds	—		1		—		—		1
Corporate bonds	—		223		—		—		223
Mortgage and asset backed securities	—		22		—		—		22
Private equity	—		—		—		160		160
Other	7		—		—		9		16
Cash equivalents	193		13		—		—		206
Other investments	—		29		—		—		29
Total	$	742	$	524	$	—	$	169	$	1,435
Liabilities:
Energy-related derivatives	$	—	$	96	$	—	$	—	$	96
Georgia Power
Assets:
Energy-related derivatives	$	—	$	22	$	—	$	—	$	22
Nuclear decommissioning trusts:(b)(c)
Domestic equity	276		1		—		—		277
Foreign equity	—		161		—		—		161
U.S. Treasury and government agency securities	—		297		—		—		297
Municipal bonds	—		47		—		—		47
Corporate bonds	—		180		—		—		180
Mortgage and asset backed securities	—		68		—		—		68
Other	33		12		—		—		45
Total	$	309	$	788	$	—	$	—	$	1,097
Liabilities:
Energy-related derivatives	$	—	$	132	$	—	$	—	$	132
Interest rate derivatives	—		1		—		—		1
Total	$	—	$	133	$	—	$	—	$	133

	Fair Value Measurements Using:
At March 31, 2023	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	$	—	$	35	$	—	$	—	$	35
Cash equivalents	3		—		—		—		3
Total	$	3	$	35	$	—	$	—	$	38
Liabilities:
Energy-related derivatives	$	—	$	62	$	—	$	—	$	62
Southern Power
Assets:
Energy-related derivatives	$	—	$	5	$	—	$	—	$	5
Cash equivalents	13		—		—		—		13
Total	$	13	$	5	$	—	$	—	$	18
Liabilities:
Energy-related derivatives	$	—	$	14	$	—	$	—	$	14
Foreign currency derivatives	—		47		—		—		47
Contingent consideration	—		—		12		—		12
Other	—		13		—		—		13
Total	$	—	$	74	$	12	$	—	$	86
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	4	$	6	$	—	$	—	$	10
Interest rate derivatives	—		1		—		—		1
Non-qualified deferred compensation trusts:
Domestic equity	—		6		—		—		6
Foreign equity	—		1		—		—		1
Pooled funds – fixed income	—		7		—		—		7
Cash equivalents	2		—		—		—		2
Cash equivalents and restricted cash	55		—		—		—		55
Total	$	61	$	21	$	—	$	—	$	82
Liabilities:
Energy-related derivatives(a)	$	40	$	50	$	—	$	—	$	90
Interest rate derivatives	—		72		—		—		72
Total	$	40	$	122	$	—	$	—	$	162

(a)Excludes cash collateral of $60 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 March 31, 2023, approximately $37 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 months ended March 31, 2023 and 2022. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

	Three Months Ended
Fair value increases (decreases)	March 31, 2023		March 31, 2022
	(in millions)
Southern Company	$	102	$	(150)
Alabama Power	45		(67)
Georgia Power	57		(83)

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" primarily includes investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds.

At March 31, 2023, the fair value measurements of private market investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $169 million and unfunded commitments related to the private market investments totaled $75 million. Private market investments include high-quality private equity funds across several market sectors, funds that invest in real estate assets, and a private credit fund. Private market funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated.

At March 31, 2023, 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	$	56.1	$	10.6	$	14.9	$	1.5	$	3.0	$	7.5
Fair value	51.6		9.5		13.7		1.3		2.9		6.7

(*)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

3 Months Ended

Mar. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

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. 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.

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 March 31, 2023, 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(*)	437	2030	2028
Alabama Power	111	2026	2023
Georgia Power	122	2026	2023
Mississippi Power	86	2027	2023
Southern Power	11	2030	2023
Southern Company Gas(*)	107	2028	2028

(*)Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 113.6 million mmBtu and short natural gas positions of 6.6 million mmBtu at March 31, 2023, 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 22 million mmBtu for Southern Company, which includes 6 million mmBtu for Alabama Power, 8 million mmBtu for Georgia Power, 3 million mmBtu for Mississippi Power, and 5 million mmBtu for Southern Power.

For cash flow hedges of energy-related derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2024 are $(42) million for Southern Company, $(12) million for Southern Power, $(30) million for Southern Company Gas, and 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 March 31, 2023, the following interest rate derivatives were outstanding:

	Notional Amount		Weighted Average Interest Rate Paid	Interest Rate Received	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2023
	(in millions)					(in millions)
Cash Flow Hedges of Forecasted Debt
Georgia Power	$	750	3.63%	N/A	February 2033	$	(1)
Southern Company parent	500		3.47%	N/A	June 2033	—
Southern Company Gas	250		3.40%	N/A	August 2033	1
Fair Value Hedges of Existing Debt
Southern Company parent	400		1-month LIBOR + 0.68%	1.75%	March 2028	(45)
Southern Company parent	1,000		1-month LIBOR + 2.36%	3.70%	April 2030	(142)
Southern Company Gas	500		1-month LIBOR + 0.38%	1.75%	January 2031	(71)
Southern Company	$	3,400				$	(258)

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 March 31, 2024 are $(15) million for Southern Company and 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 March 31, 2023, the following foreign currency derivatives were outstanding:

	Pay Notional		Pay Rate	Receive Notional		Receive Rate	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2023
	(in millions)			(in millions)				(in millions)
Cash Flow Hedges of Existing Debt
Southern Power	$	564	3.78%	€	500	1.85%	June 2026	$	(47)
Fair Value Hedges of Existing Debt
Southern Company parent	1,476		3.39%	1,250		1.88%	September 2027	(171)
Southern Company	$	2,040		€	1,750			$	(218)

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 March 31, 2024 are $11 million for Southern Power.

Derivative Financial Statement Presentation and Amounts

The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.

The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Liabilities from risk management activities	$	41	$	230	$	123	$	121
Other deferred charges and assets/Other deferred credits and liabilities	53		113		52		44
Total derivatives designated as hedging instruments for regulatory purposes	94		343		175		165
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities	—		38		3		27
Other deferred charges and assets/Other deferred credits and liabilities	4		4		6		4
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities	2		71		12		62
Other deferred charges and assets/Other deferred credits and liabilities	—		191		—		240
Foreign currency derivatives:
Assets from risk management activities/Liabilities from risk management activities	—		35		—		34
Other deferred charges and assets/Other deferred credits and liabilities	—		183		—		182
Total derivatives designated as hedging instruments in cash flow and fair value hedges	6		522		21		549
Energy-related derivatives not designated as hedging instruments
Assets from risk management activities/Liabilities from risk management activities	4		8		13		13
Other deferred charges and assets/Other deferred credits and liabilities	2		1		2		1
Total derivatives not designated as hedging instruments	6		9		15		14
Gross amounts recognized	106		874		211		728
Gross amounts offset(a)	(57)		(118)		(70)		(111)
Net amounts recognized in the Balance Sheets(b)	$	49	$	756	$	141	$	617

	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power(c)
Energy-related derivatives designated as hedging instruments for regulatory purposes
Other current assets/Other current liabilities	$	14	$	54	$	42	$	21
Other deferred charges and assets/Other deferred credits and liabilities	18		42		20		18
Total derivatives designated as hedging instruments for regulatory purposes	32		96		62		39
Gross amounts offset	(28)		(28)		(24)		(24)
Net amounts recognized in the Balance Sheets	$	4	$	68	$	38	$	15
Georgia Power
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Other current liabilities	$	10	$	86	$	36	$	43
Other deferred charges and assets/Other deferred credits and liabilities	11		45		6		18
Total derivatives designated as hedging instruments for regulatory purposes	21		131		42		61
Interest rate derivatives designated as hedging instruments in cash flow and fair value hedges
Assets from risk management activities/Other current liabilities	—		1		—		—
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	1		1		—		1
Gross amounts recognized	22		133		42		62
Gross amounts offset	(19)		(19)		(21)		(21)
Net amounts recognized in the Balance Sheets	$	3	$	114	$	21	$	41
Mississippi Power(c)
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Other current liabilities	$	11	$	37	$	33	$	24
Other deferred charges and assets/Other deferred credits and liabilities	24		25		26		8
Total derivatives designated as hedging instruments for regulatory purposes	35		62		59		32
Gross amounts offset	(25)		(25)		(17)		(17)
Net amounts recognized in the Balance Sheets	$	10	$	37	$	42	$	15

	At March 31, 2023				At December 31, 2022
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	$	—	$	12	$	—	$	12
Other deferred charges and assets/Other deferred credits and liabilities	4		—		5		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		11		—		11
Other deferred charges and assets/Other deferred credits and liabilities	—		36		—		36
Total derivatives designated as hedging instruments in cash flow and fair value hedges	4		59		5		59
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	—		2		2		—
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	1		2		3		—
Gross amounts recognized	5		61		8		59
Net amounts recognized in the Balance Sheets	$	5	$	61	$	8	$	59

	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Energy-related derivatives designated as hedging instruments for regulatory purposes
Other current assets/Other current liabilities	$	6	$	53	$	12	$	33
Other deferred charges and assets/Other deferred credits and liabilities	—		1		—		—
Total derivatives designated as hedging instruments for regulatory purposes	6		54		12		33
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	—		26		3		15
Other deferred charges and assets/Other deferred credits and liabilities	—		4		1		4
Interest rate derivatives:
Other current assets/Other current liabilities	1		19		—		14
Other deferred charges and assets/Other deferred credits and liabilities	—		53		—		72
Total derivatives designated as hedging instruments in cash flow and fair value hedges	1		102		4		105
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	3		5		11		12
Other deferred charges and assets/Other deferred credits and liabilities	1		1		1		1
Total derivatives not designated as hedging instruments	4		6		12		13
Gross amounts recognized	11		162		28		151
Gross amounts offset(a)	18		(43)		—		(41)
Net amounts recognized in the Balance Sheets(b)	$	29	$	119	$	28	$	110

(a)Gross amounts offset includes cash collateral held on deposit in broker margin accounts of $60 million and $41 million at March 31, 2023 and December 31, 2022, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for both periods presented.

(c)Energy-related derivatives not designated as hedging instruments were immaterial for Alabama Power and Mississippi Power for both periods presented.

At March 31, 2023 and December 31, 2022, 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 March 31, 2023:
Energy-related derivatives:
Other regulatory assets, current	$	(198)	$	(44)	$	(78)	$	(29)	$	(47)
Other regulatory assets, deferred	(67)		(24)		(35)		(8)		—
Other regulatory liabilities, current	19		3		2		3		11
Other regulatory liabilities, deferred	9		1		1		7		—
Total energy-related derivative gains (losses)	$	(237)	$	(64)	$	(110)	$	(27)	$	(36)
At December 31, 2022:
Energy-related derivatives:
Other regulatory assets, current	$	(71)	$	(8)	$	(26)	$	(13)	$	(24)
Other regulatory assets, deferred	(23)		(7)		(14)		(2)		—
Other regulatory liabilities, current	72		29		19		22		2
Other regulatory liabilities, deferred	31		9		2		20		—
Total energy-related derivative gains (losses)	$	9	$	23	$	(19)	$	27	$	(22)

For the three months ended March 31, 2023 and 2022, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI for the applicable Registrants were as follows:

Gain (Loss) Recognized in OCI on Derivatives	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	(45)	$	42
Interest rate derivatives	(13)		9
Foreign currency derivatives	—		(28)
Fair value hedges(*):
Foreign currency derivatives	(28)		4
Total	$	(86)	$	27
Georgia Power
Cash flow hedges:
Interest rate derivatives	$	(1)	$	12
Southern Power
Cash flow hedges:
Energy-related derivatives	$	(11)	$	5
Foreign currency derivatives	—		(28)
Total	$	(11)	$	(23)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	(34)	$	37
Interest rate derivatives	1		—
Total	$	(33)	$	37

(*)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 months ended March 31, 2023, the pre-tax effects of energy-related derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for Alabama Power and Mississippi Power. There were no such instruments for Alabama Power and Mississippi Power at March 31, 2022.

For the three months ended March 31, 2023 and 2022, 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 March 31,
	2023		2022
	(in millions)
Southern Company
Total cost of natural gas	$	898	$	1,095
Gain (loss) on energy-related cash flow hedges(a)	(20)		9
Total depreciation and amortization	1,111		892
Gain (loss) on energy-related cash flow hedges(a)	(9)		2
Total interest expense, net of amounts capitalized	(582)		(462)
Gain (loss) on interest rate cash flow hedges(a)	(4)		(7)
Gain (loss) on foreign currency cash flow hedges(a)	(3)		(6)
Gain (loss) on interest rate fair value hedges(b)	43		(123)
Total other income (expense), net	147		145
Gain (loss) on foreign currency cash flow hedges(a)(c)	10		(25)
Gain (loss) on foreign currency fair value hedges	(2)		(24)
Amount excluded from effectiveness testing recognized in earnings	28		(4)
Southern Power
Total depreciation and amortization	$	128	$	120
Gain (loss) on energy-related cash flow hedges(a)	(9)		2
Total interest expense, net of amounts capitalized	(33)		(37)
Gain (loss) on foreign currency cash flow hedges(a)	(3)		(6)
Total other income (expense), net	2		2
Gain (loss) on foreign currency cash flow hedges(a)(c)	10		(25)
Southern Company Gas
Total cost of natural gas	$	898	$	1,095
Gain (loss) on energy-related cash flow hedges(a)	(20)		9
Total interest expense, net of amounts capitalized	(76)		(61)
Gain (loss) on interest rate cash flow hedges(a)	(1)		(1)
Gain (loss) on interest rate fair value hedges(b)	13		(36)

(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.

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 for both periods presented.

At March 31, 2023 and December 31, 2022, 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 March 31, 2023		At December 31, 2022		At March 31, 2023		At December 31, 2022
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(3,007)	$	(2,927)	$	228	$	282
Southern Company Gas
Long-term debt	$	(428)	$	(415)	$	69	$	81

For the three months ended March 31, 2023 and 2022, 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 March 31,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location		2023		2022
			(in millions)
Energy-related derivatives:	Natural gas revenues(*)		$	—	$	2
	Cost of natural gas		13		21
Total derivatives in non-designated hedging relationships			$	13	$	23

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

For the three months ended March 31, 2023 and 2022, 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. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. At March 31, 2023, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For Southern Company and Southern Power, the fair value of interest rate derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were $73 million and $23 million, respectively, at March 31, 2023. For the traditional electric operating companies and Southern Power, energy-related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were immaterial at March 31, 2023. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade.

Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions and they may be required to post collateral based on the value of the positions in

these accounts and the associated margin requirements. At March 31, 2023, cash collateral posted in these accounts was $15 million for Southern Power and immaterial for Alabama Power. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At March 31, 2023, cash collateral held on deposit in broker margin accounts was $60 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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Segment and Related Information

3 Months Ended

Mar. 31, 2023

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.

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 $135 million and $105 million for the three months ended March 31, 2023 and 2022, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies and Southern Power were immaterial for both periods presented. The "All Other" column includes the Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications and, for the three months ended March 31, 2022, leveraged lease projects. All other inter-segment revenues are not material.

Financial data for business segments and products and services for the three months ended March 31, 2023 and 2022 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 March 31, 2023
Operating revenues	$	4,113	$	508	$	(138)	$	4,483	$	1,875	$	166	$	(44)	$	6,480
Segment net income (loss)(a)(b)	610		102		—		712		309		(154)		(5)		862
At March 31, 2023
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	144	$	—	$	5,161
Total assets	96,223		13,134		(575)		108,782		24,222		2,606		(854)		134,756
Three Months Ended March 31, 2022
Operating revenues	$	4,191	$	539	$	(221)	$	4,509	$	2,058	$	123	$	(42)	$	6,648
Segment net income (loss)(a)	774		72		—		846		319		(125)		(8)		1,032
At December 31, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	144	$	—	$	5,161
Total assets	95,861		13,081		(659)		108,283		24,621		2,665		(678)		134,891

(a)Attributable to Southern Company.

(b)For Southern Power, includes a $16 million pre-tax gain ($12 million after tax) on the sale of spare parts.

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2023	$	3,599	$	599	$	285	$	4,483
Three Months Ended March 31, 2022	3,613		664		232		4,509

	Southern Company Gas' Revenues
	Gas Distribution Operations		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended March 31, 2023	$	1,610	$	246	$	19	$	1,875
Three Months Ended March 31, 2022	1,791		243		24		2,058

Southern Company Gas

Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. The non-reportable segments are combined and presented as all other.

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. 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 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. The all other column included a natural gas storage facility in Texas through its sale in November 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information, including the sale of a natural gas storage facility in California expected to be completed later in 2023.

Business segment financial data for the three months ended March 31, 2023 and 2022 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2023
Operating revenues	$	1,618	$	8	$	246	$	1,872	$	12	$	(9)	$	1,875
Segment net income	221		31		50		302		7		—		309
Total assets at March 31, 2023	22,223		1,583		1,596		25,402		9,598		(10,778)		24,222
Three Months Ended March 31, 2022
Operating revenues	$	1,803	$	8	$	243	$	2,054	$	16	$	(12)	$	2,058
Segment net income	214		29		66		309		10		—		319
Total assets at December 31, 2022	22,040		1,577		1,616		25,233		8,943		(9,555)		24,621

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Introduction (Policies)

3 Months Ended

Mar. 31, 2023

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, 2022 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 March 31, 2023 and 2022. 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. 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.

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. 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.

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.

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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Introduction (Tables)

3 Months Ended

Mar. 31, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Goodwill

Goodwill at March 31, 2023 and December 31, 2022 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,161
Southern Company Gas:
Gas distribution operations	$	4,034
Gas marketing services	981
Southern Company Gas total	$	5,015

Schedule of Other Intangible Assets, Indefinite-Lived

Other intangible assets were as follows:

	At March 31, 2023						At December 31, 2022
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Subject to amortization:
Customer relationships	$	212	$	(164)	$	48	$	212	$	(162)	$	50
Trade names	64		(47)		17		64		(44)		20
PPA fair value adjustments	390		(134)		256		390		(129)		261
Other	6		(5)		1		5		(5)		—
Total subject to amortization	$	672	$	(350)	$	322	$	671	$	(340)	$	331
Not subject to amortization:
FCC licenses	75		—		75		75		—		75
Total other intangible assets	$	747	$	(350)	$	397	$	746	$	(340)	$	406
Southern Power(*)
PPA fair value adjustments	$	390	$	(134)	$	256	$	390	$	(129)	$	261
Southern Company Gas(*)
Gas marketing services
Customer relationships	$	156	$	(140)	$	16	$	156	$	(139)	$	17
Trade names	26		(19)		7		26		(17)		9
Total other intangible assets	$	182	$	(159)	$	23	$	182	$	(156)	$	26

(*) All subject to amortization.

Schedule of Other Intangible Assets, Finite-Lived

Other intangible assets were as follows:

	At March 31, 2023						At December 31, 2022
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Subject to amortization:
Customer relationships	$	212	$	(164)	$	48	$	212	$	(162)	$	50
Trade names	64		(47)		17		64		(44)		20
PPA fair value adjustments	390		(134)		256		390		(129)		261
Other	6		(5)		1		5		(5)		—
Total subject to amortization	$	672	$	(350)	$	322	$	671	$	(340)	$	331
Not subject to amortization:
FCC licenses	75		—		75		75		—		75
Total other intangible assets	$	747	$	(350)	$	397	$	746	$	(340)	$	406
Southern Power(*)
PPA fair value adjustments	$	390	$	(134)	$	256	$	390	$	(129)	$	261
Southern Company Gas(*)
Gas marketing services
Customer relationships	$	156	$	(140)	$	16	$	156	$	(139)	$	17
Trade names	26		(19)		7		26		(17)		9
Total other intangible assets	$	182	$	(159)	$	23	$	182	$	(156)	$	26

(*) All subject to amortization.

Schedule of Amortization of Other Intangible Assets

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2023		March 31, 2022
	(in millions)
Southern Company(a)	$	10	$	10
Southern Power(b)	5		5
Southern Company Gas	3		3

(a)Includes $5 million recorded as a reduction to operating revenues for both periods presented.

(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		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
At March 31, 2023
Cash and cash equivalents	$	1,053	$	—	$	123	$	88
Restricted cash(a):
Other current assets	117		115		—		2
Other deferred charges and assets	47		45		3		—
Total cash, cash equivalents, and restricted cash(b)	$	1,217	$	160	$	126	$	89
At December 31, 2022
Cash and cash equivalents	$	1,917	$	364	$	131	$	81
Restricted cash(a):
Other current assets	62		60		—		2
Other deferred charges and assets	58		56		3		—
Total cash, cash equivalents, and restricted cash(b)	$	2,037	$	480	$	133	$	83

(a)For Georgia Power, reflects $116 million at both March 31, 2023 and December 31, 2022 related to proceeds from the issuance of solid waste disposal facility revenue bonds in 2022 and $44 million at March 31, 2023 related to funds from a Georgia Housing and Finance Authority (GHFA) rental assistance program used to offset qualifying customers' past due balances, which expired on March 31, 2023 and will be returned to the GHFA. For Southern Power, reflects $3 million at both March 31, 2023 and December 31, 2022 held to fund estimated construction completion costs at the Deuel Harvest wind facility. 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		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
At March 31, 2023
Cash and cash equivalents	$	1,053	$	—	$	123	$	88
Restricted cash(a):
Other current assets	117		115		—		2
Other deferred charges and assets	47		45		3		—
Total cash, cash equivalents, and restricted cash(b)	$	1,217	$	160	$	126	$	89
At December 31, 2022
Cash and cash equivalents	$	1,917	$	364	$	131	$	81
Restricted cash(a):
Other current assets	62		60		—		2
Other deferred charges and assets	58		56		3		—
Total cash, cash equivalents, and restricted cash(b)	$	2,037	$	480	$	133	$	83

(a)For Georgia Power, reflects $116 million at both March 31, 2023 and December 31, 2022 related to proceeds from the issuance of solid waste disposal facility revenue bonds in 2022 and $44 million at March 31, 2023 related to funds from a Georgia Housing and Finance Authority (GHFA) rental assistance program used to offset qualifying customers' past due balances, which expired on March 31, 2023 and will be returned to the GHFA. For Southern Power, reflects $3 million at both March 31, 2023 and December 31, 2022 held to fund estimated construction completion costs at the Deuel Harvest wind facility. 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 Storm Damage Reserve Activity

Storm damage reserve activity for the traditional electric operating companies during the three months ended March 31, 2023 was as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power
	(in millions)
Balance at December 31, 2022	$	216	$	97	$	83	$	36
Accrual	13		3		8		2
Weather-related damages	(43)		(12)		(31)		—
Balance at March 31, 2023	$	186	$	88	$	60	$	38

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Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2023

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 March 31, 2023 and December 31, 2022 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2023		December 31, 2022
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, current	$	23	$	47
	Other regulatory assets, deferred	18		—
Rate CNP PPA	Other regulatory assets, current	17		18
	Other regulatory assets, deferred	100		102
Retail Energy Cost Recovery	Other regulatory assets, current	101		102
	Other regulatory assets, deferred	420		520
Georgia Power
Fuel Cost Recovery(*)	Receivables – under recovered fuel clause revenues	$	447	$	—
	Deferred under recovered fuel clause revenues	1,702		2,056
Mississippi Power
Fuel Cost Recovery	Receivables – customer accounts, net	$	25	$	1
Ad Valorem Tax	Other regulatory assets, current	9		12
	Other regulatory assets, deferred	19		19
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	—	$	108
	Natural gas cost over recovery	117		—

(*)See "Georgia Power – Fuel Cost Recovery" herein for additional information.

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 second quarter 2023 and the first quarter 2024, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,553
Construction contingency estimate	40
Total project capital cost forecast(a)(b)	10,593
Net investment at March 31, 2023(b)	(9,747)
Remaining estimate to complete	$	846

(a)Includes approximately $610 million of costs that are not shared with the other Vogtle Owners, including $33 million of construction monitoring costs approved for recovery by the Georgia PSC in its nineteenth VCM order, and approximately $407 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 $418 million, of which $334 million had been accrued through March 31, 2023.

(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

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first three months of 2023 were as follows:

Utility	Program	Three Months Ended March 31, 2023
		(in millions)
Nicor Gas	Investing in Illinois	$	62
Virginia Natural Gas	SAVE	20
Atlanta Gas Light	System Reinforcement Rider	32
Chattanooga Gas	Pipeline Replacement Program	1
Total		$	115

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Revenue from Contracts with Customers and Lease Income (Tables)

3 Months Ended

Mar. 31, 2023

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue

The following table disaggregates revenue from contracts with customers for the three months ended March 31, 2023 and 2022:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2023
Operating revenues
Retail electric revenues
Residential	$	1,525	$	659	$	801	$	65	$	—	$	—
Commercial	1,251		430		753		68		—		—
Industrial	789		398		313		78		—		—
Other	27		3		22		2		—		—
Total retail electric revenues	3,592		1,490		1,889		213		—		—
Natural gas distribution revenues
Residential	896		—		—		—		—		896
Commercial	232		—		—		—		—		232
Transportation	319		—		—		—		—		319
Industrial	23		—		—		—		—		23
Other	117		—		—		—		—		117
Total natural gas distribution revenues	1,587		—		—		—		—		1,587
Wholesale electric revenues
PPA energy revenues	284		72		12		4		202		—
PPA capacity revenues	190		60		11		32		89		—
Non-PPA revenues	36		20		3		107		103		—
Total wholesale electric revenues	510		152		26		143		394		—
Other natural gas revenues
Gas marketing services	231		—		—		—		—		231
Other natural gas revenues	11		—		—		—		—		11
Total natural gas revenues	242		—		—		—		—		242
Other revenues	310		54		132		11		11		—
Total revenue from contracts with customers	6,241		1,696		2,047		367		405		1,829
Other revenue sources(*)	239		(49)		129		23		103		46
Total operating revenues	$	6,480	$	1,647	$	2,176	$	390	$	508	$	1,875

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Operating revenues
Retail electric revenues
Residential	$	1,525	$	634	$	821	$	70	$	—	$	—
Commercial	1,178		375		738		65		—		—
Industrial	727		323		334		70		—		—
Other	26		4		20		2		—		—
Total retail electric revenues	3,456		1,336		1,913		207		—		—
Natural gas distribution revenues
Residential	1,016		—		—		—		—		1,016
Commercial	270		—		—		—		—		270
Transportation	337		—		—		—		—		337
Industrial	32		—		—		—		—		32
Other	129		—		—		—		—		129
Total natural gas distribution revenues	1,784		—		—		—		—		1,784
Wholesale electric revenues
PPA energy revenues	342		59		32		3		251		—
PPA capacity revenues	134		39		12		3		81		—
Non-PPA revenues	58		64		9		102		73		—
Total wholesale electric revenues	534		162		53		108		405		—
Other natural gas revenues
Gas marketing services	243		—		—		—		—		243
Other natural gas revenues	16		—		—		—		—		16
Total natural gas revenues	259		—		—		—		—		259
Other revenues	225		48		95		9		8		—
Total revenue from contracts with customers	6,258		1,546		2,061		324		413		2,043
Other revenue sources(*)	390		103		147		11		126		15
Total operating revenues	$	6,648	$	1,649	$	2,208	$	335	$	539	$	2,058

(*)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.

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 March 31, 2023 and December 31, 2022:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At March 31, 2023	$	2,433	$	622	$	672	$	79	$	119	$	853
At December 31, 2022	3,123		696		922		92		237		1,107
Contract Assets
At March 31, 2023	$	160	$	3	$	74	$	—	$	—	$	19
At December 31, 2022	156		2		89		—		—		—
Contract Liabilities
At March 31, 2023	$	61	$	2	$	14	$	1	$	1	$	—
At December 31, 2022	45		4		9		—		1		—

Schedule of Remaining Performance Obligations

Revenues from contracts with customers related to these performance obligations remaining at March 31, 2023 are expected to be recognized as follows:

	2023 (remaining)		2024		2025		2026		2027		Thereafter
	(in millions)
Southern Company	$	632	$	553	$	347	$	315	$	319	$	2,089
Alabama Power	17		7		6		—		—		—
Georgia Power	68		60		25		13		14		23
Southern Power	268		345		302		303		310		2,077
Southern Company Gas	15		29		—		—		—		—

Schedule of Lease Income

Lease income for the three months ended March 31, 2023 and 2022 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended March 31, 2023
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	49		18		7		1		21		9
Variable lease income	69		—		—		—		75		—
Total lease income	$	124	$	18	$	7	$	5	$	98	$	9
For the Three Months Ended March 31, 2022
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	51		20		8		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	141	$	20	$	8	$	4	$	113	$	9

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Consolidated Entities and Equity Method Investments (Tables)

3 Months Ended

Mar. 31, 2023

Regulated Operations [Abstract]

Schedule of Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at March 31, 2023 and December 31, 2022 and related earnings from those investments for the three months ended March 31, 2023 and 2022 were as follows:

Investment Balance	March 31, 2023		December 31, 2022
	(in millions)
SNG	$	1,249	$	1,243
Other	33		33
Total	$	1,282	$	1,276

Schedule of Earnings (Loss) from Equity Method Investments

	Three Months Ended March 31,
Earnings from Equity Method Investments	2023		2022
	(in millions)
SNG	$	44	$	39
Other	1		1
Total	$	45	$	40

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Financing and Leases (Tables)

3 Months Ended

Mar. 31, 2023

Debt Disclosure [Abstract]

Schedule of Credit Arrangements

At March 31, 2023, 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		225		—
Southern Power(a)	—		—		—		600		600		587		—
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	$	7,564	$	280

(a)Does not include Southern Power Company's $75 million and $100 million continuing letter of credit facilities for standby letters of credit, expiring in 2025 and 2026, respectively, of which $9 million and $16 million, respectively, was unused at March 31, 2023. In March 2023, Southern Power amended the $100 million letter of credit facility, which, among other things, extended the expiration date from 2025 to 2026 and increased the amount from $75 million. 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 under a $250 million credit arrangement expiring in 2023.

Schedule of Shares Used to Compute Diluted Earnings Per Share

Shares used to compute diluted EPS were as follows:

	Three Months Ended March 31,
	2023	2022
	(in millions)
As reported shares	1,091	1,063
Effect of stock-based compensation	7	6
Diluted shares	1,098	1,069

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Retirement Benefits (Tables)

3 Months Ended

Mar. 31, 2023

Retirement Benefits [Abstract]

Schedule of Pension Plans and Postretirement Plans

Components of the net periodic benefit costs for the three months ended March 31, 2023 and 2022 are presented in the following tables.

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2023
Pension Plans
Service cost	$	69	$	16	$	17	$	3	$	2	$	6
Interest cost	156		36		48		7		2		11
Expected return on plan assets	(307)		(74)		(96)		(14)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net (gain) loss	8		2		3		—		—		(1)
Net periodic pension income	$	(74)	$	(20)	$	(28)	$	(4)	$	—	$	(3)
Postretirement Benefits
Service cost	$	4	$	1	$	1	$	—	$	—	$	—
Interest cost	18		4		6		1		—		2
Expected return on plan assets	(21)		(8)		(7)		(1)		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net gain	(3)		(1)		(1)		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(2)	$	(4)	$	(1)	$	—	$	—	$	1

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Pension Plans
Service cost	$	103	$	25	$	26	$	4	$	2	$	9
Interest cost	102		24		31		5		2		7
Expected return on plan assets	(316)		(77)		(99)		(15)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	60		16		18		3		1		2
Net periodic pension cost (income)	$	(51)	$	(12)	$	(24)	$	(3)	$	1	$	(1)
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	10		3		4		—		—		1
Expected return on plan assets	(20)		(8)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2023

Fair Value Disclosures [Abstract]

Schedule of Assets and Liabilities Measured at Fair Value

At March 31, 2023, 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 March 31, 2023	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)	$	4	$	100	$	—	$	—	$	104
Interest rate derivatives	—		2		—		—		2
Investments in trusts:(b)(c)
Domestic equity	680		192		—		—		872
Foreign equity	138		162		—		—		300
U.S. Treasury and government agency securities	—		316		—		—		316
Municipal bonds	—		48		—		—		48
Pooled funds – fixed income	—		7		—		—		7
Corporate bonds	—		403		—		—		403
Mortgage and asset backed securities	—		90		—		—		90
Private equity	—		—		—		160		160
Cash and cash equivalents	2		—		—		—		2
Other	40		12		—		9		61
Cash equivalents	433		13		—		—		446
Other investments	9		29		8		—		46
Total	$	1,306	$	1,374	$	8	$	169	$	2,857
Liabilities:
Energy-related derivatives(a)	$	40	$	354	$	—	$	—	$	394
Interest rate derivatives	—		261		—		—		261
Foreign currency derivatives	—		218		—		—		218
Contingent consideration	—		—		12		—		12
Other	—		13		—		—		13
Total	$	40	$	846	$	12	$	—	$	898

	Fair Value Measurements Using:
At March 31, 2023	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	$	—	$	32	$	—	$	—	$	32
Nuclear decommissioning trusts:(b)
Domestic equity	404		185		—		—		589
Foreign equity	138		—		—		—		138
U.S. Treasury and government agency securities	—		19		—		—		19
Municipal bonds	—		1		—		—		1
Corporate bonds	—		223		—		—		223
Mortgage and asset backed securities	—		22		—		—		22
Private equity	—		—		—		160		160
Other	7		—		—		9		16
Cash equivalents	193		13		—		—		206
Other investments	—		29		—		—		29
Total	$	742	$	524	$	—	$	169	$	1,435
Liabilities:
Energy-related derivatives	$	—	$	96	$	—	$	—	$	96
Georgia Power
Assets:
Energy-related derivatives	$	—	$	22	$	—	$	—	$	22
Nuclear decommissioning trusts:(b)(c)
Domestic equity	276		1		—		—		277
Foreign equity	—		161		—		—		161
U.S. Treasury and government agency securities	—		297		—		—		297
Municipal bonds	—		47		—		—		47
Corporate bonds	—		180		—		—		180
Mortgage and asset backed securities	—		68		—		—		68
Other	33		12		—		—		45
Total	$	309	$	788	$	—	$	—	$	1,097
Liabilities:
Energy-related derivatives	$	—	$	132	$	—	$	—	$	132
Interest rate derivatives	—		1		—		—		1
Total	$	—	$	133	$	—	$	—	$	133

	Fair Value Measurements Using:
At March 31, 2023	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	$	—	$	35	$	—	$	—	$	35
Cash equivalents	3		—		—		—		3
Total	$	3	$	35	$	—	$	—	$	38
Liabilities:
Energy-related derivatives	$	—	$	62	$	—	$	—	$	62
Southern Power
Assets:
Energy-related derivatives	$	—	$	5	$	—	$	—	$	5
Cash equivalents	13		—		—		—		13
Total	$	13	$	5	$	—	$	—	$	18
Liabilities:
Energy-related derivatives	$	—	$	14	$	—	$	—	$	14
Foreign currency derivatives	—		47		—		—		47
Contingent consideration	—		—		12		—		12
Other	—		13		—		—		13
Total	$	—	$	74	$	12	$	—	$	86
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	4	$	6	$	—	$	—	$	10
Interest rate derivatives	—		1		—		—		1
Non-qualified deferred compensation trusts:
Domestic equity	—		6		—		—		6
Foreign equity	—		1		—		—		1
Pooled funds – fixed income	—		7		—		—		7
Cash equivalents	2		—		—		—		2
Cash equivalents and restricted cash	55		—		—		—		55
Total	$	61	$	21	$	—	$	—	$	82
Liabilities:
Energy-related derivatives(a)	$	40	$	50	$	—	$	—	$	90
Interest rate derivatives	—		72		—		—		72
Total	$	40	$	122	$	—	$	—	$	162

(a)Excludes cash collateral of $60 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 March 31, 2023, approximately $37 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 months ended March 31, 2023 and 2022. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

	Three Months Ended
Fair value increases (decreases)	March 31, 2023		March 31, 2022
	(in millions)
Southern Company	$	102	$	(150)
Alabama Power	45		(67)
Georgia Power	57		(83)

Schedule of Financial Instruments for which Carrying Amount Did Not Equal Fair Value

At March 31, 2023, 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	$	56.1	$	10.6	$	14.9	$	1.5	$	3.0	$	7.5
Fair value	51.6		9.5		13.7		1.3		2.9		6.7

(*)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)

3 Months Ended

Mar. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Energy-Related Derivatives

At March 31, 2023, 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(*)	437	2030	2028
Alabama Power	111	2026	2023
Georgia Power	122	2026	2023
Mississippi Power	86	2027	2023
Southern Power	11	2030	2023
Southern Company Gas(*)	107	2028	2028

(*)Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 113.6 million mmBtu and short natural gas positions of 6.6 million mmBtu at March 31, 2023, which is also included in Southern Company's total volume.

Schedule of Interest Rate Derivatives

At March 31, 2023, the following interest rate derivatives were outstanding:

	Notional Amount		Weighted Average Interest Rate Paid	Interest Rate Received	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2023
	(in millions)					(in millions)
Cash Flow Hedges of Forecasted Debt
Georgia Power	$	750	3.63%	N/A	February 2033	$	(1)
Southern Company parent	500		3.47%	N/A	June 2033	—
Southern Company Gas	250		3.40%	N/A	August 2033	1
Fair Value Hedges of Existing Debt
Southern Company parent	400		1-month LIBOR + 0.68%	1.75%	March 2028	(45)
Southern Company parent	1,000		1-month LIBOR + 2.36%	3.70%	April 2030	(142)
Southern Company Gas	500		1-month LIBOR + 0.38%	1.75%	January 2031	(71)
Southern Company	$	3,400				$	(258)

Schedule of Foreign Currency Derivatives

At March 31, 2023, the following foreign currency derivatives were outstanding:

	Pay Notional		Pay Rate	Receive Notional		Receive Rate	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2023
	(in millions)			(in millions)				(in millions)
Cash Flow Hedges of Existing Debt
Southern Power	$	564	3.78%	€	500	1.85%	June 2026	$	(47)
Fair Value Hedges of Existing Debt
Southern Company parent	1,476		3.39%	1,250		1.88%	September 2027	(171)
Southern Company	$	2,040		€	1,750			$	(218)

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 March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Liabilities from risk management activities	$	41	$	230	$	123	$	121
Other deferred charges and assets/Other deferred credits and liabilities	53		113		52		44
Total derivatives designated as hedging instruments for regulatory purposes	94		343		175		165
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities	—		38		3		27
Other deferred charges and assets/Other deferred credits and liabilities	4		4		6		4
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities	2		71		12		62
Other deferred charges and assets/Other deferred credits and liabilities	—		191		—		240
Foreign currency derivatives:
Assets from risk management activities/Liabilities from risk management activities	—		35		—		34
Other deferred charges and assets/Other deferred credits and liabilities	—		183		—		182
Total derivatives designated as hedging instruments in cash flow and fair value hedges	6		522		21		549
Energy-related derivatives not designated as hedging instruments
Assets from risk management activities/Liabilities from risk management activities	4		8		13		13
Other deferred charges and assets/Other deferred credits and liabilities	2		1		2		1
Total derivatives not designated as hedging instruments	6		9		15		14
Gross amounts recognized	106		874		211		728
Gross amounts offset(a)	(57)		(118)		(70)		(111)
Net amounts recognized in the Balance Sheets(b)	$	49	$	756	$	141	$	617

	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power(c)
Energy-related derivatives designated as hedging instruments for regulatory purposes
Other current assets/Other current liabilities	$	14	$	54	$	42	$	21
Other deferred charges and assets/Other deferred credits and liabilities	18		42		20		18
Total derivatives designated as hedging instruments for regulatory purposes	32		96		62		39
Gross amounts offset	(28)		(28)		(24)		(24)
Net amounts recognized in the Balance Sheets	$	4	$	68	$	38	$	15
Georgia Power
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Other current liabilities	$	10	$	86	$	36	$	43
Other deferred charges and assets/Other deferred credits and liabilities	11		45		6		18
Total derivatives designated as hedging instruments for regulatory purposes	21		131		42		61
Interest rate derivatives designated as hedging instruments in cash flow and fair value hedges
Assets from risk management activities/Other current liabilities	—		1		—		—
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	1		1		—		1
Gross amounts recognized	22		133		42		62
Gross amounts offset	(19)		(19)		(21)		(21)
Net amounts recognized in the Balance Sheets	$	3	$	114	$	21	$	41
Mississippi Power(c)
Energy-related derivatives designated as hedging instruments for regulatory purposes
Assets from risk management activities/Other current liabilities	$	11	$	37	$	33	$	24
Other deferred charges and assets/Other deferred credits and liabilities	24		25		26		8
Total derivatives designated as hedging instruments for regulatory purposes	35		62		59		32
Gross amounts offset	(25)		(25)		(17)		(17)
Net amounts recognized in the Balance Sheets	$	10	$	37	$	42	$	15

	At March 31, 2023				At December 31, 2022
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	$	—	$	12	$	—	$	12
Other deferred charges and assets/Other deferred credits and liabilities	4		—		5		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		11		—		11
Other deferred charges and assets/Other deferred credits and liabilities	—		36		—		36
Total derivatives designated as hedging instruments in cash flow and fair value hedges	4		59		5		59
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	—		2		2		—
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	1		2		3		—
Gross amounts recognized	5		61		8		59
Net amounts recognized in the Balance Sheets	$	5	$	61	$	8	$	59

	At March 31, 2023				At December 31, 2022
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Energy-related derivatives designated as hedging instruments for regulatory purposes
Other current assets/Other current liabilities	$	6	$	53	$	12	$	33
Other deferred charges and assets/Other deferred credits and liabilities	—		1		—		—
Total derivatives designated as hedging instruments for regulatory purposes	6		54		12		33
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	—		26		3		15
Other deferred charges and assets/Other deferred credits and liabilities	—		4		1		4
Interest rate derivatives:
Other current assets/Other current liabilities	1		19		—		14
Other deferred charges and assets/Other deferred credits and liabilities	—		53		—		72
Total derivatives designated as hedging instruments in cash flow and fair value hedges	1		102		4		105
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities	3		5		11		12
Other deferred charges and assets/Other deferred credits and liabilities	1		1		1		1
Total derivatives not designated as hedging instruments	4		6		12		13
Gross amounts recognized	11		162		28		151
Gross amounts offset(a)	18		(43)		—		(41)
Net amounts recognized in the Balance Sheets(b)	$	29	$	119	$	28	$	110

(a)Gross amounts offset includes cash collateral held on deposit in broker margin accounts of $60 million and $41 million at March 31, 2023 and December 31, 2022, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for both periods presented.

(c)Energy-related derivatives not designated as hedging instruments were immaterial for Alabama Power and Mississippi Power for both periods presented.

Schedule of Pre-tax Effects of Unrealized Derivative Gains (Losses)

At March 31, 2023 and December 31, 2022, 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 March 31, 2023:
Energy-related derivatives:
Other regulatory assets, current	$	(198)	$	(44)	$	(78)	$	(29)	$	(47)
Other regulatory assets, deferred	(67)		(24)		(35)		(8)		—
Other regulatory liabilities, current	19		3		2		3		11
Other regulatory liabilities, deferred	9		1		1		7		—
Total energy-related derivative gains (losses)	$	(237)	$	(64)	$	(110)	$	(27)	$	(36)
At December 31, 2022:
Energy-related derivatives:
Other regulatory assets, current	$	(71)	$	(8)	$	(26)	$	(13)	$	(24)
Other regulatory assets, deferred	(23)		(7)		(14)		(2)		—
Other regulatory liabilities, current	72		29		19		22		2
Other regulatory liabilities, deferred	31		9		2		20		—
Total energy-related derivative gains (losses)	$	9	$	23	$	(19)	$	27	$	(22)

Schedule of Pre-Tax Effects of Hedging on AOCI

For the three months ended March 31, 2023 and 2022, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI for the applicable Registrants were as follows:

Gain (Loss) Recognized in OCI on Derivatives	For the Three Months Ended March 31,
	2023		2022
	(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	(45)	$	42
Interest rate derivatives	(13)		9
Foreign currency derivatives	—		(28)
Fair value hedges(*):
Foreign currency derivatives	(28)		4
Total	$	(86)	$	27
Georgia Power
Cash flow hedges:
Interest rate derivatives	$	(1)	$	12
Southern Power
Cash flow hedges:
Energy-related derivatives	$	(11)	$	5
Foreign currency derivatives	—		(28)
Total	$	(11)	$	(23)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	(34)	$	37
Interest rate derivatives	1		—
Total	$	(33)	$	37

(*)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 months ended March 31, 2023 and 2022, 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 March 31,
	2023		2022
	(in millions)
Southern Company
Total cost of natural gas	$	898	$	1,095
Gain (loss) on energy-related cash flow hedges(a)	(20)		9
Total depreciation and amortization	1,111		892
Gain (loss) on energy-related cash flow hedges(a)	(9)		2
Total interest expense, net of amounts capitalized	(582)		(462)
Gain (loss) on interest rate cash flow hedges(a)	(4)		(7)
Gain (loss) on foreign currency cash flow hedges(a)	(3)		(6)
Gain (loss) on interest rate fair value hedges(b)	43		(123)
Total other income (expense), net	147		145
Gain (loss) on foreign currency cash flow hedges(a)(c)	10		(25)
Gain (loss) on foreign currency fair value hedges	(2)		(24)
Amount excluded from effectiveness testing recognized in earnings	28		(4)
Southern Power
Total depreciation and amortization	$	128	$	120
Gain (loss) on energy-related cash flow hedges(a)	(9)		2
Total interest expense, net of amounts capitalized	(33)		(37)
Gain (loss) on foreign currency cash flow hedges(a)	(3)		(6)
Total other income (expense), net	2		2
Gain (loss) on foreign currency cash flow hedges(a)(c)	10		(25)
Southern Company Gas
Total cost of natural gas	$	898	$	1,095
Gain (loss) on energy-related cash flow hedges(a)	(20)		9
Total interest expense, net of amounts capitalized	(76)		(61)
Gain (loss) on interest rate cash flow hedges(a)	(1)		(1)
Gain (loss) on interest rate fair value hedges(b)	13		(36)

(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 March 31, 2023 and December 31, 2022, 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 March 31, 2023		At December 31, 2022		At March 31, 2023		At December 31, 2022
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(3,007)	$	(2,927)	$	228	$	282
Southern Company Gas
Long-term debt	$	(428)	$	(415)	$	69	$	81

Schedule of Pre-tax Effect of Interest Rate and Energy Related Derivatives on Income

For the three months ended March 31, 2023 and 2022, 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 March 31,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location		2023		2022
			(in millions)
Energy-related derivatives:	Natural gas revenues(*)		$	—	$	2
	Cost of natural gas		13		21
Total derivatives in non-designated hedging relationships			$	13	$	23

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

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Segment and Related Information (Tables)

3 Months Ended

Mar. 31, 2023

Segment Reporting [Abstract]

Schedule of Financial Data for Business Segments

Financial data for business segments and products and services for the three months ended March 31, 2023 and 2022 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 March 31, 2023
Operating revenues	$	4,113	$	508	$	(138)	$	4,483	$	1,875	$	166	$	(44)	$	6,480
Segment net income (loss)(a)(b)	610		102		—		712		309		(154)		(5)		862
At March 31, 2023
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	144	$	—	$	5,161
Total assets	96,223		13,134		(575)		108,782		24,222		2,606		(854)		134,756
Three Months Ended March 31, 2022
Operating revenues	$	4,191	$	539	$	(221)	$	4,509	$	2,058	$	123	$	(42)	$	6,648
Segment net income (loss)(a)	774		72		—		846		319		(125)		(8)		1,032
At December 31, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	144	$	—	$	5,161
Total assets	95,861		13,081		(659)		108,283		24,621		2,665		(678)		134,891

(a)Attributable to Southern Company.

(b)For Southern Power, includes a $16 million pre-tax gain ($12 million after tax) on the sale of spare parts.

Business segment financial data for the three months ended March 31, 2023 and 2022 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2023
Operating revenues	$	1,618	$	8	$	246	$	1,872	$	12	$	(9)	$	1,875
Segment net income	221		31		50		302		7		—		309
Total assets at March 31, 2023	22,223		1,583		1,596		25,402		9,598		(10,778)		24,222
Three Months Ended March 31, 2022
Operating revenues	$	1,803	$	8	$	243	$	2,054	$	16	$	(12)	$	2,058
Segment net income	214		29		66		309		10		—		319
Total assets at December 31, 2022	22,040		1,577		1,616		25,233		8,943		(9,555)		24,621

Schedule of Financial Data for Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2023	$	3,599	$	599	$	285	$	4,483
Three Months Ended March 31, 2022	3,613		664		232		4,509

	Southern Company Gas' Revenues
	Gas Distribution Operations		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended March 31, 2023	$	1,610	$	246	$	19	$	1,875
Three Months Ended March 31, 2022	1,791		243		24		2,058

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Introduction - Schedule of Goodwill (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Goodwill [Line Items]
Goodwill	$ 5,161	$ 5,161
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	Mar. 31, 2023	Dec. 31, 2022
Subject to amortization:
Gross Carrying Amount	$ 672	$ 671
Accumulated Amortization	(350)	(340)
Other Intangible Assets, Net	322	331
Not subject to amortization:
FCC licenses	75	75
Total other intangible assets
Gross Carrying Amount	747	746
Accumulated Amortization	(350)	(340)
Other Intangible Assets, Net	397	406
Customer relationships
Subject to amortization:
Gross Carrying Amount	212	212
Accumulated Amortization	(164)	(162)
Other Intangible Assets, Net	48	50
Total other intangible assets
Accumulated Amortization	(164)	(162)
Trade names
Subject to amortization:
Gross Carrying Amount	64	64
Accumulated Amortization	(47)	(44)
Other Intangible Assets, Net	17	20
Total other intangible assets
Accumulated Amortization	(47)	(44)
PPA fair value adjustments
Subject to amortization:
Gross Carrying Amount	390	390
Accumulated Amortization	(134)	(129)
Other Intangible Assets, Net	256	261
Total other intangible assets
Accumulated Amortization	(134)	(129)
Other
Subject to amortization:
Gross Carrying Amount	6	5
Accumulated Amortization	(5)	(5)
Other Intangible Assets, Net	1	0
Total other intangible assets
Accumulated Amortization	(5)	(5)
SOUTHERN POWER CO
Subject to amortization:
Accumulated Amortization	(134)	(129)
Total other intangible assets
Accumulated Amortization	(134)	(129)
SOUTHERN POWER CO | PPA fair value adjustments
Subject to amortization:
Gross Carrying Amount	390	390
Accumulated Amortization	(134)	(129)
Other Intangible Assets, Net	256	261
Total other intangible assets
Accumulated Amortization	(134)	(129)
SOUTHERN Co GAS
Subject to amortization:
Gross Carrying Amount	182	182
Accumulated Amortization	(159)	(156)
Other Intangible Assets, Net	23	26
Total other intangible assets
Accumulated Amortization	(159)	(156)
Other Intangible Assets, Net	23	26
SOUTHERN Co GAS | Customer relationships
Subject to amortization:
Gross Carrying Amount	156	156
Accumulated Amortization	(140)	(139)
Other Intangible Assets, Net	16	17
Total other intangible assets
Accumulated Amortization	(140)	(139)
SOUTHERN Co GAS | Trade names
Subject to amortization:
Gross Carrying Amount	26	26
Accumulated Amortization	(19)	(17)
Other Intangible Assets, Net	7	9
Total other intangible assets
Accumulated Amortization	$ (19)	$ (17)

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Introduction - Schedule of Amortization of Other Intangible Assets (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 10	$ 10
Decrease in operating revenues	5	5
SOUTHERN POWER CO
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	5	5
SOUTHERN Co GAS
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 3	$ 3

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Introduction - Schedule of Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	$ 1,053	$ 1,917
Restricted cash:
Total cash, cash equivalents, and restricted cash	1,217	2,037	$ 1,673	$ 1,829
Other current assets
Restricted cash:
Restricted cash	117	62
Other deferred charges and assets
Restricted cash:
Restricted cash	47	58
GEORGIA POWER CO
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	0	364
Restricted cash:
Total cash, cash equivalents, and restricted cash	160	480	26	33
GEORGIA POWER CO | Other current assets
Restricted cash:
Restricted cash	115	60
GEORGIA POWER CO | Other deferred charges and assets
Restricted cash:
Restricted cash	45	56
GEORGIA POWER CO | Proceeds From Issuance Of Solid Waste Disposal Facility Revenue Bonds
Restricted cash:
Restricted cash	116	116
GEORGIA POWER CO | Funds From Georgia Housing And Finance Authority
Restricted cash:
Restricted cash	44
SOUTHERN POWER CO
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	123	131
Restricted cash:
Total cash, cash equivalents, and restricted cash	126	133	139	135
SOUTHERN POWER CO | Other current assets
Restricted cash:
Restricted cash	0	0
SOUTHERN POWER CO | Other deferred charges and assets
Restricted cash:
Restricted cash	3	3
SOUTHERN POWER CO | Estimated Construction Completion Costs | Deuel Harvest
Restricted cash:
Restricted cash	3	3
SOUTHERN Co GAS
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	88	81
Restricted cash:
Total cash, cash equivalents, and restricted cash	89	83	$ 33	$ 48
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 - Storm Damage Reserves (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($)
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Balance at December 31, 2022	$ 216
Balance at March 31, 2023	186
Accrued Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Accrual	13
Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Weather-related damages	(43)
ALABAMA POWER CO
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Balance at December 31, 2022	97
Balance at March 31, 2023	88
ALABAMA POWER CO | Accrued Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Accrual	3
ALABAMA POWER CO | Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Weather-related damages	(12)
GEORGIA POWER CO
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Balance at December 31, 2022	83
Balance at March 31, 2023	60
GEORGIA POWER CO | Accrued Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Accrual	8
GEORGIA POWER CO | Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Weather-related damages	(31)
MISSISSIPPI POWER CO
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Balance at December 31, 2022	36
Balance at March 31, 2023	38
MISSISSIPPI POWER CO | Accrued Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Accrual	2
MISSISSIPPI POWER CO | Storm Reserve
Liability for Unpaid Claims and Claims Adjustment Expense [Roll Forward]
Weather-related damages	$ 0

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Introduction - Asset Retirement Obligations (Details) $ in Millions	Mar. 06, 2023 USD ($)
Plant Vogtle Unit 3
Schedule of Asset Retirement Obligation [Line Items]
Asset retirement obligations	$ 90

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Regulatory Matters - Schedule of Cost Recovery Clauses (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Loss Contingencies [Line Items]
Natural gas cost under recovery	$ 0	$ 108
ALABAMA POWER CO | Other regulatory assets, current
Loss Contingencies [Line Items]
Rate CNP Compliance	23	47
Rate CNP PPA	17	18
Retail Energy Cost Recovery	101	102
ALABAMA POWER CO | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Rate CNP Compliance	18	0
Rate CNP PPA	100	102
Retail Energy Cost Recovery	420	520
GEORGIA POWER CO | Receivables – under recovered fuel clause revenues
Loss Contingencies [Line Items]
Fuel Cost Recovery(*)	447	0
GEORGIA POWER CO | Deferred under recovered fuel clause revenues
Loss Contingencies [Line Items]
Fuel Cost Recovery(*)	1,702	2,056
MISSISSIPPI POWER CO | Other regulatory assets, current
Loss Contingencies [Line Items]
Ad Valorem Tax	9	12
MISSISSIPPI POWER CO | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Ad Valorem Tax	19	19
MISSISSIPPI POWER CO | Receivables – customer accounts, net
Loss Contingencies [Line Items]
Fuel Cost Recovery(*)	25	1
SOUTHERN Co GAS
Loss Contingencies [Line Items]
Natural gas cost under recovery	0	108
SOUTHERN Co GAS | Other regulatory assets, current
Loss Contingencies [Line Items]
Natural gas cost under recovery	0	108
SOUTHERN Co GAS | Natural gas cost over recovery
Loss Contingencies [Line Items]
Natural gas cost under recovery	$ 117	$ 0

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Regulatory Matters - APC Certificate of Convenience and Necessity (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022	Dec. 31, 2020
Public Utilities, General Disclosures [Line Items]
Construction work in progress	$ 11,510	$ 10,896
Plant in service, net of depreciation	82,700	82,232
ALABAMA POWER CO
Public Utilities, General Disclosures [Line Items]
Construction work in progress	1,510	1,526
Plant in service, net of depreciation	23,139	$ 23,002
ALABAMA POWER CO | Plant Barry Unit 8
Public Utilities, General Disclosures [Line Items]
Estimated in-service cost			$ 652
Construction work in progress	541
Construction in progress, work in progress amount	536
Plant in service, net of depreciation	$ 5

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Regulatory Matters - APC Rate CNP New Plant (Details) $ in Millions	Mar. 24, 2023 USD ($)
ALABAMA POWER CO
Public Utilities, General Disclosures [Line Items]
Requested rate increase (decrease) amount	$ 78

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Regulatory Matters - APC Renewable Generation Certificate (Details)	Apr. 04, 2023 claim MW	Mar. 31, 2023 MW
Subsequent Event
Public Utilities, General Disclosures [Line Items]
Renewable generation certificate, number of new solar power purchase agreements | claim	2
ALABAMA POWER CO
Public Utilities, General Disclosures [Line Items]
Renewable generation certificate, authorized generating capacity (in MWs)		500
ALABAMA POWER CO | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Renewable generation certificate, additional generating capacity procured (in MWs)	160
Renewable generation certificate, generating capacity (in MWs)	490

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Regulatory Matters - GPC Fuel Cost Recovery (Details) $ in Billions	Feb. 28, 2023 USD ($)
Public Utilities, General Disclosures [Line Items]
Under recovered fuel balance to be recovered	$ 2.2
GEORGIA POWER CO
Public Utilities, General Disclosures [Line Items]
Under recovered fuel balance to be recovered, period of recovery	3 years
Requested revenues increase (decrease) percentage	54.00%
Requested rate increase (decrease) amount	$ 1.1

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Regulatory Matters - GPC Integrated Resource Plan (Details) $ in Millions	1 Months Ended
	Aug. 31, 2022 USD ($)
GEORGIA POWER CO | Plant Tugalo
Public Utilities, General Disclosures [Line Items]
Planned expenses to modernize plant	$ 115

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Regulatory Matters - GPC Nuclear Construction (Details) - GEORGIA POWER CO - Plant Vogtle Units 3 And 4 $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2023 USD ($)	Dec. 31, 2012 utility MW	Aug. 31, 2018
Loss Contingencies [Line Items]
Proportionate ownership share	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	$ 3,500
Estimated cost to complete, construction contingency estimate, financing costs, incurred to date	3,300
Construction contingency estimate	20
Base project capital cost forecast, monthly	15
Monthly AFUDC	$ 35
Percentage of ownership interest required for voting for continuing construction			90.00%
Vogtle Owners
Loss Contingencies [Line Items]
Period of notice required in the event letters of credit are not renewed	30 days
Minimum | COVID-19
Loss Contingencies [Line Items]
Loss contingency, estimate of possible loss, loss of productivity, term	3 months
Estimate of possible loss	$ 160
Maximum | COVID-19
Loss Contingencies [Line Items]
Loss contingency, estimate of possible loss, loss of productivity, term	4 months
Estimate of possible loss	$ 200

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Regulatory Matters - GPC Nuclear Construction Cost and Schedule (Details) - GEORGIA POWER CO - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Dec. 31, 2022
Loss Contingencies [Line Items]
Pre-tax charge to income		$ 407
Plant Vogtle Units 3 And 4
Loss Contingencies [Line Items]
Base project capital cost forecast	$ 10,553
Construction contingency estimate	40
Total project capital cost forecast	10,593
Net investment as of end of the period	(9,747)
Remaining estimate to complete	846
Estimated cost to complete, costs not shared with other owners	610
Estimated cost to complete, construction monitoring costs approved for recovery	33
Expected capitalized costs	418
Capitalized interest accrued	334
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) - USD ($) $ in Thousands		1 Months Ended	3 Months Ended
	Jan. 11, 2018	Sep. 30, 2022	Mar. 31, 2023	Dec. 31, 2022	Jul. 31, 2022	Jun. 30, 2022	Aug. 31, 2018
Public Utilities, General Disclosures [Line Items]
Agreement with third party, amount of costs over projected forecast to be paid by company		20.00%
GEORGIA POWER CO
Public Utilities, General Disclosures [Line Items]
Pre-tax charge to income				$ 407,000
After tax charge to income				304,000
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO
Public Utilities, General Disclosures [Line Items]
Production tax credits, aggregate purchase price, maximum			$ 300,000
Preliminary estimated cost to complete			$ 10,593,000
Additional construction capital costs	$ 3,300,000			$ 345,000
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
Estimated cost to complete, starting dollar amount					$ 18,380,000
Proportionate ownership share			45.70%
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO | Vogtle Owners
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs			$ 100
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO | 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 | GEORGIA POWER CO | MEAG Power
Public Utilities, General Disclosures [Line Items]
Payment of power costs		$ 92,000
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO | Category I
Public Utilities, General Disclosures [Line Items]
Preliminary estimated cost to complete			8,400,000
Additional construction capital costs, threshold			$ 800,000
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO | 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 | GEORGIA POWER CO | 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 | GEORGIA POWER CO | Category II | Minimum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold			$ 800,000
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO | Category II | Maximum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold			$ 1,600,000
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO | 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 | GEORGIA POWER CO | 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 | GEORGIA POWER CO | Category III | Minimum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold			$ 1,600,000
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO | 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							3 Months Ended		6 Months Ended	12 Months Ended
	Feb. 16, 2023 USD ($)	Jan. 01, 2023 USD ($)	Jan. 01, 2021	Jan. 01, 2020	Jan. 11, 2018 USD ($)	Jan. 01, 2016	Mar. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Jun. 30, 2022 USD ($) report	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2009 USD ($)	Dec. 31, 2021 USD ($)	Jun. 30, 2021 report	Jun. 30, 2018 USD ($)	Dec. 31, 2013
Public Utilities, General Disclosures [Line Items]
Estimated in-service capital cost													$ 4,418
Financing costs collected, net of tax							$ 2,900
Requested decrease in tariff		$ 36
Additional construction capital costs					$ 3,300			$ 345
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												$ 300
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
Number of additional reports reviewed | report									2
Twenty Sixth Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Requested capital construction costs									$ 1,100
Twenty Seventh Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Requested capital construction costs	$ 461
Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Return on equity reduction, negative impact on earnings										$ 60	$ 270

XML

Regulatory Matters - MPC (Details) - USD ($) $ in Millions	Apr. 04, 2023	Apr. 03, 2023	Mar. 31, 2023
Subsequent Event
Loss Contingencies [Line Items]
Minimum annual accrual, amount		$ 8
MISSISSIPPI POWER CO | Subsequent Event
Loss Contingencies [Line Items]
Approved rate increase (decrease)	$ 12
MISSISSIPPI POWER CO | Ad Valorem Tax Adjustment
Loss Contingencies [Line Items]
Requested rate increase (decrease) amount			$ 7
MISSISSIPPI POWER CO | ECO Plan | Subsequent Event
Loss Contingencies [Line Items]
Approved rate increase (decrease)	$ 3

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Regulatory Matters - GAS Schedule of Infrastructure Replacement Programs and Capital Projects (Details) - SOUTHERN Co GAS $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($)
Public Utilities, General Disclosures [Line Items]
Capital expenditures	$ 115
Investing in Illinois
Public Utilities, General Disclosures [Line Items]
Capital expenditures	62
SAVE
Public Utilities, General Disclosures [Line Items]
Capital expenditures	20
System Reinforcement Rider
Public Utilities, General Disclosures [Line Items]
Capital expenditures	32
Pipeline Replacement Program
Public Utilities, General Disclosures [Line Items]
Capital expenditures	$ 1

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Contingencies - General Litigation Matters (Details) - Pending Litigation $ in Millions	1 Months Ended	5 Months Ended	6 Months Ended
	Mar. 31, 2019 plaintiff	Feb. 28, 2022 claim	Jun. 30, 2019 USD ($) defendant plaintiff
GEORGIA POWER CO | Class Action Lawsuit
Loss Contingencies [Line Items]
Complaints filed | claim		7
MISSISSIPPI POWER CO | Purported Violations of Mississippi Consumer Protection Act
Loss Contingencies [Line Items]
Number of plaintiffs			10
Number of defendants | defendant			3
Number of additional plaintiffs	4
Underpayment of refunds | $			$ 23.5

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Contingencies - Environmental Remediation (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
GEORGIA POWER CO
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 15	$ 15
SOUTHERN Co GAS
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 243	$ 256

XML

Contingencies - Other Matters (Details) - USD ($) $ in Millions	1 Months Ended
	Aug. 31, 2022	Apr. 30, 2019
Loss Contingencies [Line Items]
Estimated additional interest expense	$ 1
ALABAMA POWER CO | AT&T
Loss Contingencies [Line Items]
Potential refund amount owed		$ 87
Refund payment period		6 years
MISSISSIPPI POWER CO
Loss Contingencies [Line Items]
Estimate of possible loss	$ 28

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Revenue from Contracts with Customers and Lease Income - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 6,241	$ 6,258
Total operating revenues	6,480	6,648
Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	3,599	3,613
Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3,592	3,456
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,525	1,525
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,251	1,178
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	789	727
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	27	26
Natural Gas
Disaggregation of Revenue [Line Items]
Total operating revenues	1,875	2,058
Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,587	1,784
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	896	1,016
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	232	270
Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	319	337
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	23	32
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	117	129
Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	242	259
Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	231	243
Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	11	16
Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	239	390
Wholesale Electric
Disaggregation of Revenue [Line Items]
Total operating revenues	599	664
Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	510	534
PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	284	342
PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	190	134
Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	36	58
Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	310	225
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,696	1,546
Total operating revenues	1,647	1,649
ALABAMA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,381	1,379
ALABAMA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,490	1,336
ALABAMA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	659	634
ALABAMA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	430	375
ALABAMA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	398	323
ALABAMA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3	4
ALABAMA POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Other natural gas revenues
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
ALABAMA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	(49)	103
ALABAMA POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	152	162
ALABAMA POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	72	59
ALABAMA POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	60	39
ALABAMA POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	20	64
ALABAMA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	54	48
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2,047	2,061
Total operating revenues	2,176	2,208
GEORGIA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,981	2,017
GEORGIA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,889	1,913
GEORGIA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	801	821
GEORGIA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	753	738
GEORGIA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	313	334
GEORGIA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	22	20
GEORGIA POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Other natural gas revenues
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
GEORGIA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	129	147
GEORGIA POWER CO | Wholesale Electric
Disaggregation of Revenue [Line Items]
Total operating revenues	31	66
GEORGIA POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	26	53
GEORGIA POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	12	32
GEORGIA POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	11	12
GEORGIA POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3	9
GEORGIA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	132	95
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	367	324
Total operating revenues	390	335
MISSISSIPPI POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	236	217
MISSISSIPPI POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	213	207
MISSISSIPPI POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	65	70
MISSISSIPPI POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	68	65
MISSISSIPPI POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	78	70
MISSISSIPPI POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2	2
MISSISSIPPI POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Other natural gas revenues
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
MISSISSIPPI POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	23	11
MISSISSIPPI POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	143	108
MISSISSIPPI POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4	3
MISSISSIPPI POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	32	3
MISSISSIPPI POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	107	102
MISSISSIPPI POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	11	9
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	405	413
Total operating revenues	508	539
SOUTHERN POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other natural gas revenues
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
SOUTHERN POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	103	126
SOUTHERN POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	394	405
SOUTHERN POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	202	251
SOUTHERN POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	89	81
SOUTHERN POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	103	73
SOUTHERN POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	11	8
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,829	2,043
Total operating revenues	1,875	2,058
SOUTHERN Co GAS | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,587	1,784
SOUTHERN Co GAS | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	896	1,016
SOUTHERN Co GAS | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	232	270
SOUTHERN Co GAS | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	319	337
SOUTHERN Co GAS | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	23	32
SOUTHERN Co GAS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	117	129
SOUTHERN Co GAS | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	242	259
SOUTHERN Co GAS | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	231	243
SOUTHERN Co GAS | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	11	16
SOUTHERN Co GAS | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	46	15
SOUTHERN Co GAS | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 0	$ 0

XML

Revenue from Contracts with Customers and Lease Income - Schedule of Contract Balances (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Accounts Receivable	$ 2,433	$ 3,123
Contract Assets	160	156
Contract Liabilities	61	45
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	622	696
Contract Assets	3	2
Contract Liabilities	2	4
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	672	922
Contract Assets	74	89
Contract Liabilities	14	9
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	79	92
Contract Assets	0	0
Contract Liabilities	1	0
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	119	237
Contract Assets	0	0
Contract Liabilities	1	1
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Accounts Receivable	853	1,107
Contract Assets	19	0
Contract Liabilities	$ 0	$ 0

XML

Revenue from Contracts with Customers and Lease Income - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 61	$ 45
Contract assets	160	156
Revenue from contracts with customers recognized	19
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Contract liabilities	14	9
Contract assets	74	89
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Contract liabilities	0	0
Contract assets	$ 19	0
Retail Customer Fixed Bill Programs | GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Contract term	1 year
Energy Efficiency Enhancement And Upgrade | SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Contract liabilities	$ 30
Unregulated Distributed Generation
Disaggregation of Revenue [Line Items]
Contract liabilities	44	32
Contract assets	$ 64	$ 65

XML

Revenue from Contracts with Customers and Lease Income - Schedule of Remaining Performance Obligations (Details) $ in Millions	Mar. 31, 2023 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 632
Performance obligation, expected timing of satisfaction	9 months
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	$ 553
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	$ 347
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	$ 315
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	$ 319
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,089
Performance obligation, expected timing of satisfaction
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 17
Performance obligation, expected timing of satisfaction	9 months
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	$ 6
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	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
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]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 68
Performance obligation, expected timing of satisfaction	9 months
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	$ 60
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	$ 25
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	$ 13
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	$ 14
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 23
Performance obligation, expected timing of satisfaction
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 268
Performance obligation, expected timing of satisfaction	9 months
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	$ 345
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	$ 302
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	$ 303
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	$ 310
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,077
Performance obligation, expected timing of satisfaction
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 15
Performance obligation, expected timing of satisfaction	9 months
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	1 year
SOUTHERN Co GAS | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01
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
	Mar. 31, 2023	Mar. 31, 2022
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	$ 6	$ 6
Lease income - operating leases	49	51
Variable lease income	69	84
Total lease income	124	141
ALABAMA POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0
Lease income - operating leases	18	20
Variable lease income	0	0
Total lease income	18	20
GEORGIA POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0
Lease income - operating leases	7	8
Variable lease income	0	0
Total lease income	7	8
MISSISSIPPI POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	4	4
Lease income - operating leases	1	0
Variable lease income	0	0
Total lease income	5	4
SOUTHERN POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	2	2
Lease income - operating leases	21	21
Variable lease income	75	90
Total lease income	98	113
SOUTHERN Co GAS
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0
Lease income - operating leases	9	9
Variable lease income	0	0
Total lease income	$ 9	$ 9

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Consolidated Entities and Equity Method Investments - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) investor	Dec. 31, 2022 USD ($)
Schedule of Equity Method Investments [Line Items]
Equity investments in unconsolidated subsidiaries	$ 1,408	$ 1,443
Assets	134,756	134,891
Liabilities	100,194	100,359
Southern Holdings Company
Schedule of Equity Method Investments [Line Items]
Equity investments in unconsolidated subsidiaries	120	112
SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Equity investments in unconsolidated subsidiaries	0	49
Assets	13,134	13,081
Liabilities	6,276	6,165
Proceeds from sale of equity method investments	$ 50
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	$ 5,800	5,900
Liabilities	400	400
Noncontrolling interests related to other partners' interests	1,000	1,100
Variable Interest Entity, Primary Beneficiary | SP Wind | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Assets	2,200	2,200
Liabilities	172	169
Noncontrolling interests related to other partners' interests	$ 39	39
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	1,800
Liabilities	200	200
Noncontrolling interests related to other partners' interests	$ 800	$ 800

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Consolidated Entities and Equity Method Investments - Schedule of Equity Method Investments (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Investment Balance	$ 1,408	$ 1,443
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,282	1,276
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,249	1,243
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Investment Balance	$ 33	$ 33

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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
	Mar. 31, 2023	Mar. 31, 2022
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	$ 48	$ 46
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	45	40
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	44	39
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	$ 1	$ 1

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Financing and Leases - Schedule of Credit Arrangements (Details)	Mar. 31, 2023 USD ($)
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	7,564,000,000
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	225,000,000
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	587,000,000
Expires within One Year	0
SOUTHERN POWER CO | Continuing Letter of Credit Facility A
Line of Credit Facility [Line Items]
Expires, 2025	75,000,000
Expires, 2026	100,000,000
Unused	9,000,000
SOUTHERN POWER CO | Continuing Letter of Credit Facility B
Line of Credit Facility [Line Items]
Unused	16,000,000
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, 2027	800,000,000
Nicor Gas
Line of Credit Facility [Line Items]
Expires, 2027	$ 700,000,000

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Financing and Leases - Narrative (Details) $ in Millions	Mar. 31, 2023 USD ($)
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	$ 1,700
MISSISSIPPI POWER CO
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	69
ALABAMA POWER CO
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	789
Fixed rate pollution control revenue bonds outstanding	120
GEORGIA POWER CO
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	819
Fixed rate pollution control revenue bonds outstanding	$ 285

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Financing and Leases - Convertible Senior Notes (Details) - Series 2023A Convertible Senior Notes Due 2025 - Convertible Debt $ / shares in Units, $ in Millions		1 Months Ended
	Feb. 28, 2023 USD ($) $ / shares	Feb. 28, 2023 USD ($) d $ / shares	Mar. 31, 2023 USD ($)
Debt Instrument [Line Items]
Aggregate principal amount | $	$ 1,500	$ 1,500	$ 225
Interest rate	3.875%	3.875%
Conversion ratio		0.0118818
Conversion price (in dollars per share) | $ / shares	$ 84.16	$ 84.16
Redemption price	100.00%
Debt Conversion Terms One
Debt Instrument [Line Items]
Trading day threshold		20
Consecutive trading day threshold		30
Stock price trigger threshold, percentage		130.00%
Debt Conversion Terms Two
Debt Instrument [Line Items]
Trading day threshold		5
Consecutive trading day threshold		10
Stock price trigger threshold, percentage		98.00%

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Financing and Leases - Schedule of Shares Used to Compute Diluted Earnings Per Share (Details) - shares shares in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Debt Disclosure [Abstract]
As reported shares (in shares)	1,091,000	1,063,000
Effect of stock-based compensation (in shares)	7,000	6,000
Diluted (in shares)	1,098,000	1,069,000
Antidilutive securities excluded from computation of earnings per share (in shares)	0	0

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Income Taxes - Narrative (Details)	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	10.80%	14.90%
ALABAMA POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	(0.80%)	23.30%
GEORGIA POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	15.10%	7.30%
SOUTHERN POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	(20.70%)	(80.00%)

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Retirement Benefits (Details) - USD ($)	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, expected future employer contributions, remainder of fiscal year	$ 0
Pension Plans and Postretirement Plans
Service cost	69,000,000	$ 103,000,000
Interest cost	156,000,000	102,000,000
Expected return on plan assets	(307,000,000)	(316,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net gain	8,000,000	60,000,000
Net periodic pension cost (income)	(74,000,000)	(51,000,000)
Pension Plans | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	16,000,000	25,000,000
Interest cost	36,000,000	24,000,000
Expected return on plan assets	(74,000,000)	(77,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net gain	2,000,000	16,000,000
Net periodic pension cost (income)	(20,000,000)	(12,000,000)
Pension Plans | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	17,000,000	26,000,000
Interest cost	48,000,000	31,000,000
Expected return on plan assets	(96,000,000)	(99,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net gain	3,000,000	18,000,000
Net periodic pension cost (income)	(28,000,000)	(24,000,000)
Pension Plans | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	3,000,000	4,000,000
Interest cost	7,000,000	5,000,000
Expected return on plan assets	(14,000,000)	(15,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net gain	0	3,000,000
Net periodic pension cost (income)	(4,000,000)	(3,000,000)
Pension Plans | SOUTHERN POWER CO
Pension Plans and Postretirement Plans
Service cost	2,000,000	2,000,000
Interest cost	2,000,000	2,000,000
Expected return on plan assets	(4,000,000)	(4,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net gain	0	1,000,000
Net periodic pension cost (income)	0	1,000,000
Pension Plans | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	6,000,000	9,000,000
Interest cost	11,000,000	7,000,000
Expected return on plan assets	(22,000,000)	(22,000,000)
Amortization:
Prior service costs	(1,000,000)	(1,000,000)
Regulatory asset	4,000,000	4,000,000
Net gain	(1,000,000)	2,000,000
Net periodic pension cost (income)	(3,000,000)	(1,000,000)
Postretirement Benefits
Pension Plans and Postretirement Plans
Service cost	4,000,000	6,000,000
Interest cost	18,000,000	10,000,000
Expected return on plan assets	(21,000,000)	(20,000,000)
Amortization:
Regulatory asset	0	0
Net gain	(3,000,000)
Net periodic pension cost (income)	(2,000,000)	(4,000,000)
Postretirement Benefits | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	1,000,000	1,000,000
Interest cost	4,000,000	3,000,000
Expected return on plan assets	(8,000,000)	(8,000,000)
Amortization:
Regulatory asset	0	0
Net gain	(1,000,000)
Net periodic pension cost (income)	(4,000,000)	(4,000,000)
Postretirement Benefits | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	1,000,000	2,000,000
Interest cost	6,000,000	4,000,000
Expected return on plan assets	(7,000,000)	(7,000,000)
Amortization:
Regulatory asset	0	0
Net gain	(1,000,000)
Net periodic pension cost (income)	(1,000,000)	(1,000,000)
Postretirement Benefits | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	0	0
Interest cost	1,000,000	0
Expected return on plan assets	(1,000,000)	0
Amortization:
Regulatory asset	0	0
Net gain	0
Net periodic pension cost (income)	0	0
Postretirement Benefits | SOUTHERN POWER CO
Pension Plans and Postretirement Plans
Service cost	0	0
Interest cost	0	0
Expected return on plan assets	0	0
Amortization:
Regulatory asset	0	0
Net gain	0
Net periodic pension cost (income)	0	0
Postretirement Benefits | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	0	0
Interest cost	2,000,000	1,000,000
Expected return on plan assets	(2,000,000)	(2,000,000)
Amortization:
Regulatory asset	2,000,000	2,000,000
Net gain	(1,000,000)
Net periodic pension cost (income)	$ 1,000,000	$ 1,000,000

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Fair Value Measurements - Schedule of Assets and Liabilities Measured at Fair Value (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Assets:
Derivatives	$ 49	$ 141
Liabilities:
Derivatives	756	617
Other	13
Collateral already posted, assets, aggregate fair value	60
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	4	38
Liabilities:
Derivatives	68	15
Collateral already posted, assets, aggregate fair value	0
GEORGIA POWER CO
Assets:
Derivatives	3	21
Investments in trusts	37
Liabilities:
Derivatives	114	41
MISSISSIPPI POWER CO
Assets:
Derivatives	10	42
Liabilities:
Derivatives	37	15
SOUTHERN POWER CO
Assets:
Derivatives	5	8
Liabilities:
Derivatives	61	59
Other	13
Collateral already posted, assets, aggregate fair value	15
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	29	28
Liabilities:
Derivatives	119	110
Total
Collateral already posted, assets, aggregate fair value	60	$ 41
Fair Value, Measurements, Recurring
Assets:
Cash equivalents	446
Other investments	46
Total	2,857
Liabilities:
Contingent consideration	12
Total	898
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	433
Other investments	9
Total	1,306
Liabilities:
Contingent consideration	0
Total	40
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	13
Other investments	29
Total	1,374
Liabilities:
Contingent consideration	0
Total	846
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Other investments	8
Total	8
Liabilities:
Contingent consideration	12
Total	12
Fair Value, Measurements, Recurring | Net Asset Value as a Practical Expedient (NAV)
Assets:
Total	169
Fair Value, Measurements, Recurring | Energy-related derivatives
Assets:
Derivatives	104
Liabilities:
Derivatives	394
Fair Value, Measurements, Recurring | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	4
Liabilities:
Derivatives	40
Fair Value, Measurements, Recurring | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	100
Liabilities:
Derivatives	354
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
Assets:
Derivatives	2
Liabilities:
Derivatives	261
Fair Value, Measurements, Recurring | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	2
Liabilities:
Derivatives	261
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Domestic equity
Assets:
Investments in trusts	872
Fair Value, Measurements, Recurring | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	680
Fair Value, Measurements, Recurring | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	192
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	300
Fair Value, Measurements, Recurring | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	138
Fair Value, Measurements, Recurring | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	162
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	316
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	316
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	48
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	48
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	7
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	7
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	403
Fair Value, Measurements, Recurring | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	403
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	90
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	90
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	160
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	160
Fair Value, Measurements, Recurring | Cash and cash equivalents
Assets:
Investments in trusts	2
Fair Value, Measurements, Recurring | Cash and cash equivalents | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	2
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	61
Fair Value, Measurements, Recurring | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	40
Fair Value, Measurements, Recurring | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	12
Fair Value, Measurements, Recurring | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Other | Net Asset Value as a Practical Expedient (NAV)
Assets:
Investments in trusts	9
Fair Value, Measurements, Recurring | Foreign currency derivatives
Liabilities:
Derivatives	218
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	218
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	206
Other investments	29
Total	1,435
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	193
Other investments	0
Total	742
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	13
Other investments	29
Total	524
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	169
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives
Assets:
Derivatives	32
Liabilities:
Derivatives	96
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	32
Liabilities:
Derivatives	96
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	589
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	404
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	185
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	138
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	138
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	19
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	19
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	1
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	1
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	223
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	223
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	22
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	22
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	160
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	160
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other
Assets:
Investments in trusts	16
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	7
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 | ALABAMA POWER CO | Other | Net Asset Value as a Practical Expedient (NAV)
Assets:
Investments in trusts	9
Fair Value, Measurements, Recurring | GEORGIA POWER CO
Assets:
Total	1,097
Liabilities:
Total	133
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Total	309
Liabilities:
Total	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Total	788
Liabilities:
Total	133
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Total	0
Liabilities:
Total	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives
Assets:
Derivatives	22
Liabilities:
Derivatives	132
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	22
Liabilities:
Derivatives	132
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 | Interest rate derivatives
Liabilities:
Derivatives	1
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	1
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity
Assets:
Investments in trusts	277
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	276
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	161
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	161
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	297
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	297
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	47
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	47
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	180
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	180
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	68
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	68
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	45
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	33
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	12
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
Assets:
Cash equivalents	3
Total	38
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	3
Total	3
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	35
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Total	0
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives
Assets:
Derivatives	35
Liabilities:
Derivatives	62
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	35
Liabilities:
Derivatives	62
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
Assets:
Cash equivalents	13
Total	18
Liabilities:
Contingent consideration	12
Total	86
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	13
Total	13
Liabilities:
Contingent consideration	0
Total	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	5
Liabilities:
Contingent consideration	0
Total	74
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Total	0
Liabilities:
Contingent consideration	12
Total	12
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives
Assets:
Derivatives	5
Liabilities:
Derivatives	14
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	5
Liabilities:
Derivatives	14
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	47
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	47
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	55
Total	82
Liabilities:
Total	162
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	55
Total	61
Liabilities:
Total	40
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	21
Liabilities:
Total	122
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	10
Liabilities:
Derivatives	90
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	4
Liabilities:
Derivatives	40
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	6
Liabilities:
Derivatives	50
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
Assets:
Derivatives	1
Liabilities:
Derivatives	72
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	1
Liabilities:
Derivatives	72
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity
Assets:
Non-qualified deferred compensation trusts	6
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	6
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	1
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	1
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	7
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	7
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	2
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	2
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
	Mar. 31, 2023	Mar. 31, 2022
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ 102	$ (150)
ALABAMA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	45	(67)
GEORGIA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ 57	$ (83)

XML

Fair Value Measurements - Narrative (Details) - ALABAMA POWER CO - Private equity $ in Millions	Mar. 31, 2023 USD ($)
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Fair value	$ 169
Unfunded commitments	$ 75

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Fair Value Measurements - Schedule of Financial Instruments for which Carrying Amount did not Equal Fair Value (Details) $ in Millions	Mar. 31, 2023 USD ($)
Long-term debt, including securities due within one year:
Carrying amount	$ 56,100.0
Fair value	51,600.0
ALABAMA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	10,600.0
Fair value	9,500.0
GEORGIA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	14,900.0
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	7,500.0
Fair value	$ 6,700.0

XML

Derivatives - Schedule of Energy-Related Derivatives (Details) - Energy-related, Natural Gas MMBTU in Millions	Mar. 31, 2023 MMBTU
Energy-related derivative contracts
Net Purchased mmBtu	437.0
ALABAMA POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	111.0
GEORGIA POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	122.0
MISSISSIPPI POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	86.0
SOUTHERN POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	11.0
SOUTHERN Co GAS
Energy-related derivative contracts
Net Purchased mmBtu	107.0
SOUTHERN Co GAS | Energy-related derivatives not designated as hedging instruments | Long
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume	113.6
SOUTHERN Co GAS | Energy-related derivatives not designated as hedging instruments | Short
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume	6.6

XML

Derivatives - Narrative (Details) MMBTU in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) MMBTU	Dec. 31, 2022 USD ($)
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	22
Energy-related derivative hedge gain (loss) to be reclassified within twelve months	$ (42,000,000)
Collateral already posted, assets, aggregate fair value	60,000,000
Derivatives	756,000,000	$ 617,000,000
Interest rate derivatives
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	(15,000,000)
Derivatives	$ 73,000,000
SOUTHERN POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	5
Energy-related derivative hedge gain (loss) to be reclassified within twelve months	$ (12,000,000)
Foreign currency cash flow hedge gain (loss) to be reclassified during next 12 months	(11,000,000)
Collateral already posted, assets, aggregate fair value	15,000,000
Derivatives	61,000,000	59,000,000
SOUTHERN POWER CO | Interest rate derivatives
Derivative [Line Items]
Derivatives	23,000,000
SOUTHERN Co GAS
Derivative [Line Items]
Energy-related derivative hedge gain (loss) to be reclassified within twelve months	(30,000,000)
Collateral already posted, assets, aggregate fair value	60,000,000	41,000,000
Derivatives	$ 119,000,000	110,000,000
ALABAMA POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	6
Energy-related derivative hedge gain (loss) to be reclassified within twelve months	$ 0
Collateral already posted, assets, aggregate fair value	0
Derivatives	$ 68,000,000	15,000,000
GEORGIA POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	8
Energy-related derivative hedge gain (loss) to be reclassified within twelve months	$ 0
Derivatives	$ 114,000,000	41,000,000
MISSISSIPPI POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	3
Energy-related derivative hedge gain (loss) to be reclassified within twelve months	$ 0
Derivatives	37,000,000	$ 15,000,000
Registrants | Derivative Counterparties
Derivative [Line Items]
Collateral already posted, assets, aggregate fair value	$ 0

XML

Derivatives - Schedule of Interest Rate Derivatives (Details) - Interest rate derivatives $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($)
Derivative [Line Items]
Notional Amount	$ 3,400
Fair Value Gain (Loss)	(258)
GEORGIA POWER CO | Cash Flow Hedges of Forecasted Debt
Derivative [Line Items]
Notional Amount	$ 750
Weighted Average Interest Rate Paid	3.63%
Fair Value Gain (Loss)	$ (1)
Southern Company parent | Cash Flow Hedges of Forecasted Debt
Derivative [Line Items]
Notional Amount	$ 500
Weighted Average Interest Rate Paid	3.47%
Fair Value Gain (Loss)	$ 0
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)	$ (45)
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)	$ (142)
SOUTHERN Co GAS | Cash Flow Hedges of Forecasted Debt
Derivative [Line Items]
Notional Amount	$ 250
Weighted Average Interest Rate Paid	3.40%
Fair Value Gain (Loss)	$ 1
SOUTHERN Co GAS | Fair Value Hedges of Existing Debt
Derivative [Line Items]
Notional Amount	$ 500
Interest Rate Received	1.75%
Fair Value Gain (Loss)	$ (71)
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%
London Interbank Offered Rate (LIBOR) | SOUTHERN Co GAS | Fair Value Hedges of Existing Debt
Derivative [Line Items]
Weighted Average Interest Rate Paid	0.38%

XML

Derivatives - Schedule of Foreign Currency Derivatives (Details) - 3 months ended Mar. 31, 2023 - Foreign currency derivatives € in Millions, $ in Millions	USD ($)	EUR (€)
Derivative [Line Items]
Pay Notional	$ 2,040
Receive Notional | €		€ 1,750
Fair Value Gain (Loss)	(218)
Cash Flow Hedges of Forecasted Debt | SOUTHERN POWER CO
Derivative [Line Items]
Pay Notional	$ 564
Pay Rate	3.78%
Receive Notional | €		500
Receive Rate	1.85%
Fair Value Gain (Loss)	$ (47)
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)	$ (171)

XML

Derivatives - Schedule of Derivative Category and Balance Sheet Location (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	$ 106	$ 211
Derivative asset, Gross amounts offset	(57)	(70)
Derivative asset, net amounts recognized in the balance sheets	49	141
Derivative liability, gross amount recognized	874	728
Derivative liability, Gross amounts offset	(118)	(111)
Derivative liability, net amounts recognized in the balance sheets	756	617
Collateral already posted, assets, aggregate fair value	60
Interest rate derivatives
Derivatives, Fair Value [Line Items]
Derivative liability, net amounts recognized in the balance sheets	73
Energy-related derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	6	15
Derivative liability, gross amount recognized	9	14
Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	4	13
Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	8	13
Energy-related 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	2
Energy-related 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	1
Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	94	175
Derivative liability, gross amount recognized	343	165
Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	41	123
Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	230	121
Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	53	52
Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	113	44
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	6	21
Derivative liability, gross amount recognized	522	549
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	0	3
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	38	27
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	6
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	4	4
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	2	12
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	71	62
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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 | Energy-related 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	191	240
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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 | Energy-related derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	35	34
Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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 | Energy-related 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	183	182
ALABAMA POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, Gross amounts offset	(28)	(24)
Derivative asset, net amounts recognized in the balance sheets	4	38
Derivative liability, Gross amounts offset	(28)	(24)
Derivative liability, net amounts recognized in the balance sheets	68	15
Collateral already posted, assets, aggregate fair value	0
ALABAMA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	32	62
Derivative liability, gross amount recognized	96	39
ALABAMA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	14	42
ALABAMA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	54	21
ALABAMA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	18	20
ALABAMA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	42	18
GEORGIA POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	22	42
Derivative asset, Gross amounts offset	(19)	(21)
Derivative asset, net amounts recognized in the balance sheets	3	21
Derivative liability, gross amount recognized	133	62
Derivative liability, Gross amounts offset	(19)	(21)
Derivative liability, net amounts recognized in the balance sheets	114	41
GEORGIA POWER CO | Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	0
GEORGIA POWER CO | Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	1
GEORGIA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	21	42
Derivative liability, gross amount recognized	131	61
GEORGIA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	10	36
GEORGIA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	86	43
GEORGIA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	11	6
GEORGIA POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	45	18
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	0
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	0
MISSISSIPPI POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, Gross amounts offset	(25)	(17)
Derivative asset, net amounts recognized in the balance sheets	10	42
Derivative liability, Gross amounts offset	(25)	(17)
Derivative liability, net amounts recognized in the balance sheets	37	15
MISSISSIPPI POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	35	59
Derivative liability, gross amount recognized	62	32
MISSISSIPPI POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	11	33
MISSISSIPPI POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	37	24
MISSISSIPPI POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	24	26
MISSISSIPPI POWER CO | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	25	8
SOUTHERN POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	5	8
Derivative asset, net amounts recognized in the balance sheets	5	8
Derivative liability, gross amount recognized	61	59
Derivative liability, net amounts recognized in the balance sheets	61	59
Collateral already posted, assets, aggregate fair value	15
SOUTHERN POWER CO | Interest rate derivatives
Derivatives, Fair Value [Line Items]
Derivative liability, net amounts recognized in the balance sheets	23
SOUTHERN POWER CO | Energy-related derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	3
Derivative liability, gross amount recognized	2	0
SOUTHERN POWER CO | Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	2
SOUTHERN POWER CO | Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	2	0
SOUTHERN POWER CO | Energy-related 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 POWER CO | Energy-related 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 | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	4	5
Derivative liability, gross amount recognized	59	59
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	12	12
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	5
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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 | Energy-related 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 | Energy-related 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	11
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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 | Energy-related 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	36	36
SOUTHERN Co GAS
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	11	28
Derivative asset, Gross amounts offset	18	0
Derivative asset, net amounts recognized in the balance sheets	29	28
Derivative liability, gross amount recognized	162	151
Derivative liability, Gross amounts offset	(43)	(41)
Derivative liability, net amounts recognized in the balance sheets	119	110
Collateral already posted, assets, aggregate fair value	60	41
SOUTHERN Co GAS | Energy-related derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	4	12
Derivative liability, gross amount recognized	6	13
SOUTHERN Co GAS | Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	3	11
SOUTHERN Co GAS | Energy-related derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	5	12
SOUTHERN Co GAS | Energy-related 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 | Energy-related 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	1
SOUTHERN Co GAS | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	6	12
Derivative liability, gross amount recognized	54	33
SOUTHERN Co GAS | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	6	12
SOUTHERN Co GAS | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	53	33
SOUTHERN Co GAS | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	0	0
SOUTHERN Co GAS | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related 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	1	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	4
Derivative liability, gross amount recognized	102	105
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	3
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	26	15
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	0	1
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	4	4
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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	14
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Energy-related 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 | Energy-related 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	$ 53	$ 72

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Derivatives - Schedule of Pre-tax Effects of Unrealized Derivative Gains (Losses) (Details) - Energy-related derivatives - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	$ (237)	$ 9
Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(198)	(71)
Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(67)	(23)
Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	19	72
Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	9	31
ALABAMA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(64)	23
ALABAMA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(44)	(8)
ALABAMA POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(24)	(7)
ALABAMA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	3	29
ALABAMA POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	1	9
GEORGIA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(110)	(19)
GEORGIA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(78)	(26)
GEORGIA POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(35)	(14)
GEORGIA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	2	19
GEORGIA POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	1	2
MISSISSIPPI POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(27)	27
MISSISSIPPI POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(29)	(13)
MISSISSIPPI POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(8)	(2)
MISSISSIPPI POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	3	22
MISSISSIPPI POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	7	20
SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(36)	(22)
SOUTHERN Co GAS | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(47)	(24)
SOUTHERN Co GAS | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	0	0
SOUTHERN Co GAS | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	11	2
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
	Mar. 31, 2023	Mar. 31, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	$ (86)	$ 27
Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(45)	42
Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(13)	9
Cash Flow Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	0	(28)
Fair Value Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(28)	4
GEORGIA POWER CO | Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(1)	12
SOUTHERN POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(11)	(23)
SOUTHERN POWER CO | Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(11)	5
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	0	(28)
SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(33)	37
SOUTHERN Co GAS | Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	(34)	37
SOUTHERN Co GAS | Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivatives	$ 1	$ 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
	Mar. 31, 2023	Mar. 31, 2022
Derivative [Line Items]
Depreciation and amortization	$ 1,111	$ 892
Total interest expense, net of amounts capitalized	(582)	(462)
Total other income (expense), net	147	145
Natural gas
Derivative [Line Items]
Total cost of sales	898	1,095
Other Income (Expense)
Derivative [Line Items]
Amount excluded from effectiveness testing recognized in earnings	28	(4)
Cash Flow Hedging | Energy-related derivatives | Cost of Sales
Derivative [Line Items]
Gain (loss) on hedges	(20)	9
Cash Flow Hedging | Energy-related derivatives | Depreciation and Amortization
Derivative [Line Items]
Gain (loss) on hedges	(9)	2
Cash Flow Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(4)	(7)
Cash Flow Hedging | Foreign currency derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(3)	(6)
Cash Flow Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	10	(25)
Fair Value Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	43	(123)
Fair Value Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	(2)	(24)
SOUTHERN POWER CO
Derivative [Line Items]
Depreciation and amortization	128	120
Total interest expense, net of amounts capitalized	(33)	(37)
Total other income (expense), net	2	2
SOUTHERN POWER CO | Cash Flow Hedging | Energy-related derivatives | Depreciation and Amortization
Derivative [Line Items]
Gain (loss) on hedges	(9)	2
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(3)	(6)
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	10	(25)
SOUTHERN Co GAS
Derivative [Line Items]
Depreciation and amortization	141	137
Total interest expense, net of amounts capitalized	(76)	(61)
Total other income (expense), net	14	16
SOUTHERN Co GAS | Natural gas
Derivative [Line Items]
Total cost of sales	898	1,095
SOUTHERN Co GAS | Cash Flow Hedging | Energy-related derivatives | Cost of Sales
Derivative [Line Items]
Gain (loss) on hedges	(20)	9
SOUTHERN Co GAS | Cash Flow Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(1)	(1)
SOUTHERN Co GAS | Fair Value Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	$ 13	$ (36)

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Derivatives - Schedule of Cumulative Basis Adjustments for Fair Value Hedges (Details) - Fair Value Hedging - Long-term debt - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Derivative [Line Items]
Carrying Amount of the Hedged Item	$ (3,007)	$ (2,927)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	228	282
SOUTHERN Co GAS
Derivative [Line Items]
Carrying Amount of the Hedged Item	(428)	(415)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	$ 69	$ 81

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Derivatives - Schedule of Pre-tax Effect of Interest Rate and Energy Related Derivatives on Income (Details) - Energy-related derivatives not designated as hedging instruments - Energy-related derivatives - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 13	$ 23
Natural gas revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	0	2
Cost of natural gas
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 13	$ 21

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Segment and Related Information - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) state segment	Mar. 31, 2022 USD ($)
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	3
Operating revenues	$ 6,241	$ 6,258
SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	$ 405	413
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	4
Operating revenues	$ 1,829	2,043
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%
SOUTHERN Co GAS | Dalton Pipeline
Segment Reporting Information [Line Items]
Ownership percentage, equity method investment	50.00%
Traditional Electric Operating Companies | Wholesale revenues, affiliates | SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	$ 135	$ 105

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Segment and Related Information - Schedule of Financial Data for Business Segments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2022
Segment Reporting Information [Line Items]
Operating revenues	$ 6,480	$ 6,648
Net income	862	1,032
Goodwill	5,161			$ 5,161
Total assets	134,756			134,891
SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	508	539
Total assets	13,134			13,081
SOUTHERN POWER CO | Disposal Group, Disposed of by Sale | Spare Parts
Segment Reporting Information [Line Items]
Gain on sale	16
Gain on sale, after tax			$ 12
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,875	2,058
Net income	309	319
Goodwill	5,015			5,015
Total assets	24,222			24,621
Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	4,483	4,509
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,875	2,058
Gas distribution operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	4,034			4,034
Gas marketing services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	981			981
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,872	2,054
Net income	302	309
Total assets	25,402			25,233
Operating Segments | Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	4,483	4,509
Net income	712	846
Goodwill	2			2
Total assets	108,782			108,283
Operating Segments | Traditional Electric Operating Companies
Segment Reporting Information [Line Items]
Operating revenues	4,113	4,191
Net income	610	774
Goodwill	0			0
Total assets	96,223			95,861
Operating Segments | SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	508	539
Net income	102	72
Goodwill	2			2
Total assets	13,134			13,081
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,875	2,058
Net income	309	319
Goodwill	5,015			5,015
Total assets	24,222			24,621
Operating Segments | Gas distribution operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,618	1,803
Net income	221	214
Total assets	22,223			22,040
Operating Segments | Gas Pipeline Investments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	8	8
Net income	31	29
Total assets	1,583			1,577
Operating Segments | Gas marketing services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	246	243
Net income	50	66
Total assets	1,596			1,616
Operating Segments | All Other
Segment Reporting Information [Line Items]
Operating revenues	166	123
Net income	(154)	(125)
Goodwill	144			144
Total assets	2,606			2,665
Operating Segments | All Other | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	12	16
Net income	7	10
Total assets	9,598			8,943
Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(44)	(42)
Net income	(5)	(8)
Goodwill	0			0
Total assets	(854)			(678)
Eliminations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	(9)	(12)
Net income	0	0
Total assets	(10,778)			(9,555)
Eliminations | Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	(138)	(221)
Net income	0	$ 0
Goodwill	0			0
Total assets	$ (575)			$ (659)

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Segment and Related Information - Schedule of Financial Data for Products and Services (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Concentration Risk [Line Items]
Operating revenues	$ 6,480	$ 6,648
Electric Utilities
Concentration Risk [Line Items]
Operating revenues	4,483	4,509
Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	1,875	2,058
Retail
Concentration Risk [Line Items]
Operating revenues	3,599	3,613
Retail | Electric Utilities
Concentration Risk [Line Items]
Operating revenues	3,599	3,613
Wholesale Electric
Concentration Risk [Line Items]
Operating revenues	599	664
Wholesale Electric | Electric Utilities
Concentration Risk [Line Items]
Operating revenues	599	664
Other Revenue | Electric Utilities
Concentration Risk [Line Items]
Operating revenues	285	232
Natural Gas
Concentration Risk [Line Items]
Operating revenues	1,875	2,058
Gas Distribution Operations | Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	1,610	1,791
Gas marketing services | Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	246	243
Other | Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	$ 19	$ 24