10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

þQUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2019

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 (A Delaware Corporation) 30 Ivan Allen Jr. Boulevard, N.W. Atlanta, Georgia 30308 (404) 506-5000	58-0690070
1-3164	Alabama Power Company (An Alabama Corporation) 600 North 18th Street Birmingham, Alabama 35203 (205) 257-1000	63-0004250
1-6468	Georgia Power Company (A Georgia Corporation) 241 Ralph McGill Boulevard, N.E. Atlanta, Georgia 30308 (404) 506-6526	58-0257110
001-11229	Mississippi Power Company (A Mississippi Corporation) 2992 West Beach Boulevard Gulfport, Mississippi 39501 (228) 864-1211	64-0205820
001-37803	Southern Power Company (A Delaware Corporation) 30 Ivan Allen Jr. Boulevard, N.W. Atlanta, Georgia 30308 (404) 506-5000	58-2598670
1-14174	Southern Company Gas (A Georgia Corporation) Ten Peachtree Place, N.E. Atlanta, Georgia 30309 (404) 584-4000	58-2210952

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, 2019
The Southern Company	Par Value $5 Per Share	1,040,295,732
Alabama Power Company	Par Value $40 Per Share	30,537,500
Georgia Power Company	Without Par Value	9,261,500
Mississippi Power Company	Without Par Value	1,121,000
Southern Power Company	Par Value $0.01 Per Share	1,000
Southern Company Gas	Par Value $0.01 Per Share	100

This combined Form 10-Q is separately filed by The Southern Company, Alabama Power Company, Georgia Power Company, Mississippi Power Company, Southern Power Company, and Southern Company Gas. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrants.

2

INDEX TO QUARTERLY REPORT ON FORM 10-Q

March 31, 2019

		Page Number
DEFINITIONS		5
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION		9
	PART I—FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations
	The Southern Company and Subsidiary Companies
	Condensed Consolidated Statements of Income	12
	Condensed Consolidated Statements of Comprehensive Income	13
	Condensed Consolidated Statements of Cash Flows	14
	Condensed Consolidated Balance Sheets	15
	Condensed Consolidated Statements of Stockholders' Equity	17
	Management's Discussion and Analysis of Financial Condition and Results of Operations	18
	Alabama Power Company
	Condensed Statements of Income	45
	Condensed Statements of Comprehensive Income	45
	Condensed Statements of Cash Flows	46
	Condensed Balance Sheets	47
	Condensed Statements of Common Stockholder's Equity	49
	Management's Discussion and Analysis of Financial Condition and Results of Operations	50
	Georgia Power Company
	Condensed Statements of Income	61
	Condensed Statements of Comprehensive Income	61
	Condensed Statements of Cash Flows	62
	Condensed Balance Sheets	63
	Condensed Statements of Common Stockholder's Equity	65
	Management's Discussion and Analysis of Financial Condition and Results of Operations	66
	Mississippi Power Company
	Condensed Statements of Operations	83
	Condensed Statements of Comprehensive Income	83
	Condensed Statements of Cash Flows	84
	Condensed Balance Sheets	85
	Condensed Statements of Common Stockholder's Equity	87
	Management's Discussion and Analysis of Financial Condition and Results of Operations	88
	Southern Power Company and Subsidiary Companies
	Condensed Consolidated Statements of Income	100
	Condensed Consolidated Statements of Comprehensive Income	100
	Condensed Consolidated Statements of Cash Flows	101
	Condensed Consolidated Balance Sheets	102
	Condensed Consolidated Statements of Stockholders' Equity	104
	Management's Discussion and Analysis of Financial Condition and Results of Operations	105

3

INDEX TO QUARTERLY REPORT ON FORM 10-Q

March 31, 2019

		Page Number
	PART I—FINANCIAL INFORMATION (CONTINUED)
	Southern Company Gas and Subsidiary Companies
	Condensed Consolidated Statements of Income	116
	Condensed Consolidated Statements of Comprehensive Income	116
	Condensed Consolidated Statements of Cash Flows	117
	Condensed Consolidated Balance Sheets	118
	Condensed Consolidated Statements of Stockholder's Equity	120
	Management's Discussion and Analysis of Financial Condition and Results of Operations	121
	Notes to the Condensed Financial Statements	141
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	43
Item 4.	Controls and Procedures	43
	PART II—OTHER INFORMATION
Item 1.	Legal Proceedings	198
Item 1A.	Risk Factors	198
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	198
	Signatures	202

4

DEFINITIONS

Term	Meaning
2013 ARP	Alternative Rate Plan approved by the Georgia PSC in 2013 for Georgia Power for the years 2014 through 2016 and subsequently extended through 2019
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 on March 22, 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
ASC	Accounting Standards Codification
ASU	Accounting Standards Update
Atlanta Gas Light	Atlanta Gas Light Company, a wholly-owned subsidiary of Southern Company Gas
Atlantic Coast Pipeline	Atlantic Coast Pipeline, LLC, a joint venture to construct and operate a natural gas pipeline in which Southern Company Gas has a 5% ownership interest
Bechtel	Bechtel Power Corporation, the primary contractor for the remaining construction activities for Plant Vogtle Units 3 and 4
Bechtel Agreement	The October 23, 2017 construction completion agreement between the Vogtle Owners and Bechtel
CCR	Coal combustion residuals
Chattanooga Gas	Chattanooga Gas Company, a wholly-owned subsidiary of Southern Company Gas
CO2	Carbon dioxide
COD	Commercial operation date
Contractor Settlement Agreement	The December 31, 2015 agreement between Westinghouse and the Vogtle Owners resolving disputes between the Vogtle Owners and the EPC Contractor under the Vogtle 3 and 4 Agreement
Cooperative Energy	Electric cooperative in Mississippi
Customer Refunds	Refunds issued to Georgia Power customers in 2018 as ordered by the Georgia PSC related to the Guarantee Settlement Agreement
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
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
FASB	Financial Accounting Standards Board
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, 2018, as applicable
GAAP	U.S. generally accepted accounting principles

5

DEFINITIONS

(continued)

Term	Meaning
Georgia Power	Georgia Power Company
GHG	Greenhouse gas
Guarantee Settlement Agreement	The June 9, 2017 settlement agreement between the Vogtle Owners and Toshiba related to certain payment obligations of the EPC Contractor guaranteed by Toshiba
Gulf Power	Gulf Power Company, until January 1, 2019, a subsidiary of Southern Company
Heating Degree Days	A measure of weather, calculated when the average daily temperatures are less than 65 degrees Fahrenheit
Heating Season	The period from November through March when Southern Company Gas' natural gas usage and operating revenues are generally higher
HLBV	Hypothetical liquidation at book value
IGCC	Integrated coal gasification combined cycle, the technology originally approved for Mississippi Power's Kemper County energy facility (Plant Ratcliffe)
IIC	Intercompany Interchange Contract
Illinois Commission	Illinois Commerce Commission
ITAAC	Inspections, Tests, Analyses, and Acceptance Criteria, standards established by the NRC
ITC	Investment tax credit
JEA	Jacksonville Electric Authority
KWH	Kilowatt-hour
LIFO	Last-in, first-out
LOCOM	Lower of weighted average cost or current market price
LTSA	Long-term service agreement
MEAG	Municipal Electric Authority of Georgia
Merger	The merger, effective July 1, 2016, of a wholly-owned, direct subsidiary of Southern Company with and into Southern Company Gas, with Southern Company Gas continuing as the surviving corporation
Mississippi Power	Mississippi Power Company
mmBtu	Million British thermal units
Moody's	Moody's Investors Service, Inc.
MRA	Municipal and Rural Associations
MW	Megawatt
natural gas distribution utilities	Southern Company Gas' natural gas distribution utilities (Nicor Gas, Atlanta Gas Light, Virginia Natural Gas, Elizabethtown Gas, Florida City Gas, Chattanooga Gas, and Elkton Gas as of June 30, 2018) (Nicor Gas, Atlanta Gas Light, Virginia Natural Gas, and Chattanooga Gas as of July 29, 2018)
NCCR	Georgia Power's Nuclear Construction Cost Recovery
NextEra Energy	NextEra Energy, Inc.
Nicor Gas	Northern Illinois Gas Company, a wholly-owned subsidiary of Southern Company Gas
NRC	U.S. Nuclear Regulatory Commission
NYMEX	New York Mercantile Exchange, Inc.
OATT	Open access transmission tariff
OCI	Other comprehensive income
PennEast Pipeline	PennEast Pipeline Company, LLC, a joint venture to construct and operate a natural gas pipeline in which Southern Company Gas has a 20% ownership interest
PEP	Mississippi Power's Performance Evaluation Plan
Pivotal Home Solutions	Nicor Energy Services Company, until June 4, 2018 a wholly-owned subsidiary of Southern Company Gas, doing business as Pivotal Home Solutions

6

DEFINITIONS

(continued)

Term	Meaning
Pivotal Utility Holdings	Pivotal Utility Holdings, Inc., until July 29, 2018 a wholly-owned subsidiary of Southern Company Gas, doing business as Elizabethtown Gas (until July 1, 2018), Elkton Gas (until July 1, 2018), and Florida City Gas
PowerSecure	PowerSecure, Inc.
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
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
Rate CNP Compliance	Alabama Power's Rate Certificated New Plant Compliance
Rate CNP PPA	Alabama Power's Rate Certificated New Plant Power Purchase Agreement
Rate ECR	Alabama Power's Rate Energy Cost Recovery
Rate NDR	Alabama Power's Rate Natural Disaster Reserve
Rate RSE	Alabama Power's Rate Stabilization and Equalization
registrants	Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power Company, and Southern Company Gas
revenue from contracts with customers	Revenue from contracts accounted for under the guidance of ASC 606, Revenue from Contracts with Customers
ROE	Return on equity
S&P	S&P Global Ratings, a division of S&P Global Inc.
SCS	Southern Company Services, Inc. (the Southern Company system service company)
SEC	U.S. Securities and Exchange Commission
SNG	Southern Natural Gas Company, L.L.C.
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 Gas Dispositions	Southern Company Gas' disposition of Pivotal Home Solutions, Pivotal Utility Holdings' disposition of Elizabethtown Gas and Elkton Gas, and NUI Corporation's disposition of Pivotal Utility Holdings, which primarily consisted of Florida City Gas
Southern Company system	Southern Company, the traditional electric operating companies, Southern Power, Southern Company Gas, Southern Electric Generating Company, Southern Nuclear, SCS, Southern Communications Services, Inc., PowerSecure, and other subsidiaries
Southern Nuclear	Southern Nuclear Operating Company, Inc.
Southern Power	Southern Power Company and its subsidiaries
SP Solar	SP Solar Holdings I, LP
SP Wind	SP Wind Holdings II, LLC
Tax Reform Legislation	The Tax Cuts and Jobs Act, which became effective on January 1, 2018
Toshiba	Toshiba Corporation, the parent company of Westinghouse
traditional electric operating companies	Alabama Power, Georgia Power, Gulf Power, and Mississippi Power through December 31, 2018; Alabama Power, Georgia Power, and Mississippi Power as of January 1, 2019
Triton	Triton Container Investments, LLC
VCM	Vogtle Construction Monitoring
VIE	Variable interest entity
Virginia Commission	Virginia State Corporation Commission

7

DEFINITIONS

(continued)

Term	Meaning
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, Oglethorpe Power Corporation, MEAG, and Dalton
Vogtle Services Agreement	The June 9, 2017 services agreement between the Vogtle Owners and the EPC Contractor, as amended and restated on July 20, 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

8

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q contains forward-looking statements. Forward-looking statements include, among other things, statements concerning regulated rates, the strategic goals for the business, customer and sales growth, economic conditions, fuel and environmental 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 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 and environmental laws and regulations 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;

• 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;

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

• transmission constraints;

• effects of inflation;

• the ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of facilities, including Plant Vogtle Units 3 and 4, which includes components based on new technology that only recently began initial operation in the global nuclear industry at this scale, and including changes in labor costs, availability, and productivity; challenges with management of contractors, subcontractors, or vendors; adverse weather conditions; shortages, increased costs, or inconsistent quality of equipment, materials, and labor; contractor or supplier delay; non-performance under construction, operating, or other agreements; operational readiness, including specialized operator training and required site safety programs; engineering or design problems; design and other licensing-based compliance matters, including the timely resolution of ITAAC and the related approvals by the NRC; challenges with start-up activities, including major equipment failure and system integration; and/or operational performance;

• 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;

• 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, and fuel and other cost recovery mechanisms;

9

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

(continued)

• the ability to successfully operate the electric utilities' generating, transmission, and distribution facilities and Southern Company Gas' natural gas distribution and storage facilities and the successful performance of necessary corporate functions;

• legal proceedings and regulatory approvals and actions related to construction projects, such as Plant Vogtle Units 3 and 4 and pipeline projects, 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 and the ability of other Vogtle Owners to tender a portion of their ownership interests to Georgia Power following certain construction cost increases;

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

• 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, including the proposed dispositions of Plant Mankato and the Nacogdoches biomass-fueled facility, which cannot be assured to be completed or beneficial to Southern Company or its subsidiaries;

• the ability of counterparties of Southern Company and its subsidiaries to make payments as and when due and to perform as required;

• the ability to obtain new short- and long-term contracts with wholesale customers;

• the direct or indirect effect on the Southern Company system's business resulting from cyber intrusion or physical attack and the threat of physical attacks;

• interest rate fluctuations and financial market conditions and the results of financing efforts;

• access to capital markets and other financing sources;

• changes in Southern Company's and any of its subsidiaries' credit ratings;

• the ability of Southern Company's electric utilities 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, or other similar occurrences;

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

• impairments of goodwill or long-lived assets;

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

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

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

10

THE SOUTHERN COMPANY

AND SUBSIDIARY COMPANIES

11

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Revenues:
Retail electric revenues	$	3,084		$	3,568
Wholesale electric revenues	499			623
Other electric revenues	168			161
Natural gas revenues (includes alternative revenue programs of $(2) and $(24), respectively)	1,474			1,607
Other revenues	187			413
Total operating revenues	5,412			6,372
Operating Expenses:
Fuel	850			1,101
Purchased power	170			267
Cost of natural gas	686			720
Cost of other sales	118			289
Other operations and maintenance	1,312			1,451
Depreciation and amortization	751			769
Taxes other than income taxes	329			355
Estimated loss on plants under construction	2			44
Gain on dispositions, net	(2,497		)	—
Total operating expenses	1,721			4,996
Operating Income	3,691			1,376
Other Income and (Expense):
Allowance for equity funds used during construction	32			30
Earnings from equity method investments	48			41
Interest expense, net of amounts capitalized	(430		)	(458		)
Other income (expense), net	78			60
Total other income and (expense)	(272		)	(327		)
Earnings Before Income Taxes	3,419			1,049
Income taxes	1,360			113
Consolidated Net Income	2,059			936
Dividends on preferred stock of subsidiaries	4			4
Net loss attributable to noncontrolling interests	(29		)	(6		)
Consolidated Net Income Attributable to Southern Company	$	2,084		$	938
Common Stock Data:
Earnings per share -
Basic	$	2.01		$	0.93
Diluted	$	1.99		$	0.92
Average number of shares of common stock outstanding (in millions)
Basic	1,038			1,011
Diluted	1,045			1,016

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

12

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Consolidated Net Income	$	2,059		$	936
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(9) and $16, respectively	(28		)	47
Reclassification adjustment for amounts included in net income, net of tax of $9 and $(6), respectively	28			(19		)
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax of $- and $-, respectively	—			2
Total other comprehensive income (loss)	—			30
Comprehensive Income	2,059			966
Dividends on preferred stock of subsidiaries	4			4
Comprehensive loss attributable to noncontrolling interests	(29		)	(6		)
Consolidated Comprehensive Income Attributable to Southern Company	$	2,084		$	968

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

13

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Activities:
Consolidated net income	$	2,059		$	936
Adjustments to reconcile consolidated net income to net cash provided from operating activities —
Depreciation and amortization, total	851			873
Deferred income taxes	191			34
Allowance for equity funds used during construction	(32		)	(30		)
Mark-to-market adjustments	46			(60		)
Pension, postretirement, and other employee benefits	(53		)	(27		)
Settlement of asset retirement obligations	(62		)	(41		)
Stock based compensation expense	64			69
Estimated loss on plants under construction	6			37
Gain on dispositions, net	(2,503		)	1
Other, net	19			73
Changes in certain current assets and liabilities —
-Receivables	378			197
-Prepayments	(129		)	(82		)
-Natural gas for sale	363			413
-Other current assets	17			7
-Accounts payable	(783		)	(425		)
-Accrued taxes	928			(79		)
-Accrued compensation	(489		)	(471		)
-Other current liabilities	(127		)	84
Net cash provided from operating activities	744			1,509
Investing Activities:
Business acquisitions, net of cash acquired	(2		)	(46		)
Property additions	(1,678		)	(1,781		)
Nuclear decommissioning trust fund purchases	(197		)	(306		)
Nuclear decommissioning trust fund sales	192			301
Proceeds from dispositions	4,427			135
Cost of removal, net of salvage	(89		)	(79		)
Change in construction payables, net	(146		)	(112		)
Investment in unconsolidated subsidiaries	(10		)	(30		)
Payments pursuant to LTSAs	(28		)	(73		)
Other investing activities	(15		)	(4		)
Net cash provided from (used for) investing activities	2,454			(1,995		)
Financing Activities:
Increase in notes payable, net	86			782
Proceeds —
Long-term debt	1,220			600
Common stock	224			113
Short-term borrowings	—			1,200
Redemptions and repurchases —
Long-term debt	(2,429		)	(1,283		)
Short-term borrowings	(1,750		)	(150		)
Distributions to noncontrolling interests	(36		)	(13		)
Capital contributions from noncontrolling interests	3			8
Payment of common stock dividends	(623		)	(586		)
Other financing activities	(48		)	(42		)
Net cash provided from (used for) financing activities	(3,353		)	629
Net Change in Cash, Cash Equivalents, and Restricted Cash	(155		)	143
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,519			2,147
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	1,364		$	2,290
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $18 and $17 capitalized for 2019 and 2018, respectively)	$	462		$	499
Income taxes, net	—			(1		)
Noncash transactions — Accrued property additions at end of period	899			894

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

14

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2019			At December 31, 2018
	(in millions)
Current Assets:
Cash and cash equivalents	$	1,361		$	1,396
Receivables —
Customer accounts receivable	1,715			1,726
Energy marketing receivables	529			801
Unbilled revenues	555			654
Under recovered fuel clause revenues	73			115
Other accounts and notes receivable	863			813
Accumulated provision for uncollectible accounts	(46		)	(50		)
Materials and supplies	1,477			1,465
Fossil fuel for generation	427			405
Natural gas for sale	189			524
Prepaid expenses	786			432
Assets from risk management activities, net of collateral	111			222
Other regulatory assets	482			525
Assets held for sale	55			393
Other current assets	132			162
Total current assets	8,709			9,583
Property, Plant, and Equipment:
In service	102,673			103,706
Less: Accumulated depreciation	30,834			31,038
Plant in service, net of depreciation	71,839			72,668
Other utility plant, net	1,315			—
Nuclear fuel, at amortized cost	885			875
Construction work in progress	7,598			7,254
Total property, plant, and equipment	81,637			80,797
Other Property and Investments:
Goodwill	5,284			5,315
Equity investments in unconsolidated subsidiaries	1,598			1,580
Other intangible assets, net of amortization of $251 and $235 at March 31, 2019 and December 31, 2018, respectively	585			613
Nuclear decommissioning trusts, at fair value	1,875			1,721
Leveraged leases	806			798
Miscellaneous property and investments	363			269
Total other property and investments	10,511			10,296
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,881			—
Deferred charges related to income taxes	794			794
Unamortized loss on reacquired debt	318			323
Other regulatory assets, deferred	8,191			8,308
Assets held for sale, deferred	763			5,350
Other deferred charges and assets	1,292			1,463
Total deferred charges and other assets	13,239			16,238
Total Assets	$	114,096		$	116,914

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

15

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholders' Equity	At March 31, 2019		At December 31, 2018
	(in millions)
Current Liabilities:
Securities due within one year	$	2,315	$	3,198
Notes payable	1,251		2,915
Energy marketing trade payables	532		856
Accounts payable	2,037		2,580
Customer deposits	483		522
Accrued taxes —
Accrued income taxes	340		21
Other accrued taxes	331		635
Accrued interest	412		472
Accrued compensation	473		1,030
Asset retirement obligations	417		404
Other regulatory liabilities	310		376
Liabilities held for sale	38		425
Operating lease obligations	226		—
Other current liabilities	754		852
Total current liabilities	9,919		14,286
Long-term Debt	40,457		40,736
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	7,937		6,558
Deferred credits related to income taxes	6,417		6,460
Accumulated deferred ITCs	2,353		2,372
Employee benefit obligations	2,084		2,147
Operating lease obligations, deferred	1,720		—
Asset retirement obligations, deferred	9,011		8,990
Accrued environmental remediation	261		268
Other cost of removal obligations	2,304		2,297
Other regulatory liabilities, deferred	211		169
Liabilities held for sale, deferred	39		2,836
Other deferred credits and liabilities	405		465
Total deferred credits and other liabilities	32,742		32,562
Total Liabilities	83,118		87,584
Redeemable Preferred Stock of Subsidiaries	291		291
Total Stockholders' Equity (See accompanying statements)	30,687		29,039
Total Liabilities and Stockholders' Equity	$	114,096	$	116,914

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

16

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 thousands)			(in millions)
Balance at December 31, 2017	1,008,532	(929	)	$	5,037	$	10,470	$	(36	)	$	8,885		$	(189	)	$	1,361		$	25,528
Consolidated net income attributable to Southern Company	—	—		—		—		—			938			—			—			938
Other comprehensive income	—	—		—		—		—			—			30			—			30
Stock issued	4,055	—		16		97		—			—			—			—			113
Stock-based compensation	—	—		—		36		—			—			—			—			36
Cash dividends of $0.58 per share	—	—		—		—		—			(586		)	—			—			(586		)
Contributions from noncontrolling interests	—	—		—		—		—			—			—			9			9
Distributions to noncontrolling interests	—	—		—		—		—			—			—			(13		)	(13		)
Net income (loss) attributable to noncontrolling interests	—	—		—		—		—			—			—			(6		)	(6		)
Other	—	(33	)	1		—		(2		)	20			(41		)	(2		)	(24		)
Balance at March 31, 2018	1,012,587	(962	)	$	5,054	$	10,603	$	(38	)	$	9,257		$	(200	)	$	1,349		$	26,025
Balance at December 31, 2018	1,034,741	(953	)	$	5,164	$	11,094	$	(38	)	$	8,706		$	(203	)	$	4,316		$	29,039
Consolidated net income attributable to Southern Company	—	—		—		—		—			2,084			—			—			2,084
Stock issued	6,547	—		28		196		—			—			—			—			224
Stock-based compensation	—	—		—		24		—			—			—			—			24
Cash dividends of $0.60 per share	—	—		—		—		—			(622		)	—			—			(622		)
Contributions from noncontrolling interests	—	—		—		—		—			—			—			3			3
Distributions to noncontrolling interests	—	—		—		—		—			—			—			(41		)	(41		)
Net income (loss) attributable to noncontrolling interests	—	—		—		—		—			—			—			(29		)	(29		)
Other	—	(39	)	—		7		(2		)	(1		)	—			1			5
Balance at March 31, 2019	1,041,288	(992	)	$	5,192	$	11,321	$	(40	)	$	10,167		$	(203	)	$	4,250		$	30,687

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

17

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2019 vs. FIRST QUARTER 2018

OVERVIEW

Southern Company is a holding company that owns all of the common stock of the traditional electric operating companies and the parent entities of Southern Power and Southern Company Gas and owns other direct and indirect subsidiaries. Discussion of the results of operations is focused on the Southern Company system's primary businesses of 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 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, wholesale gas services, and gas marketing services. The Southern Company system's other business activities include providing energy solutions, such as distributed energy infrastructure, energy efficiency products and services, and utility infrastructure services, to customers. Other business activities also include investments in telecommunications, leveraged lease projects, and gas storage facilities. For additional information, see BUSINESS – "The Southern Company System – Traditional Electric Operating Companies," " – Southern Power," " – Southern Company Gas," and " – Other Businesses" in Item 1 of the Form 10-K.

On January 1, 2019, Southern Company completed its sale of Gulf Power to NextEra Energy for an aggregate cash purchase price of approximately $5.8 billion (less $1.3 billion of indebtedness assumed), subject to customary working capital adjustments. The preliminary gain associated with the sale of Gulf Power totaled $2.5 billion pre-tax ($1.3 billion after tax). See Note (K) to the Condensed Financial Statements under "Southern Company" herein for additional information.

Georgia Power and Atlanta Gas Light are required to file base rate cases with the Georgia PSC by July 1, 2019 and June 3, 2019, respectively. Nicor Gas filed a rate case with the Illinois Commission in November 2018. These three rate cases are expected to conclude in 2019. In addition, Mississippi Power is scheduled to file a base rate case with the Mississippi PSC in the fourth quarter 2019. The ultimate outcome of these matters cannot be determined at this time. See FUTURE EARNINGS POTENTIAL – "Regulatory Matters" herein and Note 2 to the financial statements in Item 8 of the Form 10-K for additional information.

Southern Company continues to focus on several key performance indicators. These indicators include, but are not limited to, customer satisfaction, plant availability, electric and natural gas system reliability, execution of major construction projects, and earnings per share.

Plant Vogtle Units 3 and 4 Status

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4 (with electric generating capacity of approximately 1,100 MWs each). Georgia Power holds a 45.7% ownership interest in Plant Vogtle Units 3 and 4. In March 2017, the EPC Contractor filed for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code. In December 2017, the Georgia PSC approved Georgia Power's recommendation to continue construction. The current expected in-service dates remain November 2021 for Unit 3 and November 2022 for Unit 4.

In the second quarter 2018, Georgia Power revised its base capital cost forecast and estimated contingency to complete construction and start-up of Plant Vogtle Units 3 and 4 to $8.0 billion and $0.4 billion, respectively, for a total project capital cost forecast of $8.4 billion (net of $1.7 billion received under the Guarantee Settlement Agreement and approximately $188 million in related Customer Refunds), with respect to Georgia Power's ownership interest.

As a result of the increase in the total project capital cost forecast and Georgia Power's decision not to seek rate recovery of the increase in the base capital costs, the holders of at least 90% of the ownership interests in Plant

18

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Vogtle Units 3 and 4 were required to vote to continue construction. In September 2018, the Vogtle Owners unanimously voted to continue construction of Plant Vogtle Units 3 and 4. In connection with the vote to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and certain of MEAG's wholly-owned subsidiaries, including MEAG Power SPVJ, LLC (MEAG SPVJ), to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners and (ii) a term sheet (MEAG Term Sheet) with MEAG and MEAG SPVJ to provide funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. On January 14, 2019, Georgia Power, MEAG, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. On February 18, 2019, Georgia Power, the other Vogtle Owners, and certain of MEAG's wholly-owned subsidiaries entered into certain amendments to their joint ownership agreements to implement the provisions of the Vogtle Owner Term Sheet.

In April 2019, Southern Nuclear completed a cost and schedule validation process to verify and update quantities of commodities remaining to install, labor hours to install remaining quantities and related productivity, testing and system turnover requirements, and forecasted staffing needs and related costs. This process confirmed the total estimated project capital cost forecast for Plant Vogtle Units 3 and 4. The expected in-service dates of November 2021 for Unit 3 and November 2022 for Unit 4, as previously approved by the Georgia PSC, remain unchanged.

In March 2019, Georgia Power entered into the Amended and Restated Loan Guarantee Agreement with the DOE, 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, up to approximately $5.130 billion. At March 31, 2019, Georgia Power had a total of $3.46 billion of borrowings outstanding under the related multi-advance credit facilities.

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

See FUTURE EARNINGS POTENTIAL – "Construction Program – Nuclear Construction" and Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information.

RESULTS OF OPERATIONS

Net Income

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$1,146	122.2

Consolidated net income attributable to Southern Company was $2.1 billion ($2.01 per share) for the first quarter 2019 compared to $938 million ($0.93 per share) for the corresponding period in 2018. The increase was primarily due to the $2.5 billion ($1.3 billion after tax) gain on the sale of Gulf Power in 2019, partially offset by a decrease in retail revenues due to milder weather compared to the corresponding period in 2018. See Note (K) to the Condensed Financial Statements under "Southern Company" herein for additional information.

Retail Electric Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(484)	(13.6)

In the first quarter 2019, retail electric revenues were $3.1 billion compared to $3.6 billion for the corresponding period in 2018.

19

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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

	First Quarter 2019
	(in millions)			(% change)
Retail electric – prior year	$	3,568
Estimated change resulting from –
Rates and pricing	58			1.6
Sales decline	(11		)	(0.3	)
Weather	(91		)	(2.6	)
Fuel and other cost recovery	(150		)	(4.2	)
Gulf Power disposition	(290		)	(8.1	)
Retail electric – current year	$	3,084		(13.6	)%

Revenues associated with changes in rates and pricing increased in the first quarter 2019 when compared to the corresponding period in 2018 primarily due to increases under Rate CNP Compliance at Alabama Power and increases related to PEP and ECO Plan rate changes that became effective for the first billing cycle of September 2018 at Mississippi Power.

See Note 2 to the financial statements under "Alabama Power" and "Mississippi Power" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein for additional information.

Revenues attributable to changes in sales decreased in the first quarter 2019 when compared to the corresponding period in 2018. In the first quarter 2019, weather-adjusted residential KWH sales increased 0.4% primarily due to customer growth, partially offset by decreased customer usage primarily resulting from an increase in energy efficient residential appliances. Weather-adjusted commercial KWH sales decreased 1.9% primarily due to decreased customer usage resulting from an increase in energy saving initiatives, partially offset by customer growth. Industrial KWH sales decreased 2.0% in the first quarter 2019 when compared to the corresponding period in 2018 as a result of a decrease in demand resulting from changes in production levels primarily in the primary metals, chemicals, and paper sectors, partially offset by increased demand in the pipeline sector.

Fuel and other cost recovery revenues decreased $150 million in the first quarter 2019 compared to the corresponding period in 2018 primarily due to decreased energy sales driven by milder weather, resulting in lower customer demand and lower generation costs. Electric rates for the traditional electric operating companies includeprovisions 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.

Wholesale Electric Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(124)	(19.9)

Wholesale electric revenues consist of 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

20

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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.

In the first quarter 2019, wholesale electric revenues were $499 million compared to $623 million for the corresponding period in 2018. This decrease was related to a $106 million decrease in energy revenues and an $18 million decrease in capacity revenues. Excluding a decrease of $7 million of energy revenues related to the sale of Gulf Power, the decrease in energy revenues primarily related to Southern Power and included a decrease in non-PPA revenues due to a decrease in the volume of KWHs sold through short-term sales, primarily due to a reduction in uncovered natural gas capacity, as well as a decrease in revenues related to natural gas PPAs due to a decrease in the average cost of fuel and purchased power, partially offset by an increase in the volume of KWHs sold due to increased customer load. The decrease was also due to lower fuel prices and lower customer demand due to milder weather at the traditional electric operating companies. The decrease in capacity revenues primarily related to the sales of Gulf Power and Southern Power's Plant Oleander and Plant Stanton Unit A. See Note 15 to the financial statements under "Southern Power – Sales of Natural Gas Plants" in Item 8 of the Form 10-K for additional information.

Natural Gas Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(133)	(8.3)

In the first quarter 2019, natural gas revenues were $1.5 billion compared to $1.6 billion for the corresponding period in 2018.

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

	First Quarter 2019
	(in millions)			(% change)
Natural gas revenues – prior year	$	1,607
Estimated change resulting from –
Infrastructure replacement programs and base rate changes	32			2.0
Gas costs and other cost recovery	62			3.9
Weather	7			0.4
Wholesale gas services	(80		)	(5.0	)
Southern Company Gas Dispositions	(167		)	(10.4	)
Other	13			0.8
Natural gas revenues – current year	$	1,474		(8.3	)%

Revenues attributable to infrastructure replacement programs and base rate changes at the natural gas distribution utilities increased for the first quarter 2019 compared to the corresponding period in 2018 primarily due to a $22 million increase at Nicor Gas and a $9 million increase at Atlanta Gas Light. These amounts include the natural gas distribution utilities' continued investments recovered through infrastructure replacement programs and base rate increases as well as increases due to the impacts of the Tax Reform Legislation.

21

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Revenues attributable to gas costs and other cost recovery increased in the first quarter 2019 compared to the corresponding period in 2018 primarily due to higher natural gas prices and increased volumes of natural gas sold at Southern Company Gas' remaining four natural gas distribution utilities in the first quarter 2019. 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 increased due to colder weather, as determined by Heating Degree Days, in Illinois in the first quarter 2019 compared to the corresponding period in 2018.

Revenues attributable to Southern Company Gas' wholesale gas services business decreased in the first quarter 2019 compared to the corresponding period in 2018 primarily due to decreased commercial activity, partially offset by derivative gains.

See Note (B) to the Condensed Financial Statements herein under "Southern Company Gas" for additional information.

Other Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(226)	(54.7)

In the first quarter 2019, other revenues were $187 million compared to $413 million for the corresponding period in 2018. The decrease was primarily related to PowerSecure's 2018 storm restoration services in Puerto Rico.

Fuel and Purchased Power Expenses

	First Quarter 2019 vs. First Quarter 2018
	(change in millions)			(% change)
Fuel	$	(251	)	(22.8)
Purchased power	(97		)	(36.3)
Total fuel and purchased power expenses	$	(348	)

In the first quarter 2019, total fuel and purchased power expenses were $1.0 billion compared to $1.4 billion for the corresponding period in 2018. Excluding a decrease of $121 million related to the sale of Gulf Power, the decrease was primarily the result of a $149 million decrease in the average cost of fuel and purchased power and a $78 million net decrease in the aggregate 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 FUTURE EARNINGS POTENTIAL – "Regulatory Matters – Fuel Cost Recovery" herein 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.

22

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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

	First Quarter 2019	First Quarter 2018(a)
Total generation (in billions of KWHs)	43	46
Total purchased power (in billions of KWHs)	4	3
Sources of generation (percent) —
Gas	48	45
Coal	22	29
Nuclear	16	16
Hydro	8	4
Other	6	6
Cost of fuel, generated (in cents per net KWH)—
Gas	2.56	2.84
Coal	2.92	2.88
Nuclear	0.79	0.78
Average cost of fuel, generated (in cents per net KWH)	2.32	2.47
Average cost of purchased power (in cents per net KWH)(b)	4.50	7.04

(a) Excludes Gulf Power, which was sold on January 1, 2019.

(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 2019, fuel expense was $850 million compared to $1.1 billion for the corresponding period in 2018. Excluding approximately $54 million related to Gulf Power in 2018, the decrease was primarily due to a 29.1% decrease in the volume of KWHs generated by coal and a 9.9% decrease in the average cost of natural gas per KWH generated.

Purchased Power

In the first quarter 2019, purchased power expense was $170 million compared to $267 million for the corresponding period in 2018. Excluding approximately $67 million of non-affiliated purchases by Gulf Power in 2018 and $22 million of non-affiliated purchases from Gulf Power in 2019 that would have been eliminated in consolidation in 2018, the decrease was primarily due to a 29.1% decrease in the average cost per KWH purchased. See Note (K) to the Condensed Financial Statements under "Southern Company" herein for information regarding the sale of Gulf Power.

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 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(34)	(4.7)

Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through

23

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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 87% of total cost of natural gas for the first quarter 2019.

In the first quarter 2019, cost of natural gas was $686 million compared to $720 million for the corresponding period in 2018. Excluding a $79 million decrease related to the Southern Company Gas Dispositions, cost of natural gas increased $45 million. This increase reflects a 4.9% increase in natural gas prices and an increase in the volume of natural gas sold in the first quarter 2019 primarily as a result of colder weather in Illinois, as determined by Heating Degree Days, compared to the corresponding period in 2018.

Cost of Other Sales

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(171)	(59.2)

In the first quarter 2019, cost of other sales was $118 million compared to $289 million for the corresponding period in 2018. The decrease was primarily related to PowerSecure's 2018 storm restoration services in Puerto Rico.

Other Operations and Maintenance Expenses

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(139)	(9.6)

In the first quarter 2019, other operations and maintenance expenses were $1.3 billion compared to $1.5 billion for the corresponding period in 2018. The decrease reflects approximately $76 million related to Gulf Power in 2018 and $71 million related to the Southern Company Gas Dispositions, including the $42 million goodwill impairment charge recorded in contemplation of the sale of Pivotal Home Solutions.

Depreciation and Amortization

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(18)	(2.3)

In the first quarter 2019, depreciation and amortization was $751 million compared to $769 million for the corresponding period in 2018. The decrease was primarily due to decreases of $47 million related to the sale of Gulf Power and $16 million related to the Southern Company Gas Dispositions, partially offset by an increase of $33 million related to additional plant in service.

Taxes Other Than Income Taxes

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(26)	(7.3)

In the first quarter 2019, taxes other than income taxes were $329 million compared to $355 million for the corresponding period in 2018. The decrease primarily relates to the sale of Gulf Power.

24

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Estimated Loss on Plants Under Construction

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(42)	(95.5)

In the first quarter 2019, estimated loss on plants under construction was $2 million compared to $44 million for the corresponding period in 2018. The decrease was primarily due to lower costs associated with abandonment and closure activities for the mine and gasifier-related assets of the Kemper IGCC at Mississippi 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 "Mississippi Power – Kemper County Energy Facility" for additional information.

Gain on Dispositions, Net

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$2,497	N/M

N/M - Not meaningful

In the first quarter 2019, a net gain on dispositions of $2.5 billion ($1.3 billion gain after tax) was recorded related to the sale of Gulf Power. See Note (K) to the Condensed Financial Statements under "Southern Company" herein for additional information.

Interest Expense, Net of Amounts Capitalized

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(28)	(6.1)

In the first quarter 2019, interest expense, net of amounts capitalized was $430 million compared to $458 million in the corresponding period in 2018. Excluding a decrease of $13 million related to the sale of Gulf Power, the decrease was immaterial.

See FINANCIAL CONDITION AND LIQUIDITY – "Financing Activities" herein, Note 8 to the financial statements in Item 8 of the Form 10-K, and Note (F) to the Condensed Financial Statements herein for additional information.

Other Income (Expense), Net

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$18	30.0

In the first quarter 2019, other income (expense), net was $78 million compared to $60 million for the corresponding period in 2018. The increase was primarily due to an increase in interest income from a new tolling arrangement accounted for as a lease at Mississippi Power and temporary cash investments.

25

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Income Taxes

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$1,247	N/M

N/M - Not meaningful

In the first quarter 2019, income taxes were $1.4 billion compared to $113 million for the corresponding period in 2018. The increase was primarily due to tax expense related to the sale of Gulf Power.

See Notes (G) and (K) to the Condensed Financial Statements herein for additional information.

Net Loss Attributable to Noncontrolling Interests

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$23	N/M

N/M - Not meaningful

Substantially all noncontrolling interests relate to renewable projects at Southern Power. See Note 7 to the financial statements in Item 8 of the Form 10-K under "Southern Power" for additional information.

In the first quarter 2019, net loss attributable to noncontrolling interests was $29 million compared to $6 million for the corresponding period in 2018. The increase was primarily related to tax equity partnerships entered into in 2018.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Southern Company's future earnings potential. Future earnings will be impacted by the recently completed and additional pending disposition activities described herein, in Note (K) to the Condensed Financial Statements herein, and in Note 15 to the financial statements in Item 8 of the Form 10-K. The level of Southern Company's future earnings depends on numerous factors that affect the opportunities, challenges, and risks of the Southern Company system's primary businesses of selling electricity and distributing natural gas. These factors include the traditional electric operating companies' and the natural gas distribution utilities' ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs during a time of increasing costs, continued customer growth, and, for the traditional electric operating companies, the weak pace of growth in electricity use per customer, especially in residential and commercial markets. Plant Vogtle Units 3 and 4 construction and rate recovery and the profitability of Southern Power's competitive wholesale business are also major factors.

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, increasing volumes of electronic commerce transactions, and more multi-family home construction, all of which could contribute to a net reduction in customer usage. Earnings for both the electricity and natural gas businesses are subject to a variety of other factors. These factors include weather, competition, new energy contracts with other utilities and other wholesale customers, energy conservation practiced by customers, the use of alternative energy sources by customers, the prices of electricity and natural gas, the price elasticity of demand, and the rate of economic growth or decline in the service territory. In addition, the level of future earnings for the wholesale electric business also depends on numerous factors including regulatory matters, creditworthiness of customers, total electric generating capacity available and related costs, the development or acquisition of renewable facilities and other energy projects, and the successful remarketing of capacity as current contracts expire. Demand for electricity and natural gas is primarily driven by the pace of economic growth that may be affected by changes in regional and global economic conditions, which may impact future earnings. In addition, the volatility of natural gas prices has a significant impact on the natural gas distribution utilities' customer rates, long-term competitive position against

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other energy sources, and the ability of Southern Company Gas' gas marketing services and wholesale gas services businesses to capture value from locational and seasonal spreads. Additionally, changes in commodity prices subject a significant portion of Southern Company Gas' operations to earnings variability.

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 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 November 2018, Southern Power entered into an agreement to sell all of its equity interests in Plant Mankato (including the 385-MW expansion currently under construction) for an aggregate purchase price of approximately $650 million. The completion of the disposition is subject to the expansion unit reaching commercial operation as well as various other customary conditions to closing, including FERC and state commission approvals. On April 17, 2019, Southern Power entered into an agreement to sell all of its equity interests in the Nacogdoches biomass-fueled facility to Austin Energy for an aggregate purchase price of $460 million, subject to customary closing conditions and working capital adjustments. Each of these sales is expected to close in mid-2019; however, the ultimate outcome of these matters cannot be determined at this time.

For additional information relating to these issues, see RISK FACTORS and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL of Southern Company in Item 7 of the Form 10-K.

Environmental Matters

The Southern Company system's operations are regulated by state and federal environmental agencies through a variety of laws and regulations governing air, water, land, and protection of other natural resources. The Southern Company system maintains comprehensive environmental compliance and GHG strategies to assess upcoming requirements and compliance costs associated with these environmental laws and regulations. The costs, including capital expenditures, operations and maintenance costs, and costs reflected in ARO liabilities, required to comply with environmental laws and regulations and to achieve stated goals may impact future electric generating unit retirement and replacement decisions, results of operations, cash flows, and/or financial condition. Related costs may result from the installation of additional environmental controls, closure and monitoring of CCR facilities, unit retirements, or changing fuel sources for certain existing units, as well as related upgrades to the Southern Company system's transmission and distribution (electric and natural gas) systems. A major portion of these costs is expected to be recovered through retail and wholesale rates. The ultimate impact of environmental laws and regulations and GHG goals will depend on various factors, such as state adoption and implementation of requirements, the availability and cost of any deployed technology, fuel prices, and the outcome of pending and/or future legal challenges.

New or revised environmental laws and regulations could affect many areas of the traditional electric operating companies', Southern Power's, and the natural gas distribution utilities' operations. The impact of any such changes cannot be determined at this time. Environmental compliance costs could affect earnings if such costs cannot continue to be recovered in rates on a timely basis for the traditional electric operating companies and the natural gas distribution utilities or through long-term wholesale agreements for the traditional electric operating companies and Southern Power. Further, increased costs that are recovered through regulated rates could contribute to reduced demand for electricity and natural gas, which could negatively affect results of operations, cash flows, and/or financial condition. Additionally, many commercial and industrial customers may also be affected by existing and future environmental requirements, which for some may have the potential to ultimately affect their demand for electricity and natural gas. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" of Southern Company in Item 7 and Note 3 to the financial statements under "Environmental Matters" in Item 8 of the Form 10-K for additional information.

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Regulatory Matters

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.

Fuel Cost Recovery

The traditional electric operating companies each have established fuel cost recovery rates approved by their respective state PSCs. Fuel cost recovery revenues are adjusted for differences in actual recoverable fuel costs and amounts billed in current regulated rates. Accordingly, changes in the billing factor will not have a significant effect on Southern Company's revenues or net income, but will affect cash flow. The traditional electric operating companies continuously monitor their under or over recovered fuel cost balances and make appropriate filings with their state PSCs to adjust fuel cost recovery rates as necessary.

Alabama Power

Alabama Power's revenues from regulated retail operations are collected through various rate mechanisms subject to the oversight of the Alabama PSC. Alabama Power currently recovers its costs from the regulated retail business primarily through Rate RSE, Rate CNP, Rate ECR, and Rate NDR. In addition, the Alabama PSC issues accounting orders to address current events impacting Alabama Power.

Environmental Accounting Order

In connection with management's decision to retire Plant Gorgas, in February 2019, Alabama Power reclassified approximately $1.3 billion for Plant Gorgas Unit 10 from plant in service, net of depreciation to other utility plant, net and continued to depreciate the asset according to the original depreciation rates. On April 15, 2019, Alabama Power retired Plant Gorgas Units 8, 9, and 10 and reclassified approximately $740 million of the remaining net investment costs of the units to a regulatory asset to be recovered over the units' remaining useful lives as established prior to the decision to retire. Additionally, approximately $700 million of net capitalized asset retirement costs will be reclassified to a regulatory asset and recovered in accordance with accounting guidance provided by the Alabama PSC. See Note 2 to the financial statements under "Alabama Power – Environmental Accounting Order" and Note 6 in Item 8 of the Form 10-K for additional information.

Georgia Power

Georgia Power's revenues from regulated retail operations are collected through various rate mechanisms subject to the oversight of the Georgia PSC. Georgia Power currently recovers its costs from the regulated retail business through the 2013 ARP, which includes traditional base tariff rates, Demand-Side Management tariffs, Environmental Compliance Cost Recovery tariffs, and Municipal Franchise Fee tariffs. Georgia Power is scheduled to file a base rate case by July 1, 2019, which may continue or modify these tariffs. In addition, financing costs related to certified construction costs of Plant Vogtle Units 3 and 4 are being collected through the NCCR tariff and fuel costs are collected through a separate fuel cost recovery tariff.

Mississippi Power

Kemper County Energy Facility

As the mining permit holder, Liberty Fuels Company, LLC has a legal obligation to perform mine reclamation, and Mississippi Power has a contractual obligation to fund all reclamation activities. As a result of the abandonment of the Kemper IGCC, final mine reclamation began in 2018 and is expected to be substantially completed in 2020, with monitoring expected to continue through 2027. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

During the first quarter 2019, Mississippi Power recorded pre-tax charges to income of $2 million ($1 million after tax), primarily resulting from the abandonment and related closure activities and ongoing period costs, net of sales proceeds, for the mine and gasifier-related assets at the Kemper County energy facility. Additional closure costs for

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the mine and gasifier-related assets, currently estimated at up to $10 million pre-tax (excluding salvage, net of dismantlement costs), may be incurred through the first half of 2020. In addition, period costs, including, but not limited to, costs for compliance and safety, ARO accretion, and property taxes for the mine and gasifier-related assets, are estimated at $11 million for the remainder of 2019 and $2 million to $6 million annually in 2020 through 2023.

In addition, Mississippi Power constructed the CO₂ pipeline for the planned transport of captured CO₂ for use in enhanced oil recovery and is currently evaluating its options regarding the final disposition of the CO₂ pipeline, including removal of the pipeline. This evaluation is expected to be complete later in 2019. If Mississippi Power ultimately decides to remove the CO₂ pipeline, the cost of removal could have a material impact on Southern Company's financial statements.

In December 2018, Mississippi Power filed with the DOE its request for property closeout certification under the contract related to the $387 million of grants received. Mississippi Power and the DOE are currently in discussions regarding the requested closeout and property disposition, which may require payment to the DOE for a portion of certain property that is to be retained by Mississippi Power. In connection with the DOE closeout discussions, on April 29, 2019, the Civil Division of the Department of Justice informed Southern Company and Mississippi Power of an investigation related to the Kemper County energy facility. The ultimate outcome of these matters cannot be determined at this time; however, they could have a material impact on Southern Company's financial statements.

Southern Company Gas

The natural gas distribution utilities are subject to regulation and oversight by their respective state regulatory agencies for the rates charged to their customers and other matters. With the exception of Atlanta Gas Light, which does not sell natural gas to end-use customers, the natural gas distribution utilities are authorized by the relevant regulatory agencies in the states in which they serve to use natural gas cost recovery mechanisms that adjust rates to reflect changes in the wholesale cost of natural gas and ensure recovery of all costs prudently incurred in purchasing natural gas for customers. Natural gas cost recovery revenues are adjusted for differences in actual recoverable natural gas costs and amounts billed in current regulated rates. Changes in the billing factor will not have a significant effect on revenues or net income, but will affect cash flows. In addition to natural gas cost recovery mechanisms, there are other cost recovery mechanisms, such as regulatory riders, which vary by utility but allow recovery of certain costs, such as those related to infrastructure replacement programs, as well as environmental remediation and energy efficiency plans.

In November 2018, Nicor Gas filed a general base rate case with the Illinois Commission requesting a $230 million increase in annual base rate revenues. The requested increase is based on a projected test year for the 12-month period ending September 30, 2020, a ROE of 10.6%, and an increase in the equity ratio from 52% to 54% to address the negative cash flow and credit metric impacts of the Tax Reform Legislation.

On April 16, 2019, Nicor Gas entered into a stipulation agreement to resolve all related issues with the Staff of the Illinois Commission, including a ROE of 9.86% and an equity ratio of 54%. Also on April 16, 2019, Nicor Gas filed its rebuttal testimony with the Illinois Commission incorporating the stipulation agreement and addressing the remaining items outstanding with the other two intervenors. As a result of the stipulation agreement and rebuttal testimony, the revised requested annual revenue increase is $180 million.

The Illinois Commission is expected to rule on the requested increase within the statutory time limit of 11 months from the filing of the rate case, after which rate adjustments will be effective.

Atlanta Gas Light is required to file a traditional base rate case no later than June 3, 2019 for rates effective January 1, 2020.

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

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Construction Program

Overview

The subsidiary companies of Southern Company are engaged in continuous construction programs to accommodate existing and estimated future loads on their respective systems. The Southern Company system intends to continue its strategy of developing and constructing new electric generating facilities, adding environmental modifications to certain existing units, expanding and improving the electric transmission and distribution systems, and updating and expanding the natural gas distribution systems. For the traditional electric operating companies, major generation construction projects are subject to state PSC approval in order to be included in retail rates. While Southern Power generally constructs and acquires generation assets covered by long-term PPAs, any uncontracted capacity could negatively affect future earnings. Southern Company Gas is engaged in various infrastructure improvement programs designed to update or expand the natural gas distribution systems of the natural gas distribution utilities to improve reliability and meet operational flexibility and growth. The natural gas distribution utilities recover their investment and a return associated with these infrastructure programs through their regulated rates. See Notes 2 and 15 to the financial statements under "Southern Company Gas – Infrastructure Replacement Programs and Capital Projects" and "Southern Power," respectively, in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

The largest construction project currently underway in the Southern Company system is Plant Vogtle Units 3 and 4 (45.7% ownership interest by Georgia Power in the two units, each with approximately 1,100 MWs). See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K and "Nuclear Construction" herein for additional information.

Also see FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" herein for additional information regarding Southern Company's capital requirements for its subsidiaries' construction programs.

Nuclear Construction

See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information regarding the construction of Plant Vogtle Units 3 and 4, the joint ownership agreements and related funding agreement, VCM reports, and the NCCR tariff.

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4. Georgia Power holds a 45.7% ownership interest in Plant Vogtle Units 3 and 4. 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 March 2017, the EPC Contractor filed for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code. In connection with the EPC Contractor's bankruptcy filing, 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, a cost reimbursable plus fee arrangement, whereby Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, which is 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

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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.

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4 by the expected in-service dates of November 2021 and November 2022, respectively, is as follows:

	(in billions)
Base project capital cost forecast(a)(b)	$	8.0
Construction contingency estimate	0.4
Total project capital cost forecast(a)(b)	8.4
Net investment as of March 31, 2019(b)	(4.9		)
Remaining estimate to complete(a)	$	3.5

(a) Excludes financing costs expected to be capitalized through AFUDC of approximately $325 million.

(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 $3.1 billion, of which $1.9 billion had been incurred through March 31, 2019.

In April 2019, Southern Nuclear completed a cost and schedule validation process to verify and update quantities of commodities remaining to install, labor hours to install remaining quantities and related productivity, testing and system turnover requirements, and forecasted staffing needs and related costs. This process confirmed the total estimated project capital cost forecast for Plant Vogtle Units 3 and 4. The expected in-service dates of November 2021 for Unit 3 and November 2022 for Unit 4, as previously approved by the Georgia PSC, remain unchanged.

As construction continues, challenges with management of contractors, subcontractors, and vendors; supervision of craft labor and related craft labor productivity, ability to attract and retain craft labor, and/or related cost escalation; procurement, fabrication, delivery, assembly, and/or installation and the initial testing and start-up, including any required engineering changes, of plant systems, structures, or components (some of which are based on new technology that only recently began initial operation in the global nuclear industry at this scale), any of which may require additional labor and/or materials; or other issues could arise and change the projected schedule and estimated cost. Monthly construction production targets established as part of a strategy to maintain and build margin to the approved in-service dates will continue to increase significantly throughout 2019. To meet these increasing monthly targets, existing craft construction productivity must improve and additional craft laborers must be retained and deployed.

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 assure 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. As a result of such compliance processes, certain license amendment requests have been filed and approved or are pending before the NRC. Various design and other licensing-based compliance matters, including the timely resolution of ITAAC and the related approvals by the NRC, may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues are not resolved in a timely manner, there may be delays in the project schedule that could result in increased costs.

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The ultimate outcome of these matters cannot be determined at this time. However, any extension of the regulatory-approved project schedule is currently estimated to result in additional base capital costs of approximately $50 million per month, based on Georgia Power's ownership interests, and AFUDC of approximately $12 million per month. While Georgia Power is not precluded from seeking recovery of any future capital cost forecast increase, 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.

As a result of the increase in the total project capital cost forecast and Georgia Power's decision not to seek rate recovery of the increase in the base capital costs in conjunction with the nineteenth VCM report, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 were required to vote to continue construction. In September 2018, the Vogtle Owners unanimously voted to continue construction of Plant Vogtle Units 3 and 4.

Amendments to the Vogtle Joint Ownership Agreements

In connection with the vote to continue construction, Georgia Power entered into (i) the Vogtle Owner Term Sheet with the other Vogtle Owners and MEAG's wholly-owned subsidiaries 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) the MEAG Term Sheet with MEAG and MEAG SPVJ to provide funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. On January 14, 2019, Georgia Power, MEAG, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. On February 18, 2019, Georgia Power, the other Vogtle Owners, and MEAG'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.

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, 2019, Georgia Power had recovered approximately $1.9 billion of financing costs. Financing costs related to capital costs above $4.418 billion will be recovered through AFUDC; however, Georgia Power will not record 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 2018, the Georgia PSC approved Georgia Power's request to increase the NCCR tariff by $88 million annually, effective January 1, 2019.

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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 amounts 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 prudence decisions on cost recovery will be made at a later date, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 ARP) 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 upon Unit 3 reaching commercial operation, retail base rates would be adjusted to include carrying costs on those capital costs deemed prudent in the Vogtle Cost Settlement Agreement. 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 $100 million in 2018 and are estimated to have negative earnings impacts of approximately $75 million in 2019 and an aggregate of approximately $635 million from 2020 to 2022.

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 February 2018, Georgia Interfaith Power & Light, Inc. (GIPL) and Partnership for Southern Equity, Inc. (PSE) filed a petition appealing the Georgia PSC's January 11, 2018 order with the Fulton County Superior Court. In March 2018, Georgia Watch filed a similar appeal to the Fulton County Superior Court for judicial review of the Georgia PSC's decision and denial of Georgia Watch's motion for reconsideration. In December 2018, the Fulton County Superior Court granted Georgia Power's motion to dismiss the two appeals. On January 9, 2019, GIPL, PSE, and Georgia Watch filed an appeal of this decision with the Georgia Court of Appeals. Georgia Power believes the appeal has no merit; however, an adverse outcome in the appeal combined with subsequent adverse action by the Georgia PSC could have a material impact on Southern Company's results of operations, financial condition, and liquidity.

In August 2018, Georgia Power filed its nineteenth VCM report with the Georgia PSC, which requested approval of $578 million of construction capital costs incurred from January 1, 2018 through June 30, 2018. On February 19, 2019, the Georgia PSC approved the nineteenth VCM, but deferred approval of $51.6 million of expenditures

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related to Georgia Power's portion of an administrative claim filed in the Westinghouse bankruptcy proceedings. Through the nineteenth VCM, the Georgia PSC has approved total construction capital costs incurred through June 30, 2018 of $5.4 billion (before $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related Customer Refunds). In addition, the staff of the Georgia PSC requested, and Georgia Power agreed, to report the results of the cost and schedule validation process to the Georgia PSC (which is expected to occur by May 1, 2019) and to file its twentieth VCM report concurrently with the twenty-first VCM report by August 31, 2019.

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

See RISK FACTORS of Southern Company in the Form 10-K for a discussion of certain risks associated with the licensing, construction, and operation of nuclear generating units, including potential impacts that could result from a major incident at a nuclear facility anywhere in the world.

DOE Financing

At March 31, 2019, Georgia Power had borrowed $3.46 billion related to Plant Vogtle Units 3 and 4 costs as provided through the Amended and Restated Loan Guarantee Agreement and related multi-advance credit facilities among Georgia Power, the DOE, and the FFB, which provide for borrowings of up to approximately $5.130 billion, subject to the satisfaction of certain conditions. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information, including applicable covenants, events of default, mandatory prepayment events, and conditions to borrowing.

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

Other Matters

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Other Matters" of Southern Company in Item 7 for additional information.

Southern Company and its subsidiaries are involved in various other matters that could affect future earnings, including matters being litigated, as well as other regulatory matters and matters that could result in asset impairments. In addition, Southern Company and its subsidiaries are subject to certain claims and legal actions arising in the ordinary course of business. The business activities of Southern Company's subsidiaries are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of other natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO₂ and other emissions, CCR, and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters.

The ultimate outcome of such pending or potential litigation, regulatory matters, or potential asset impairments cannot be predicted at this time; however, for current proceedings not specifically reported 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 would have a material effect on Southern Company's financial statements. See Notes (B) and (C) to the Condensed Financial Statements herein for a discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

Litigation

In January 2017, a putative securities class action complaint was filed against Southern Company, certain of its officers, and certain former Mississippi Power officers in the U.S. District Court for the Northern District of Georgia by Monroe County Employees' Retirement System on behalf of all persons who purchased shares of Southern Company's common stock between April 25, 2012 and October 29, 2013. The complaint alleges that Southern Company, certain of its officers, and certain former Mississippi Power officers made materially false and

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

misleading statements regarding the Kemper County energy facility in violation of certain provisions under the Securities Exchange Act of 1934, as amended. The complaint seeks, among other things, compensatory damages and litigation costs and attorneys' fees. In 2017, the plaintiffs filed an amended complaint that provided additional detail about their claims, increased the purported class period by one day, and added certain other former Mississippi Power officers as defendants. Also in 2017, the defendants filed a motion to dismiss the plaintiffs' amended complaint with prejudice, to which the plaintiffs filed an opposition. In March 2018, the court issued an order granting, in part, the defendants' motion to dismiss. The court dismissed certain claims against certain officers of Southern Company and Mississippi Power and dismissed the allegations related to a number of the statements that plaintiffs challenged as being false or misleading. In April 2018, the defendants filed a motion for reconsideration of the court's order, seeking dismissal of the remaining claims in the lawsuit. In August 2018, the court denied the motion for reconsideration and denied a motion to certify the issue for interlocutory appeal.

In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of Georgia. The complaints allege that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints allege that the defendants were unjustly enriched and caused the waste of corporate assets and also allege that the individual defendants violated their fiduciary duties. Each plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. Each plaintiff also seeks certain changes to Southern Company's corporate governance and internal processes. In April 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action.

In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. The complaint alleges that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleges that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. The plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and disgorgement of profits and, on its behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiff also seeks certain unspecified changes to Southern Company's corporate governance and internal processes. In May 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action.

In May 2018, Southern Company and Mississippi Power received a notice of dispute and arbitration demand filed by Martin Product Sales, LLC (Martin) based on two agreements, both related to Kemper IGCC byproducts for which Mississippi Power provided termination notices in 2017. Martin alleges breach of contract, breach of good faith and fair dealing, fraud and misrepresentation, and civil conspiracy and makes a claim for damages in the amount of approximately $143 million, as well as additional unspecified damages, attorney's fees, costs, and interest. In the first quarter 2019, Mississippi Power and Southern Company filed motions to dismiss.

Southern Company believes these legal challenges have no merit; however, an adverse outcome in any of these proceedings could have an impact on Southern Company's results of operations, financial condition, and liquidity. The ultimate outcome of these matters cannot be determined at this time.

Mississippi Power

In conjunction with Southern Company's sale of Gulf Power, Mississippi Power and Gulf Power have committed to seek a restructuring of their 50% undivided ownership interests in Plant Daniel such that each of them would, after the restructuring, own 100% of a generating unit. On January 15, 2019, Gulf Power provided notice to Mississippi

35

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Power that Gulf Power will retire its share of the generating capacity of Plant Daniel on January 15, 2024. Mississippi Power has the option to purchase Gulf Power's ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior to that date. Mississippi Power is assessing the potential operational and economic effects of Gulf Power's notice. The ultimate outcome of these matters remains subject to completion of Mississippi Power's evaluations and applicable regulatory approvals, including by the FERC and the Mississippi PSC, and cannot be determined at this time. See Note (K) to the Condensed Financial Statements under "Southern Company" herein for information regarding the sale of Gulf Power.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Southern Company prepares its consolidated financial statements in accordance with GAAP. Significant accounting policies are described in Notes 1, 5, and 6 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 Southern Company's results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES – "Application of Critical Accounting Policies and Estimates" of Southern Company in Item 7 of the Form 10-K for a complete discussion of Southern Company's critical accounting policies and estimates.

Recently Issued Accounting Standards

See Note (A) to the Condensed Financial Statements herein for information regarding Southern Company's recently adopted accounting standards.

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" of Southern Company in Item 7 of the Form 10-K for additional information. Southern Company's financial condition remained stable at March 31, 2019. Southern Company intends to continue to monitor its access to short-term and long-term capital markets as well as bank credit agreements to meet future capital and liquidity needs. See "Capital Requirements and Contractual Obligations," "Sources of Capital," and "Financing Activities" herein for additional information.

Net cash provided from operating activities totaled $0.7 billion for the first three months of 2019, a decrease of $0.8 billion from the corresponding period in 2018. The decrease in net cash provided from operating activities was primarily due to the timing of vendor payments and the impacts of the Gulf Power disposition and the Southern Company Gas Dispositions. Net cash provided from investing activities totaled $2.5 billion for the first three months of 2019 primarily due to proceeds from the sale of Gulf Power, partially offset by the traditional electric operating companies' installation of equipment to comply with environmental standards and construction of electric generation, transmission, and distribution facilities and capital expenditures for Southern Company Gas' infrastructure replacement programs. Net cash used for financing activities totaled $3.4 billion for the first three months of 2019 primarily due to repayments of short-term bank debt, net redemptions and repurchases of long-term debt, and common stock dividend payments. Cash flows from financing activities vary from period to period based on capital needs and the maturity or redemption of securities. See Notes (F) and (K) to the Condensed Financial Statements herein for additional information.

Significant balance sheet changes for the first three months of 2019 include decreases in assets and liabilities held for sale of $4.9 billion and $3.2 billion, respectively, primarily related to the sale of Gulf Power; the recording of $1.9 billion in operating lease right-of-use assets, net of amortization and operating lease obligations related to the adoption of FASB ASC Topic 842, Leases; a decrease of $1.7 billion in notes payable related to the repayment of short-term bank debt; an increase of $1.6 billion in total stockholders' equity primarily related to the gain on the sale

36

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

of Gulf Power; an increase of $1.4 billion in accumulated deferred income taxes primarily related to the expected utilization of tax credit carryforwards in the 2019 tax year as a result of increased taxable income from the sale of Gulf Power; a decrease of $1.2 billion in long-term debt (including amounts due within one year) resulting from net repayments of long-term debt; and an increase of $0.8 billion in total property, plant, and equipment primarily related to the traditional electric operating companies' installation of equipment to comply with environmental standards and construction of electric generation, transmission, and distribution facilities. See Notes (F), (K), and (L) to the Condensed Financial Statements herein for additional information.

At the end of the first quarter 2019, the market price of Southern Company's common stock was $51.68 per share (based on the closing price as reported on the New York Stock Exchange) and the book value was $25.41 per share, representing a market-to-book ratio of 203%, compared to $43.92, $23.91, and 184%, respectively, at the end of 2018. Southern Company's common stock dividend for the first quarter 2019 was $0.60 per share compared to $0.58 per share in the first quarter 2018.

Capital Requirements and Contractual Obligations

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" of Southern Company in Item 7 of the Form 10-K for a description of Southern Company's capital requirements and contractual obligations. Approximately $2.3 billion will be required through March 31, 2020 to fund maturities of long-term debt. See "Sources of Capital" herein 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; the cost and efficiency of construction labor, equipment, and materials; project scope and design changes; storm impacts; and the cost of capital. In addition, there can be no assurance that costs related to capital expenditures will be fully recovered. Additionally, planned expenditures for plant acquisitions may vary due to market opportunities and Southern Power's ability to execute its growth strategy. See Note 15 to the financial statements under "Southern Power" in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information regarding Southern Power's plant acquisitions and construction projects.

The construction program also includes Plant Vogtle Units 3 and 4, which includes components based on new technology that only recently began initial operation in the global nuclear industry at this scale and which may be subject to additional revised cost estimates during construction. The ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of new facilities is subject to a number of factors, including, but not limited to, changes in labor costs, availability, and productivity; challenges with management of contractors, subcontractors, or vendors; adverse weather conditions; shortages, increased costs, or inconsistent quality of equipment, materials, and labor; contractor or supplier delay; non-performance under construction, operating, or other agreements; operational readiness, including specialized operator training and required site safety programs; engineering or design problems; design and other licensing-based compliance matters, including the timely resolution of ITAAC and the related approvals by the NRC; challenges with start-up activities, including major equipment failure and system integration; and/or operational performance. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for information regarding Plant Vogtle Units 3 and 4 and additional factors that may impact construction expenditures.

37

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Sources of Capital

Southern Company intends to meet its future capital needs through operating cash flows, borrowings from financial institutions, and debt and equity issuances in the capital markets. Equity capital can be provided from any combination of Southern Company's stock plans, private placements, or public offerings. The amount and timing of additional equity and debt issuances in 2019, as well as in subsequent years, will be contingent on Southern Company's investment opportunities and the Southern Company system's capital requirements and will depend upon prevailing market conditions and other factors. See "Capital Requirements and Contractual Obligations" herein for additional information.

Except as described herein, the traditional electric operating companies, Southern Power, and Southern Company Gas plan to obtain the funds required for construction and other purposes from operating cash flows, external security issuances, borrowings from financial institutions, and equity contributions or loans from Southern Company. Southern Power also plans to utilize tax equity partnership contributions, as well as funds resulting from its pending asset sales. However, the amount, type, and timing of any future financings, if needed, will depend upon prevailing market conditions, regulatory approval, and other factors. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" of Southern Company in Item 7 of the Form 10-K for additional information. Also see Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information regarding the pending sales of Plants Mankato and Nacogdoches.

In addition, in 2014, Georgia Power entered into a loan guarantee agreement with the DOE and, in March 2019, entered into the Amended and Restated Loan Guarantee Agreement, 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.

Under the Amended and Restated Loan Guarantee Agreement, the DOE has agreed to guarantee the obligations of Georgia Power under note purchase agreements among the DOE, Georgia Power, and the FFB and related promissory notes which provide for two multi-advance term loan facilities (FFB Credit Facilities). Under the FFB Credit Facilities, Georgia Power may make term loan borrowings through the FFB in an amount up to approximately$5.130 billion, provided that total aggregate borrowings under the FFB Credit Facilities may not exceed 70% of (i) Eligible Project Costs minus (ii) approximately $1.492 billion (reflecting the amounts received by Georgia Power under the Guarantee Settlement Agreement less the Customer Refunds).At March 31, 2019, Georgia Power had borrowed $3.46 billion under the FFB Credit Facilities.

See Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information regarding the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, mandatory prepayment events, and additional conditions to borrowing. Also see Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information regarding Plant Vogtle Units 3 and 4.

Southern Company's current liabilities frequently exceed current assets because of scheduled maturities of long-term debt and the periodic use of short-term debt as a funding source, as well as significant seasonal fluctuations in cash needs. As of March 31, 2019, Southern Company's current liabilities exceeded current assets by $1.2 billion, primarily due to long-term debt that is due within one year of $2.3 billion (including approximately $1.0 billion at Georgia Power, $0.3 billion at Mississippi Power, $0.6 billion at Southern Power, and $0.4 billion at Southern Company Gas) and notes payable of $1.3 billion (including approximately $0.5 billion at the parent company, $0.3 billion at Georgia Power, $0.1 billion at Southern Power, and $0.4 billion at Southern Company Gas), partially offset by $1.4 billion of cash and cash equivalents. To meet short-term cash needs and contingencies, the Southern Company system has substantial cash flow from operating activities and access to capital markets and financial institutions. Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas intend to utilize operating cash flows, as well as commercial paper, lines of credit, bank notes, and securities issuances, as market conditions permit, as well as, under certain circumstances for the traditional electric

38

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

operating companies, Southern Power, and Southern Company Gas, equity contributions and/or loans from Southern Company to meet their short-term capital needs.

At March 31, 2019, Southern Company and its subsidiaries had approximately $1.4 billion of cash and cash equivalents. Committed credit arrangements with banks at March 31, 2019 were as follows:

	Expires
Company	2019		2020		2022		Total		Unused(d)
	(in millions)
Southern Company(a)	$	—	$	—	$	2,000	$	2,000	$	1,999
Alabama Power	33		500		800		1,333		1,333
Georgia Power	—		—		1,750		1,750		1,736
Mississippi Power	100		—		—		100		100
Southern Power(b)	—		—		750		750		741
Southern Company Gas(c)	—		—		1,900		1,900		1,895
Other	30		—		—		30		30
Southern Company Consolidated	$	163	$	500	$	7,200	$	7,863	$	7,834

(a) Represents the Southern Company parent entity.

(b) Does not include Southern Power Company's $120 million continuing letter of credit facility for standby letters of credit expiring in 2021, of which $24 million was unused at March 31, 2019. Southern Power's subsidiaries are not parties to its bank credit arrangement.

(c) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $1.4 billion of this arrangement. Southern Company Gas' committed credit arrangement also includes $500 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to this multi-year credit arrangement, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

(d) Amounts used are for letters of credit.

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

Most of these bank credit arrangements, as well as the term loan arrangements of Alabama Power, Southern Power Company, and SEGCO, contain covenants that limit debt levels and contain cross-acceleration or 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 the applicable borrower 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, 2019, Southern Company, the traditional electric operating companies, Southern Power Company, Southern Company Gas, 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.

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.

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 Southern Company, the traditional electric operating companies, Southern Power Company, Southern Company Gas, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support as of March 31, 2019 was approximately $1.4 billion. In addition, at March 31, 2019, the traditional electric operating companies had approximately $432 million of revenue bonds outstanding that are required to be remarketed within the next 12 months. Subsequent to March 31, 2019, Georgia Power purchased and held approximately $115 million of outstanding pollution control revenue bonds required to be remarketed.

39

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Southern Company, Alabama Power, Georgia Power, Southern Power Company, Southern Company Gas, 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. Short-term borrowings are included in notes payable in the balance sheets.

Details of short-term borrowings were as follows:

	Short-term Debt at March 31, 2019				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)
Commercial paper	$	1,151	2.9	%	$	1,248	2.9	%	$	2,293
Short-term bank debt	100		3.1	%	208		3.2	%	1,850
Total	$	1,251	2.9	%	$	1,456	2.9	%

(*) Average and maximum amounts are based upon daily balances during the three-month period ended March 31, 2019.

Southern Company believes the need for working capital can be adequately met by utilizing commercial paper programs, lines of credit, bank term loans, and operating cash flows.

Credit Rating Risk

At March 31, 2019, Southern Company and its subsidiaries 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 subsidiaries to BBB and/or Baa2 or below. These contracts are for physical electricity and natural gas purchases and sales, fuel purchases, fuel transportation and storage, energy price risk management, transmission, interest rate management, and construction of new generation at Plant Vogtle Units 3 and 4.

The maximum potential collateral requirements under these contracts at March 31, 2019 were as follows:

Credit Ratings	Maximum Potential Collateral Requirements
	(in millions)
At BBB and/or Baa2	$	30
At BBB- and/or Baa3	$	433
At BB+ and/or Ba1(*)	$	1,988

(*) Any additional credit rating downgrades at or below BB- and/or Ba3 could increase collateral requirements up to an additional $38 million.

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 Southern Company and its subsidiaries to access capital markets, and would be likely to impact the cost at which they do so.

As a result of the Tax Reform Legislation, certain financial metrics, such as the funds from operations to debt percentage, used by the credit rating agencies to assess Southern Company and its subsidiaries may be negatively impacted. Southern Company and most of its regulated subsidiaries have taken actions to mitigate the resulting impacts, which, among other alternatives, include adjusting capital structure. Absent actions by Southern Company and its subsidiaries that fully mitigate the impacts, the credit ratings of Southern Company and certain of its subsidiaries could be negatively affected. See Note 2 to the financial statements in Item 8 of the Form 10-K for

40

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

additional information related to state PSC or other regulatory agency actions related to the Tax Reform Legislation, including approvals of capital structure adjustments for Alabama Power, Georgia Power, and Atlanta Gas Light by their respective state PSCs and a similar request by Nicor Gas currently pending Illinois Commission approval, which are expected to help mitigate the potential adverse impacts to certain of their credit metrics.

Financing Activities

During the first three months of 2019, Southern Company issued approximately 6.5 million shares of common stock primarily through employee equity compensation plans and received proceeds of approximately $224 million.

The following table outlines the long-term debt financing activities for Southern Company and its subsidiaries for the first three months of 2019:

Company	Senior Note Maturities, Redemptions, and Repurchases		Revenue Bond Issuances and Reofferings of Purchased Bonds		Revenue Bond Maturities, Redemptions, and Repurchases		Other Long-Term Debt Issuances		Other Long-Term Debt Redemptions and Maturities(a)
	(in millions)
Southern Company(b)	$	2,100	$	—	$	—	$	—	$	—
Alabama Power	200		—		—		—		—
Georgia Power	—		343		108		835		2
Mississippi Power	—		43		—		—		—
Other	—		—		—		—		19
Southern Company Consolidated	$	2,300	$	386	$	108	$	835	$	21

(a) Includes reductions in finance lease obligations resulting from cash payments under finance leases.

(b) Represents the Southern Company parent entity.

Except as otherwise described herein, Southern Company and its subsidiaries 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 subsidiaries also used the proceeds for their construction programs.

In January 2019, Southern Company repaid a $250 million short-term uncommitted bank credit arrangement and a $1.5 billion short-term floating rate bank loan.

Also in January 2019, through cash tender offers, Southern Company repurchased and retired approximately $522 million of the $1.0 billion aggregate principal amount outstanding of its 1.85% Senior Notes due July 1, 2019 (1.85% Notes), approximately $180 million of the $350 million aggregate principal amount outstanding of its Series 2014B 2.15% Senior Notes due September 1, 2019 (Series 2014B Notes), and approximately $504 million of the $750 million aggregate principal amount outstanding of its Series 2018A Floating Rate Notes due February 14, 2020 (Series 2018A Notes), for an aggregate purchase price, excluding accrued and unpaid interest, of approximately $1.2 billion. In addition, following the completion of the cash tender offers, in February 2019, Southern Company completed the redemption of all of the Series 2018A Notes, 1.85% Notes, and Series 2014B Notes remaining outstanding.

As reflected in the table above, in March 2019, Georgia Power made additional borrowings under the FFB Credit Facilities in an aggregate principal amount of $835 million at an interest rate of 3.213% through the final maturity date of February 20, 2044. The proceeds were used to reimburse Georgia Power for Eligible Project Costs relating to the construction of Plant Vogtle Units 3 and 4.

41

SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Subsequent to March 31, 2019, Georgia Power purchased and held the following pollution control revenue bonds, which may be reoffered to the public at a later date:

• $55 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1994;

• $30 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1995;

• $20 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Ninth Series 1994; and

• $10 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 1994.

In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Southern Company and its subsidiaries 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.

42

PART I

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

During the three months ended March 31, 2019, there were no material changes to Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, and Southern Power's disclosures about market risk. For additional market risk disclosures relating to Southern Company Gas, see MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Market Price Risk" of Southern Company Gas herein. For an in-depth discussion of each registrant's market risks, see MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Market Price Risk" of each registrant 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. Also see Notes (I) and (J) to the Condensed Financial Statements herein for information relating to derivative instruments.

Item 4. Controls and Procedures.

(a) Evaluation of disclosure controls and procedures.

As of the end of the period covered by this Quarterly Report on Form 10-Q, Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas conducted separate evaluations under the supervision and with the participation of each company's management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures (as defined in Sections 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended). Based upon these evaluations, the Chief Executive Officer and the Chief Financial Officer, in each case, concluded that the disclosure controls and procedures are effective.

(b) Changes in internal controls over financial reporting.

There have been no changes in Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended) during the first quarter 2019 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.

43

ALABAMA POWER COMPANY

44

ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Revenues:
Retail revenues	$	1,213		$	1,285
Wholesale revenues, non-affiliates	61			74
Wholesale revenues, affiliates	60			51
Other revenues	74			63
Total operating revenues	1,408			1,473
Operating Expenses:
Fuel	301			326
Purchased power, non-affiliates	37			64
Purchased power, affiliates	21			37
Other operations and maintenance	409			387
Depreciation and amortization	199			189
Taxes other than income taxes	103			98
Total operating expenses	1,070			1,101
Operating Income	338			372
Other Income and (Expense):
Allowance for equity funds used during construction	14			13
Interest expense, net of amounts capitalized	(83		)	(79		)
Other income (expense), net	14			5
Total other income and (expense)	(55		)	(61		)
Earnings Before Income Taxes	283			311
Income taxes	62			82
Net Income	221			229
Dividends on Preferred Stock	4			4
Net Income After Dividends on Preferred Stock	$	217		$	225

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019		2018
	(in millions)
Net Income	$	221	$	229
Other comprehensive income (loss):
Qualifying hedges:
Reclassification adjustment for amounts included in net income, net of tax of $- and $1, respectively	1		1
Total other comprehensive income (loss)	1		1
Comprehensive Income	$	222	$	230

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

45

ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Activities:
Net income	$	221		$	229
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	244			228
Deferred income taxes	—			32
Other, net	(24		)	(21		)
Changes in certain current assets and liabilities —
-Receivables	105			(1		)
-Prepayments	(78		)	(82		)
-Materials and supplies	(4		)	(27		)
-Other current assets	19			19
-Accounts payable	(286		)	(216		)
-Accrued taxes	80			57
-Accrued compensation	(122		)	(108		)
-Other current liabilities	(9		)	45
Net cash provided from operating activities	146			155
Investing Activities:
Property additions	(390		)	(490		)
Nuclear decommissioning trust fund purchases	(68		)	(50		)
Nuclear decommissioning trust fund sales	68			51
Cost of removal, net of salvage	(16		)	(19		)
Change in construction payables	(95		)	(50		)
Other investing activities	(10		)	(6		)
Net cash used for investing activities	(511		)	(564		)
Financing Activities:
Increase in notes payable, net	—			245
Proceeds — Capital contributions from parent company	1,232			484
Redemptions — Senior notes	(200		)	—
Payment of common stock dividends	(211		)	(202		)
Other financing activities	(10		)	(9		)
Net cash provided from financing activities	811			518
Net Change in Cash, Cash Equivalents, and Restricted Cash	446			109
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	313			544
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	759		$	653
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $5 and $5 capitalized for 2019 and 2018, respectively)	$	89		$	84
Income taxes, net	—			9
Noncash transactions — Accrued property additions at end of period	176			195

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

46

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2019			At December 31, 2018
	(in millions)
Current Assets:
Cash and cash equivalents	$	759		$	313
Receivables —
Customer accounts receivable	382			403
Unbilled revenues	126			150
Affiliated	45			94
Other accounts and notes receivable	58			51
Accumulated provision for uncollectible accounts	(10		)	(10		)
Fossil fuel stock	120			141
Materials and supplies	558			546
Prepaid expenses	113			66
Other regulatory assets	125			137
Other current assets	21			18
Total current assets	2,297			1,909
Property, Plant, and Equipment:
In service	28,810			30,402
Less: Accumulated provision for depreciation	9,447			9,988
Plant in service, net of depreciation	19,363			20,414
Other utility plant, net	1,315			—
Nuclear fuel, at amortized cost	320			324
Construction work in progress	1,023			1,113
Total property, plant, and equipment	22,021			21,851
Other Property and Investments:
Equity investments in unconsolidated subsidiaries	64			65
Nuclear decommissioning trusts, at fair value	933			847
Miscellaneous property and investments	129			127
Total other property and investments	1,126			1,039
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	160			—
Deferred charges related to income taxes	239			240
Deferred under recovered regulatory clause revenues	21			116
Other regulatory assets, deferred	1,350			1,386
Other deferred charges and assets	193			189
Total deferred charges and other assets	1,963			1,931
Total Assets	$	27,407		$	26,730

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

47

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2019		At December 31, 2018
	(in millions)
Current Liabilities:
Securities due within one year	$	1	$	201
Accounts payable —
Affiliated	262		364
Other	346		614
Customer deposits	97		96
Accrued taxes	97		44
Accrued interest	77		89
Accrued compensation	102		227
Asset retirement obligations	163		163
Other current liabilities	97		161
Total current liabilities	1,242		1,959
Long-term Debt	7,924		7,923
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	2,971		2,962
Deferred credits related to income taxes	2,015		2,027
Accumulated deferred ITCs	105		106
Employee benefit obligations	302		314
Operating lease obligations	147		—
Asset retirement obligations, deferred	3,064		3,047
Other cost of removal obligations	489		497
Other regulatory liabilities	107		69
Other deferred credits and liabilities	30		58
Total deferred credits and other liabilities	9,230		9,080
Total Liabilities	18,396		18,962
Redeemable Preferred Stock	291		291
Common Stockholder's Equity (See accompanying statements)	8,720		7,477
Total Liabilities and Stockholder's Equity	$	27,407	$	26,730

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

48

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, 2017	31	$	1,222	$	2,986	$	2,647		$	(26	)	$	6,829
Net income after dividends on preferred stock	—	—		—		225			—			225
Capital contributions from parent company	—	—		488		—			—			488
Other comprehensive income (loss)	—	—		—		—			1			1
Cash dividends on common stock	—	—		—		(202		)	—			(202		)
Other	—	—		—		—			(6		)	(6		)
Balance at March 31, 2018	31	$	1,222	$	3,474	$	2,670		$	(31	)	$	7,335
Balance at December 31, 2018	31	$	1,222	$	3,508	$	2,775		$	(28	)	$	7,477
Net income after dividends on preferred stock	—	—		—		217			—			217
Capital contributions from parent company	—	—		1,236		—			—			1,236
Other comprehensive income (loss)	—	—		—		—			1			1
Cash dividends on common stock	—	—		—		(211		)	—			(211		)
Balance at March 31, 2019	31	$	1,222	$	4,744	$	2,781		$	(27	)	$	8,720

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

49

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2019 vs. FIRST QUARTER 2018

OVERVIEW

Alabama Power operates as a vertically integrated utility providing electric service to retail and wholesale customers within its traditional service territory located in the State of Alabama in addition to wholesale customers in the Southeast.

Many factors affect the opportunities, challenges, and risks of Alabama Power's business of providing electric service. These factors include the ability to maintain a constructive regulatory environment, to maintain and grow energy sales and customers, and to effectively manage and secure timely recovery of costs. These costs include those related to projected long-term demand growth, stringent environmental standards, including CCR rules, reliability, fuel, capital expenditures, including improving the electric transmission and distribution systems, and restoration following major storms. Alabama Power has various regulatory mechanisms that operate to address cost recovery. Effectively operating pursuant to these regulatory mechanisms and appropriately balancing required costs and capital expenditures with customer prices will continue to challenge Alabama Power for the foreseeable future.

Alabama Power continues to focus on several key performance indicators including, but not limited to, customer satisfaction, plant availability, system reliability, and net income after dividends on preferred stock.

RESULTS OF OPERATIONS

Net Income

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(8)	(3.6)

Alabama Power's net income after dividends on preferred stock for the first quarter 2019 was $217 million compared to $225 million for the corresponding period in 2018. This decrease was primarily related to a decrease in retail revenues associated with milder weather and lower customer usage and an increase in non-fuel operations and maintenance expenses. These decreases to income were partially offset by an increase in retail revenues under Rate CNP Compliance associated with increases in average net investments and a decrease in income tax expense associated with the application in 2018 of the accounting order approved by the Alabama PSC in May 2018 related to the Tax Reform Legislation (Tax Reform Accounting Order). See Note 2 to the financial statements under "Alabama Power – Tax Reform Accounting Order" in Item 8 of the Form 10-K for additional information.

Retail Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(72)	(5.6)

In the first quarter 2019, retail revenues were $1.21 billion compared to $1.29 billion for the corresponding period in 2018.

50

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Details of the changes in retail revenues were as follows:

	First Quarter 2019
	(in millions)			(% change)
Retail – prior year	$	1,285
Estimated change resulting from –
Rates and pricing	34			2.6
Sales decline	(17		)	(1.3	)
Weather	(25		)	(1.9	)
Fuel and other cost recovery	(64		)	(5.0	)
Retail – current year	$	1,213		(5.6	)%

Revenues associated with changes in rates and pricing increased in the first quarter 2019 when compared to the corresponding period in 2018 primarily due to increased revenues under Rate CNP Compliance associated with increases in average net investments. 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 quarter2019 when compared to the corresponding period in 2018. Weather-adjusted commercial KWH sales decreased 3.5% in the first quarter2019 and weather-adjusted residential KWH sales decreased 2.3% in the first quarter2019 when compared to the corresponding period in 2018 primarily due to lower customer usage resulting from customer initiatives in energy savings for commercial customers and lower usage due to more energy-efficient residential appliances. Industrial KWH sales decreased 3.0% in the first quarter2019 when compared to the corresponding period in 2018 as a result of a decrease in demand resulting from changes in production levels primarily in the primary metals, chemicals, and paper sectors, partially offset by increased demand in the pipeline sector.

Revenues resulting from changes in weather decreased in the first quarter2019 due to milder weather. In the first quarter2019, the resulting decreases were 3.3% and 1.7% for residential and commercial sales revenues, respectively.

Fuel and other cost recovery revenues decreased in the first quarter2019 when compared to the corresponding period in 2018 primarily due to a decrease in generation.

Electric rates include provisions to recognize the full recovery of fuel costs, purchased power costs, PPAs certificated by the Alabama PSC, and costs associated with the natural disaster reserve. 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 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(13)	(17.6)

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 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.

51

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

In the first quarter 2019, wholesale revenues from sales to non-affiliates were $61 million compared to $74 million for the corresponding period in 2018. The decrease was primarily due to a 10.1% decrease in the price of energy due to lower natural gas prices and a 9.4% decrease in KWH sales as a result of lower demand in the first quarter 2019 compared to the corresponding period in 2018.

Wholesale Revenues – Affiliates

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$9	17.6

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

In the first quarter 2019, wholesale revenues from sales to affiliates were $60 million compared to $51 million for the corresponding period in 2018. The increase was primarily due to a 33.4% increase in KWH sales partially offset by a 12.6% decrease in the price of energy due to increased hydro generation in the first quarter 2019 as compared to the corresponding period in 2018.

Other Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$11	17.5

In the first quarter 2019, other revenues were $74 million compared to $63 million for the corresponding period in 2018. This increase was primarily due to an increase in OATT revenues and opportunity sales of natural gas.

Fuel and Purchased Power Expenses

	First Quarter 2019 vs. First Quarter 2018
	(change in millions)			(% change)
Fuel	$	(25	)	(7.7	)
Purchased power – non-affiliates	(27		)	(42.2	)
Purchased power – affiliates	(16		)	(43.2	)
Total fuel and purchased power expenses	$	(68	)

In the first quarter 2019, fuel and purchased power expenses were $359 million compared to $427 million for the corresponding period in 2018. The decrease was primarily due to a $53 million decrease related to the volume of KWHs generated (excluding hydro) and purchased and a $14 million decrease in the average cost of 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.

52

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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

	First Quarter 2019	First Quarter 2018
Total generation (in billions of KWHs)	16	16
Total purchased power (in billions of KWHs)	1	1
Sources of generation (percent) —
Coal	43	50
Nuclear	23	23
Gas	19	18
Hydro	15	9
Cost of fuel, generated (in cents per net KWH)—
Coal	2.78	2.69
Nuclear	0.78	0.75
Gas	2.57	2.87
Average cost of fuel, generated (in cents per net KWH)(a)	2.19	2.23
Average cost of purchased power (in cents per net KWH)(b)	5.75	7.10

(a) KWHs generated by hydro are excluded from the average cost of fuel, generated.

(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 2019, fuel expense was $301 million compared to $326 million for the corresponding period in 2018. The decrease was primarily due to a 79.7% increase in the volume of KWHs generated by hydro, a 12.7% decrease in the volume of KWHs generated by coal, and a 10.5% decrease in the average cost of natural gas per KWH generated, which excludes fuel associated with tolling agreements. The decrease was partially offset by a 4.6% increase in the volume of KWHs generated by natural gas and a 3.4% increase in the average cost of coal per KWH generated.

Purchased Power – Non-Affiliates

In the first quarter 2019, purchased power expense from non-affiliates was $37 million compared to $64 million for the corresponding period in 2018. The decrease was primarily related to a 28.3% decrease in the average cost of purchased power per KWH due to lower natural gas prices and a 19.7% decrease in the amount of energy purchased due to milder weather in the first quarter 2019 compared to the corresponding period in 2018.

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 service territory, and the availability of the Southern Company system's generation.

Purchased Power – Affiliates

In the first quarter 2019, purchased power expense from affiliates was $21 million compared to $37 million for the corresponding period in 2018. The decrease was primarily related to a 48.6% decrease in the amount of energy purchased due to increased hydro generation, partially offset by an 11.4% increase in the average cost of purchased power per KWH as a result of firm transportation costs.

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.

53

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Other Operations and Maintenance Expenses

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$22	5.7

In the first quarter 2019, other operations and maintenance expenses were $409 million compared to $387 million for the corresponding period in 2018. This increase was primarily due to increases of $8 million in environmental expenses, $6 million in certain compensation and benefit expenses, and $4 million in nuclear generation expenses primarily due to plant improvement projects.

Depreciation and Amortization

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$10	5.3

In the first quarter 2019, depreciation and amortization was $199 million compared to $189 million for the corresponding period in 2018. This increase was primarily due to additional plant in service associated with compliance-related steam, distribution, and transmission.

Other Income (Expense), Net

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$9	180.0

In the first quarter 2019, other income (expense), net was $14 million compared to $5 million for the corresponding period in 2018. This increase was primarily due to an increase in interest income from temporary cash investments and additional sales of non-utility property in 2019.

Income Taxes

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(20)	(24.4)

In the first quarter 2019, income taxes were $62 million compared to $82 million for the corresponding period in 2018. This decrease was primarily due to lower pre-tax earnings in the first quarter 2019 compared to the corresponding period in 2018 and the application of the Tax Reform Accounting Order in 2018. See Note 2 to the financial statements under "Alabama Power – Tax Reform Accounting Order" in Item 8 of the Form 10-K for additional information.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Alabama Power's future earnings potential. The level of Alabama Power's future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Alabama Power's primary business of providing electric service. These factors include Alabama Power's ability to maintain a constructive regulatory environment that continues to allow for the timely recovery of prudently-incurred costs during a time of increasing costs and the weak pace of growth in new customers and electricity use per customer, especially in residential and commercial markets. Earnings 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, both of

54

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

which could contribute to a net reduction in customer usage. Earnings are subject to a variety of other factors. These factors include weather, competition, new energy contracts with other utilities, energy conservation practiced by customers, the use of alternative energy sources by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth or decline in Alabama Power's service territory. Demand for electricity is primarily driven by the pace of economic growth that may be affected by changes in regional and global economic conditions, which may impact future earnings. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL of Alabama Power in Item 7 of the Form 10-K.

Environmental Matters

Alabama Power's operations are regulated by state and federal environmental agencies through a variety of laws and regulations governing air, water, land, and protection of other natural resources. Alabama Power maintains comprehensive environmental compliance and GHG strategies to assess upcoming requirements and compliance costs associated with these environmental laws and regulations. The costs, including capital expenditures, operations and maintenance costs, and costs reflected in ARO liabilities, required to comply with environmental laws and regulations and to achieve stated goals may impact future electric generating unit retirement and replacement decisions, results of operations, cash flows, and/or financial condition. Related costs may result from the installation of additional environmental controls, closure and monitoring of CCR facilities, unit retirements, or changing fuel sources for certain existing units, as well as related upgrades to Alabama Power's transmission and distribution systems. A major portion of these costs is expected to be recovered through existing ratemaking provisions. The ultimate impact of environmental laws and regulations and GHG goals will depend on various factors, such as state adoption and implementation of requirements, the availability and cost of any deployed technology, fuel prices, and the outcome of pending and/or future legal challenges.

New or revised environmental laws and regulations could affect many areas of Alabama Power's operations. The impact of any such changes cannot be determined at this time. Environmental compliance costs could affect earnings if such costs cannot continue to be recovered in rates on a timely basis. Environmental compliance costs are recovered through Rate CNP Compliance. Further, increased costs that are recovered through regulated rates could contribute to reduced demand for electricity, which could negatively affect results of operations, cash flows, and/or financial condition. Additionally, many commercial and industrial customers may also be affected by existing and future environmental requirements, which for some may have the potential to ultimately affect their demand for electricity. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" of Alabama Power in Item 7 of the Form 10-K and Note 2 to the financial statements under "Alabama Power – Rate CNP Compliance" and Note 3 to the financial statements under "Environmental Remediation" in Item 8 of the Form 10-K for additional information.

FERC Matters

See Note 2 to the financial statements under "FERC Matters – Open Access Transmission Tariff" in Item 8 of the Form 10-K for additional information.

On March 25, 2019, the Alabama Municipal Electric Authority and Cooperative Energy and SCS and the traditional electric operating companies (including Alabama Power) filed a formal settlement agreement with the FERC agreeing to a rate reduction based on a 10.6% ROE, with a retroactive effective date of May 10, 2018, and a five-year moratorium on these parties seeking changes to the OATT formula rate. The ultimate outcome of this matter cannot be determined at this time; however, if approved by the FERC as filed, the OATT settlement would not have a material impact on the financial statements of Alabama Power.

Retail Regulatory Matters

Alabama Power's revenues from regulated retail operations are collected through various rate mechanisms subject to the oversight of the Alabama PSC. Alabama Power currently recovers its costs from the regulated retail business primarily through Rate RSE, Rate CNP, Rate ECR, and Rate NDR. In addition, the Alabama PSC issues accounting

55

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

orders to address current events impacting Alabama Power. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein for additional information regarding Alabama Power's rate mechanisms, accounting orders, and the recovery balance of each regulatory clause for Alabama Power.

Environmental Accounting Order

In connection with management's decision to retire Plant Gorgas, in February 2019, Alabama Power reclassified approximately $1.3 billion for Plant Gorgas Unit 10 from plant in service, net of depreciation to other utility plant, net and continued to depreciate the asset according to the original depreciation rates. On April 15, 2019, Alabama Power retired Plant Gorgas Units 8, 9, and 10 and reclassified approximately $740 million of the remaining net investment costs of the units to a regulatory asset to be recovered over the units' remaining useful lives as established prior to the decision to retire. Additionally, approximately $700 million of net capitalized asset retirement costs will be reclassified to a regulatory asset and recovered in accordance with accounting guidance provided by the Alabama PSC. See Note 2 to the financial statements under "Alabama Power – Environmental Accounting Order" and Note 6 in Item 8 of the Form 10-K for additional information.

Other Matters

Alabama Power is involved in various other matters that could affect future earnings, including matters being litigated and regulatory matters. In addition, Alabama Power is subject to certain claims and legal actions arising in the ordinary course of business. Alabama Power's business activities are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of other natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO₂ and other emissions, CCR, and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters.

The ultimate outcome of such pending or potential litigation or regulatory matters cannot be predicted at this time; however, for current proceedings not specifically reported 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 would have a material effect on Alabama Power's financial statements. See Notes (B) and (C) to the Condensed Financial Statements herein for a discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Alabama Power prepares its financial statements in accordance with GAAP. Significant accounting policies are described in Notes 1, 5, and 6 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 Alabama Power's results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES – "Application of Critical Accounting Policies and Estimates" of Alabama Power in Item 7 of the Form 10-K for a complete discussion of Alabama Power's critical accounting policies and estimates.

Recently Issued Accounting Standards

See Note (A) to the Condensed Financial Statements herein for information regarding Alabama Power's recently adopted accounting standards.

56

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" of Alabama Power in Item 7 of the Form 10-K for additional information. Alabama Power's financial condition remained stable at March 31, 2019. Alabama Power intends to continue to monitor its access to short-term and long-term capital markets as well as its bank credit arrangements to meet future capital and liquidity needs. See "Capital Requirements and Contractual Obligations," "Sources of Capital," and "Financing Activities" herein for additional information.

Net cash provided from operating activities totaled $146 million for the first three months of 2019, a decrease of $9 million as compared to the first three months of 2018. The decrease in net cash provided from operating activities was primarily due to timing of vendor payments and other current liabilities, partially offset by increased fuel cost recovery. Net cash used for investing activities totaled $511 million for the first three months of 2019 primarily related to additional capital expenditures for distribution, environmental, and transmission assets. Net cash provided from financing activities totaled $811 million for the first three months of 2019 primarily due to capital contributions from Southern Company, partially offset by a payment of common stock dividends and a long-term debt maturity. Fluctuations in cash flows from financing activities vary from period to period based on capital needs and the maturity or redemption of securities.

Significant balance sheet changes for the first three months of 2019 include increases of $1.2 billion in total common stockholder's equity, primarily due to a $1.225 billion capital contribution from Southern Company, and $446 million in cash and cash equivalents. Other significant changes include decreases of $268 million in other accounts payable primarily due to the timing of vendor payments and $200 million in securities due within one year due to the maturity of long-term debt.

Capital Requirements and Contractual Obligations

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" of Alabama Power in Item 7 of the Form 10-K for a description of Alabama Power's capital requirements and contractual obligations. There are no scheduled maturities of long-term debt through March 31, 2020.

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" of Alabama Power in Item 7 of the Form 10-K for additional information on Alabama Power's environmental compliance strategy.

The construction program is 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 generating plants, including unit retirements and replacements and adding or changing fuel sources at existing generating units, to meet regulatory requirements; changes in the expected environmental compliance program; changes in FERC rules and regulations; Alabama PSC approvals; changes in legislation; the cost and efficiency of construction labor, equipment, and materials; project scope and design changes; storm impacts; and the cost of capital. In addition, there can be no assurance that costs related to capital expenditures will be fully recovered.

Sources of Capital

Alabama Power plans to obtain the funds to meet its future capital needs from sources similar to those used in the past, which were primarily from operating cash flows, external security issuances, borrowings from financial institutions, and equity contributions from Southern Company. However, the amount, type, and timing of any future financings, if needed, will depend upon prevailing market conditions, regulatory approval, and other factors. In January 2019, Alabama Power received a capital contribution totaling $1.225 billion from Southern Company. See

57

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" of Alabama Power in Item 7 of the Form 10-K for additional information.

Alabama Power's current liabilities sometimes exceed 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.

At March 31, 2019, Alabama Power had approximately $759 million of cash and cash equivalents. Committed credit arrangements with banks at March 31, 2019 were as follows:

Expires
2019		2020		2022		Total		Unused
(in millions)
$	33	$	500	$	800	$	1,333	$	1,333

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

Most of these bank credit arrangements, as well as Alabama Power's term loan arrangements, contain covenants that limit debt levels and contain cross-acceleration provisions to other indebtedness (including guarantee obligations) of Alabama Power. Such cross-acceleration provisions to other indebtedness would trigger an event of default if Alabama Power defaulted on indebtedness, the payment of which was then accelerated. At March 31, 2019, Alabama Power was in compliance with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowings.

Subject to applicable market conditions, Alabama Power expects to renew or replace its bank credit arrangements as needed prior to expiration. In connection therewith, Alabama Power 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 Alabama Power's pollution control revenue bonds and commercial paper programs. The amount of variable rate pollution control revenue bonds outstanding requiring liquidity support was approximately $854 million as of March 31, 2019. At March 31, 2019, Alabama Power had $87 million of fixed rate pollution control revenue bonds outstanding that were required to be reoffered within the next 12 months.

Alabama Power also has substantial cash flow from operating activities and access to the capital markets, including a commercial paper program, to meet liquidity needs. Alabama Power may meet short-term cash needs through its commercial paper program. Alabama Power may also meet short-term cash needs through a Southern Company subsidiary organized to issue and sell commercial paper at the request and for the benefit of Alabama Power and the other traditional electric operating companies. Proceeds from such issuances for the benefit of Alabama Power are loaned directly to Alabama Power. The obligations of each traditional electric operating company under these arrangements are several and there is no cross-affiliate credit support. Short-term borrowings are included in notes payable in the balance sheets.

Details of short-term borrowings were as follows:

	Short-term Debt During the Period(*)
	Average Amount Outstanding		Weighted Average Interest Rate		Maximum Amount Outstanding
	(in millions)				(in millions)
Commercial paper	$	32	2.7	%	$	185

(*) Average and maximum amounts are based upon daily balances during the three-month period ended March 31, 2019. No short-term debt was outstanding at March 31, 2019.

58

ALABAMA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Alabama Power believes the need for working capital can be adequately met by utilizing commercial paper programs, lines of credit, and operating cash flows.

Credit Rating Risk

At March 31, 2019, Alabama Power 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 to BBB and/or Baa2 or below. These contracts are primarily for physical electricity purchases, fuel purchases, fuel transportation and storage, energy price risk management, and transmission. At March 31, 2019, the maximum potential collateral requirements at a rating below BBB- and/or Baa3 totaled approximately $354 million.

Included in these amounts are certain agreements that could require collateral in the event that either Alabama Power or Georgia Power (an affiliate of Alabama 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 Alabama Power to access capital markets and would be likely to impact the cost at which it does so.

As a result of the Tax Reform Legislation, certain financial metrics, such as the funds from operations to debt percentage, used by the credit rating agencies to assess Southern Company and its subsidiaries, including Alabama Power, may be negatively impacted. The modifications to Rate RSE and other commitments approved by the Alabama PSC are expected to help mitigate these potential adverse impacts to certain credit metrics and will help Alabama Power meet its goal of achieving an equity ratio of approximately 55% by the end of 2025. See Note 2 to the financial statements under "Alabama Power – Rate RSE" in Item 8 of the Form 10-K for additional information.

Financing Activities

In February 2019, Alabama Power repaid at maturity $200 million aggregate principal amount of Series Z 5.125% Senior Notes due February 15, 2019.

In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Alabama Power plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

59

GEORGIA POWER COMPANY

60

GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Revenues:
Retail revenues	$	1,668		$	1,798
Wholesale revenues, non-affiliates	29			44
Wholesale revenues, affiliates	3			10
Other revenues	133			109
Total operating revenues	1,833			1,961
Operating Expenses:
Fuel	299			412
Purchased power, non-affiliates	118			121
Purchased power, affiliates	176			171
Other operations and maintenance	446			408
Depreciation and amortization	240			228
Taxes other than income taxes	106			108
Total operating expenses	1,385			1,448
Operating Income	448			513
Other Income and (Expense):
Interest expense, net of amounts capitalized	(96		)	(106		)
Other income (expense), net	40			38
Total other income and (expense)	(56		)	(68		)
Earnings Before Income Taxes	392			445
Income taxes	81			93
Net Income	$	311		$	352

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019		2018
	(in millions)
Net Income	$	311	$	352
Other comprehensive income (loss):
Qualifying hedges:
Reclassification adjustment for amounts included in net income, net of tax of $- and $-, respectively	1		1
Total other comprehensive income (loss)	1		1
Comprehensive Income	$	312	$	353

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

61

GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Activities:
Net income	$	311		$	352
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	287			280
Deferred income taxes	127			(38		)
Pension, postretirement, and other employee benefits	(35		)	(19		)
Settlement of asset retirement obligations	(34		)	(23		)
Other, net	(18		)	28
Changes in certain current assets and liabilities —
-Receivables	91			135
-Fossil fuel stock	(41		)	24
-Prepaid income taxes	(73		)	84
-Other current assets	33			9
-Accounts payable	(166		)	(180		)
-Accrued taxes	(245		)	(191		)
-Accrued compensation	(67		)	(85		)
-Other current liabilities	42			(3		)
Net cash provided from operating activities	212			373
Investing Activities:
Property additions	(875		)	(681		)
Nuclear decommissioning trust fund purchases	(129		)	(255		)
Nuclear decommissioning trust fund sales	124			250
Cost of removal, net of salvage	(58		)	(26		)
Change in construction payables, net of joint owner portion	(38		)	(47		)
Payments pursuant to LTSAs	(2		)	(43		)
Proceeds from asset dispositions	7			134
Other investing activities	(9		)	—
Net cash used for investing activities	(980		)	(668		)
Financing Activities:
Decrease in notes payable, net	(19		)	—
Proceeds —
FFB loan	835			—
Pollution control revenue bonds	343			—
Capital contributions from parent company	27			1,474
Redemptions and repurchases —
Pollution control revenue bonds	(108		)	(278		)
Short-term borrowings	—			(150		)
Other long-term debt	—			(100		)
Payment of common stock dividends	(394		)	(339		)
Other financing activities	(19		)	(6		)
Net cash provided from financing activities	665			601
Net Change in Cash, Cash Equivalents, and Restricted Cash	(103		)	306
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	112			852
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	9		$	1,158
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $8 and $6 capitalized for 2019 and 2018, respectively)	$	92		$	115
Noncash transactions — Accrued property additions at end of period	607			525

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

62

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2019			At December 31, 2018
	(in millions)
Current Assets:
Cash and cash equivalents	$	9		$	4
Restricted cash and cash equivalents	—			108
Receivables —
Customer accounts receivable	550			591
Unbilled revenues	179			208
Under recovered fuel clause revenues	73			115
Joint owner accounts receivable	170			170
Affiliated	21			39
Other accounts and notes receivable	241			80
Accumulated provision for uncollectible accounts	(2		)	(2		)
Fossil fuel stock	272			231
Materials and supplies	504			519
Prepaid expenses	193			142
Other regulatory assets	210			199
Other current assets	48			70
Total current assets	2,468			2,474
Property, Plant, and Equipment:
In service	38,015			37,675
Less: Accumulated provision for depreciation	12,210			12,096
Plant in service, net of depreciation	25,805			25,579
Nuclear fuel, at amortized cost	565			550
Construction work in progress	5,298			4,833
Total property, plant, and equipment	31,668			30,962
Other Property and Investments:
Equity investments in unconsolidated subsidiaries	50			51
Nuclear decommissioning trusts, at fair value	942			873
Miscellaneous property and investments	73			72
Total other property and investments	1,065			996
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,519			—
Deferred charges related to income taxes	518			517
Other regulatory assets, deferred	4,921			4,902
Other deferred charges and assets	379			514
Total deferred charges and other assets	7,337			5,933
Total Assets	$	42,538		$	40,365

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

63

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2019		At December 31, 2018
	(in millions)
Current Liabilities:
Securities due within one year	$	973	$	617
Notes payable	275		294
Accounts payable —
Affiliated	448		575
Other	827		890
Customer deposits	278		276
Accrued taxes	132		377
Accrued interest	103		105
Accrued compensation	112		221
Asset retirement obligations	221		202
Other regulatory liabilities	197		169
Other current liabilities	305		183
Total current liabilities	3,871		3,909
Long-term Debt	10,108		9,364
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,192		3,062
Deferred credits related to income taxes	3,079		3,080
Accumulated deferred ITCs	259		262
Employee benefit obligations	567		599
Operating lease obligations	1,404		—
Asset retirement obligations, deferred	5,634		5,627
Other deferred credits and liabilities	155		139
Total deferred credits and other liabilities	14,290		12,769
Total Liabilities	28,269		26,042
Common Stockholder's Equity (See accompanying statements)	14,269		14,323
Total Liabilities and Stockholder's Equity	$	42,538	$	40,365

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

64

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, 2017	9	$	398	$	7,328		$	4,215		$	(10	)	$	11,931
Net income	—	—		—			352			—			352
Capital contributions from parent company	—	—		1,476			—			—			1,476
Other comprehensive income (loss)	—	—		—			—			1			1
Cash dividends on common stock	—	—		—			(339		)	—			(339		)
Other	—	—		1			—			(2		)	(1		)
Balance at March 31, 2018	9	$	398	$	8,805		$	4,228		$	(11	)	$	13,420
Balance at December 31, 2018	9	$	398	$	10,322		$	3,612		$	(9	)	$	14,323
Net income	—	—		—			311			—			311
Capital contributions from parent company	—	—		29			—			—			29
Other comprehensive income (loss)	—	—		—			—			1			1
Cash dividends on common stock	—	—		—			(394		)	—			(394		)
Other	—	—		(1		)	—			—			(1		)
Balance at March 31, 2019	9	$	398	$	10,350		$	3,529		$	(8	)	$	14,269

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

65

GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2019 vs. FIRST QUARTER 2018

OVERVIEW

Georgia Power operates as a vertically integrated utility providing electric service to retail customers within its traditional service territory located within the State of Georgia and to wholesale customers in the Southeast.

Many factors affect the opportunities, challenges, and risks of Georgia Power's business of providing electric service. These factors include the ability to maintain a constructive regulatory environment, to maintain and grow energy sales and customers, and to effectively manage and secure timely recovery of costs. These costs include those related to projected long-term demand growth, stringent environmental standards, including CCR rules, reliability, fuel, capital expenditures, including new generating facilities and expanding and improving transmission and distribution facilities, and restoration following major storms. Georgia Power has various regulatory mechanisms that operate to address cost recovery. Effectively operating pursuant to these regulatory mechanisms and appropriately balancing required costs and capital expenditures with customer prices will continue to challenge Georgia Power for the foreseeable future. Georgia Power is required to file a base rate case by July 1, 2019.

Georgia Power continues to focus on several key performance indicators, including, but not limited to, customer satisfaction, plant availability, system reliability, the execution of major construction projects, and net income.

Plant Vogtle Units 3 and 4 Status

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4 (with electric generating capacity of approximately 1,100 MWs each). Georgia Power holds a 45.7% ownership interest in Plant Vogtle Units 3 and 4. In March 2017, the EPC Contractor filed for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code. In December 2017, the Georgia PSC approved Georgia Power's recommendation to continue construction. The current expected in-service dates remain November 2021 for Unit 3 and November 2022 for Unit 4.

In the second quarter 2018, Georgia Power revised its base capital cost forecast and estimated contingency to complete construction and start-up of Plant Vogtle Units 3 and 4 to $8.0 billion and $0.4 billion, respectively, for a total project capital cost forecast of $8.4 billion (net of $1.7 billion received under the Guarantee Settlement Agreement and approximately $188 million in related Customer Refunds), with respect to Georgia Power's ownership interest.

As a result of the increase in the total project capital cost forecast and Georgia Power's decision not to seek rate recovery of the increase in the base capital costs, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 were required to vote to continue construction. In September 2018, the Vogtle Owners unanimously voted to continue construction of Plant Vogtle Units 3 and 4. In connection with the vote to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and certain of MEAG's wholly-owned subsidiaries, including MEAG Power SPVJ, LLC (MEAG SPVJ), to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners and (ii) a term sheet (MEAG Term Sheet) with MEAG and MEAG SPVJ to provide funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. On January 14, 2019, Georgia Power, MEAG, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. On February 18, 2019, Georgia Power, the other Vogtle Owners, and certain of MEAG's wholly-owned subsidiaries entered into certain amendments to their joint ownership agreements to implement the provisions of the Vogtle Owner Term Sheet.

In April 2019, Southern Nuclear completed a cost and schedule validation process to verify and update quantities of commodities remaining to install, labor hours to install remaining quantities and related productivity, testing and system turnover requirements, and forecasted staffing needs and related costs. This process confirmed the total estimated project capital cost forecast for Plant Vogtle Units 3 and 4. The expected in-service dates of November 2021 for Unit 3 and November 2022 for Unit 4, as previously approved by the Georgia PSC, remain unchanged.

66

GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

In March 2019, Georgia Power entered into the Amended and Restated Loan Guarantee Agreement with the DOE, 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, up to approximately $5.130 billion. At March 31, 2019, Georgia Power had a total of $3.46 billion of borrowings outstanding under the related multi-advance credit facilities.

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

See FUTURE EARNINGS POTENTIAL – "Retail Regulatory Matters – Nuclear Construction" and Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information.

RESULTS OF OPERATIONS

Net Income

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(41)	(11.6)

In the first quarter 2019, net income was $311 million compared to $352 million for the corresponding period in 2018. The decrease was primarily due to a decrease in retail revenues largely due to milder weather compared to the corresponding period in 2018 and higher non-fuel operations and maintenance expenses.

Retail Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(130)	(7.2)

In the first quarter 2019, retail revenues were $1.67 billion compared to $1.80 billion for the corresponding period in 2018.

Details of the changes in retail revenues were as follows:

	First Quarter 2019
	(in millions)			(% change)
Retail – prior year	$	1,798
Estimated change resulting from –
Rates and pricing	9			0.5
Sales growth	5			0.3
Weather	(57		)	(3.2	)
Fuel cost recovery	(87		)	(4.8	)
Retail – current year	$	1,668		(7.2	)%

Revenues associated with changes in rates and pricing increased in the first quarter2019 when compared to the corresponding period in 2018 primarily due to the rate pricing effect of decreased customer usage and increases in revenues recognized under the NCCR tariff, partially offset by lower contributions from commercial and industrial customers with variable demand-driven pricing. See FUTURE EARNINGS POTENTIAL – "Retail Regulatory Matters – Nuclear Construction – Regulatory Matters" herein for additional information related to the NCCR tariff.

Revenues attributable to changes in sales increased in the first quarter2019 when compared to the corresponding period in 2018. Weather-adjusted residential KWH sales increased 2.1% in the first quarter2019 largely due to customer growth. Weather-adjusted commercial KWH sales decreased 1.1% in the first quarter2019 largely due to a

67

GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

decline in average customer usage resulting from an increase in energy saving initiatives, partially offset by customer growth. Weather-adjusted industrial KWH sales were relatively flat in the first quarter2019. The primary drivers were decreases in the textile and stone, clay, and glass sectors, largely offset by increases in the paper, primary and fabricated metal, and chemical sectors.

Fuel revenues and costs are allocated between retail and wholesale jurisdictions. Retail fuel cost recovery revenues decreased in the first quarter2019 when compared to the corresponding period in 2018 primarily due to decreased energy sales driven by milder weather, resulting in lower customer demand, and lower generation costs. Electric rates include provisions to periodically 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 MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Retail Regulatory Matters – Fuel Cost Recovery" of Georgia Power in Item 7 of the Form 10-K for additional information.

Wholesale Revenues – Non-Affiliates

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(15)	(34.1)

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 either on a levelized basis over the appropriate contract period or the 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.

In the first quarter 2019, wholesale revenues from sales to non-affiliates were $29 million compared to $44 million for the corresponding period in 2018. The decrease was due to a decrease in energy revenues primarily due to lower customer demand and scheduled generation outages.

Other Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$24	22.0

In the first quarter 2019, other revenues were $133 million compared to $109 million for the corresponding period in 2018. The increase was primarily due to revenue increases of $11 million from unregulated sales primarily associated with new energy conservation projects, $6 million from OATT sales, and $4 million from solar application fees.

68

GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Fuel and Purchased Power Expenses

	First Quarter 2019 vs. First Quarter 2018
	(change in millions)			(% change)
Fuel	$	(113	)	(27.4	)
Purchased power – non-affiliates	(3		)	(2.5	)
Purchased power – affiliates	5			2.9
Total fuel and purchased power expenses	$	(111	)

In the first quarter 2019, total fuel and purchased power expenses were $593 million compared to $704 million in the corresponding period in 2018. The decrease was primarily due to a $130 million decrease related to the average cost of fuel and purchased power primarily related to lower energy prices and more rainfall for hydro generation, partially offset by a net increase of $19 million related to the volume of KWHs generated and purchased.

Fuel and purchased power energy transactions do not have a significant impact on earnings since these fuel expenses are generally offset by fuel revenues through Georgia Power's fuel cost recovery mechanism. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Retail Regulatory Matters – Fuel Cost Recovery" of Georgia Power in Item 7 of the Form 10-K for additional information.

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

	First Quarter 2019	First Quarter 2018
Total generation (in billions of KWHs)	13	16
Total purchased power (in billions of KWHs)	8	6
Sources of generation (percent) —
Gas	50	44
Coal	18	29
Nuclear	26	24
Hydro	6	3
Cost of fuel, generated (in cents per net KWH)—
Gas	2.59	2.72
Coal	3.23	3.36
Nuclear	0.81	0.82
Average cost of fuel, generated (in cents per net KWH)	2.21	2.43
Average cost of purchased power (in cents per net KWH)(*)	3.94	5.38

(*) 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 2019, fuel expense was $299 million compared to $412 million in the corresponding period in 2018. The decrease was primarily due to a 22.1% decrease in the volume of KWHs generated largely due to scheduled generation outages and milder weather, a 9.1% decrease in the average cost of fuel primarily related to lower natural gas and coal prices, and more rainfall for hydro generation.

Purchased Power – Non-Affiliates

In the first quarter 2019, purchased power expense from non-affiliates was $118 million compared to $121 million in the corresponding period in 2018. The decrease was primarily due to a 32.5% decrease in the average cost per KWH purchased primarily due to lower natural gas and coal prices, largely offset by a 35.2% increase in the volume

69

GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

of KWHs purchased primarily due to scheduled generation outages at Georgia Power-owned generating units. The volume increase also reflects purchases from Gulf Power which were classified as affiliate prior to January 1, 2019. See Note (K) to the Condensed Financial Statements under "Southern Company" herein for information regarding the sale of Gulf Power.

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 2019, purchased power expense from affiliates was $176 million compared to $171 million in the corresponding period in 2018. The increase was primarily due to a 36.0% increase in the volume of KWHs purchased primarily due to scheduled generation outages at Georgia Power-owned generating units, partially offset by a 22.8% decrease in the average cost per KWH purchased primarily resulting from lower natural gas and coal prices. The increase in the volume of KWHs purchased was partially offset by the effect of classifying purchases from Gulf Power as non-affiliate beginning January 1, 2019. See Note (K) to the Condensed Financial Statements under "Southern Company" herein for information regarding the sale of Gulf Power.

Energy purchases from affiliates will vary depending on 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 2019 vs. First Quarter 2018
(change in millions)	(% change)
$38	9.3

In the first quarter 2019, other operations and maintenance expenses were $446 million compared to $408 million in the corresponding period in 2018. The increase was primarily due to increases of $16 million in certain compensation and benefit expenses, $14 million in scheduled generation outage expenses, $9 million of expenses from unregulated sales primarily associated with new energy conservation projects, and $6 million primarily due to the timing of vegetation management and other distribution-related maintenance expenses, partially offset by a decrease of $6 million in customer accounts and sales expenses.

Depreciation and Amortization

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$12	5.3

In the first quarter 2019, depreciation and amortization was $240 million compared to $228 million in the corresponding period in 2018. The increase was primarily due to additional plant in service.

Interest Expense, Net of Amounts Capitalized

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(10)	(9.4)

In the first quarter 2019, interest expense, net of amounts capitalized was $96 million compared to $106 million in the corresponding period in 2018. The decrease was primarily due to a $13 million decrease in interest expense associated with a decrease in outstanding borrowings, partially offset by an increase of $4 million related to PPAs

70

GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

with Southern Power accounted for as finance leases following the adoption of FASB ASC Topic 842, Leases (ASC 842). In prior periods, these expenses were included in purchased power, affiliates. See FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" and "Financing Activities" herein for additional information on borrowings and Note (L) to the Condensed Financial Statements herein for additional information regarding Georgia Power's adoption of ASC 842.

Income Taxes

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(12)	(12.9)

In first quarter 2019, income taxes were $81 million compared to $93 million in the corresponding period in 2018. The decrease was primarily due to lower pre-tax earnings and an increase in state ITCs, partially offset by an adjustment in 2018 related to the Tax Reform Legislation.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Georgia Power's future earnings potential. The level of Georgia Power's future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Georgia Power's business of providing electric service. These factors include Georgia Power's ability to maintain a constructive regulatory environment that continues to allow for the timely recovery of prudently-incurred costs during a time of increasing costs, continued customer growth, and the weak pace of growth in electricity use per customer, especially in residential and commercial markets. Plant Vogtle Units 3 and 4 construction and rate recovery are also major factors. Earnings will also depend upon maintaining and growing sales, considering, among other things, the adoption and/or penetration rates of increasingly energy-efficient technologies, increasing volumes of electronic commerce transactions, and more multi-family home construction, all of which could contribute to a net reduction in customer usage. Earnings are subject to a variety of other factors. These factors include weather, competition, new energy contracts with other utilities, energy conservation practiced by customers, the use of alternative energy sources by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth or decline in Georgia Power's service territory. Demand for electricity is primarily driven by the pace of economic growth that may be affected by changes in regional and global economic conditions, which may impact future earnings.

For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL of Georgia Power in Item 7 of the Form 10-K.

Environmental Matters

Georgia Power's operations are regulated by state and federal environmental agencies through a variety of laws and regulations governing air, water, land, and protection of other natural resources. Georgia Power maintains comprehensive environmental compliance and GHG strategies to assess upcoming requirements and compliance costs associated with these environmental laws and regulations. The costs, including capital expenditures, operations and maintenance costs, and costs reflected in ARO liabilities, required to comply with environmental laws and regulations and to achieve stated goals may impact future electric generating unit retirement and replacement decisions, results of operations, cash flows, and/or financial condition. Related costs may result from the installation of additional environmental controls, closure and monitoring of CCR facilities, unit retirements, or changing fuel sources for certain existing units, as well as related upgrades to Georgia Power's transmission and distribution systems. A major portion of these costs is expected to be recovered through retail rates. The ultimate impact of environmental laws and regulations and GHG goals will depend on various factors, such as state adoption and implementation of requirements, the availability and cost of any deployed technology, fuel prices, and the outcome of pending and/or future legal challenges.

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New or revised environmental laws and regulations could affect many areas of Georgia Power's operations. The impact of any such changes cannot be determined at this time. Environmental compliance costs could affect earnings if such costs cannot continue to be recovered in rates on a timely basis. Georgia Power's Environmental Compliance Cost Recovery (ECCR) tariff allows for the recovery of capital and operations and maintenance costs related to environmental controls mandated by state and federal regulations. Further, increased costs that are recovered through regulated rates could contribute to reduced demand for electricity, which could negatively affect results of operations, cash flows, and/or financial condition. Additionally, many commercial and industrial customers may also be affected by existing and future environmental requirements, which for some may have the potential to ultimately affect their demand for electricity. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" of Georgia Power in Item 7 and Note 3 to the financial statements under "Environmental Remediation" in Item 8 of the Form 10-K for additional information.

FERC Matters

See Note 2 to the financial statements under "FERC Matters – Open Access Transmission Tariff" in Item 8 of the Form 10-K for additional information.

On March 25, 2019, the Alabama Municipal Electric Authority and Cooperative Energy and SCS and the traditional electric operating companies (including Georgia Power) filed a formal settlement agreement with the FERC agreeing to a rate reduction based on a 10.6% ROE, with a retroactive effective date of May 10, 2018, and a five-year moratorium on these parties seeking changes to the OATT formula rate. The ultimate outcome of this matter cannot be determined at this time; however, if approved by the FERC as filed, the OATT settlement would not have a material impact on the financial statements of Georgia Power.

Retail Regulatory Matters

Georgia Power's revenues from regulated retail operations are collected through various rate mechanisms subject to the oversight of the Georgia PSC. Georgia Power currently recovers its costs from the regulated retail business through the 2013 ARP, which includes traditional base tariff rates, Demand-Side Management tariffs, ECCR tariffs, and Municipal Franchise Fee tariffs. Georgia Power is scheduled to file a base rate case by July 1, 2019, which may continue or modify these tariffs. In addition, financing costs related to certified construction costs of Plant Vogtle Units 3 and 4 are being collected through the NCCR tariff and fuel costs are collected through a separate fuel cost recovery tariff. See Note 2 to the financial statements under "Georgia Power" in Item 8 of the Form 10-K for additional information regarding regulatory matters.

Nuclear Construction

See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information regarding the construction of Plant Vogtle Units 3 and 4, the joint ownership agreements and related funding agreement, VCM reports, and the NCCR tariff.

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4. Georgia Power holds a 45.7% ownership interest in Plant Vogtle Units 3 and 4. 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 March 2017, the EPC Contractor filed for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code. In connection with the EPC Contractor's bankruptcy filing, 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, a cost reimbursable plus fee arrangement, whereby Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, which is 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.

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4 by the expected in-service dates of November 2021 and November 2022, respectively, is as follows:

	(in billions)
Base project capital cost forecast(a)(b)	$	8.0
Construction contingency estimate	0.4
Total project capital cost forecast(a)(b)	8.4
Net investment as of March 31, 2019(b)	(4.9		)
Remaining estimate to complete(a)	$	3.5

(a) Excludes financing costs expected to be capitalized through AFUDC of approximately $325 million.

(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 $3.1 billion, of which $1.9 billion had been incurred through March 31, 2019.

In April 2019, Southern Nuclear completed a cost and schedule validation process to verify and update quantities of commodities remaining to install, labor hours to install remaining quantities and related productivity, testing and system turnover requirements, and forecasted staffing needs and related costs. This process confirmed the total estimated project capital cost forecast for Plant Vogtle Units 3 and 4. The expected in-service dates of November 2021 for Unit 3 and November 2022 for Unit 4, as previously approved by the Georgia PSC, remain unchanged.

As construction continues, challenges with management of contractors, subcontractors, and vendors; supervision of craft labor and related craft labor productivity, ability to attract and retain craft labor, and/or related cost escalation; procurement, fabrication, delivery, assembly, and/or installation and the initial testing and start-up, including any required engineering changes, of plant systems, structures, or components (some of which are based on new technology that only recently began initial operation in the global nuclear industry at this scale), any of which may require additional labor and/or materials; or other issues could arise and change the projected schedule and estimated cost. Monthly construction production targets established as part of a strategy to maintain and build margin to the approved in-service dates will continue to increase significantly throughout 2019. To meet these increasing monthly targets, existing craft construction productivity must improve and additional craft laborers must be retained and deployed.

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 assure compliance with the requirements specified in the Westinghouse Design Control Document and the combined

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construction and operating licenses, including inspections by Southern Nuclear and the NRC that occur throughout construction. As a result of such compliance processes, certain license amendment requests have been filed and approved or are pending before the NRC. Various design and other licensing-based compliance matters, including the timely resolution of ITAAC and the related approvals by the NRC, may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues 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 regulatory-approved project schedule is currently estimated to result in additional base capital costs of approximately $50 million per month, based on Georgia Power's ownership interests, and AFUDC of approximately $12 million per month. While Georgia Power is not precluded from seeking recovery of any future capital cost forecast increase, 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.

As a result of the increase in the total project capital cost forecast and Georgia Power's decision not to seek rate recovery of the increase in the base capital costs in conjunction with the nineteenth VCM report, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 were required to vote to continue construction. In September 2018, the Vogtle Owners unanimously voted to continue construction of Plant Vogtle Units 3 and 4.

Amendments to the Vogtle Joint Ownership Agreements

In connection with the vote to continue construction, Georgia Power entered into (i) the Vogtle Owner Term Sheet with the other Vogtle Owners and MEAG's wholly-owned subsidiaries 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) the MEAG Term Sheet with MEAG and MEAG SPVJ to provide funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. On January 14, 2019, Georgia Power, MEAG, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. On February 18, 2019, Georgia Power, the other Vogtle Owners, and MEAG'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.

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

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applicable certified costs through annual adjustments to the NCCR tariff up to the certified capital cost of $4.418 billion. At March 31, 2019, Georgia Power had recovered approximately $1.9 billion of financing costs. Financing costs related to capital costs above $4.418 billion will be recovered through AFUDC; however, Georgia Power will not record 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 2018, the Georgia PSC approved Georgia Power's request to increase the NCCR tariff by $88 million annually, effective January 1, 2019.

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 amounts 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 prudence decisions on cost recovery will be made at a later date, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 ARP) 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 upon Unit 3 reaching commercial operation, retail base rates would be adjusted to include carrying costs on those capital costs deemed prudent in the Vogtle Cost Settlement Agreement. 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 $100 million in 2018 and are estimated to have negative earnings impacts of approximately $75 million in 2019 and an aggregate of approximately $635 million from 2020 to 2022.

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 February 2018, Georgia Interfaith Power & Light, Inc. (GIPL) and Partnership for Southern Equity, Inc. (PSE) filed a petition appealing the Georgia PSC's January 11, 2018 order with the Fulton County Superior Court. In March 2018, Georgia Watch filed a similar appeal to the Fulton County Superior Court for judicial review of the Georgia PSC's decision and denial of Georgia Watch's motion for reconsideration. In December 2018, the Fulton County Superior Court granted Georgia Power's motion to dismiss the two appeals. On January 9, 2019, GIPL, PSE, and Georgia Watch filed an appeal of this decision with the Georgia Court of Appeals. Georgia Power believes the

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appeal has no merit; however, an adverse outcome in the appeal combined with subsequent adverse action by the Georgia PSC could have a material impact on Georgia Power's results of operations, financial condition, and liquidity.

In August 2018, Georgia Power filed its nineteenth VCM report with the Georgia PSC, which requested approval of $578 million of construction capital costs incurred from January 1, 2018 through June 30, 2018. On February 19, 2019, the Georgia PSC approved the nineteenth VCM, but deferred approval of $51.6 million of expenditures related to Georgia Power's portion of an administrative claim filed in the Westinghouse bankruptcy proceedings. Through the nineteenth VCM, the Georgia PSC has approved total construction capital costs incurred through June 30, 2018 of $5.4 billion (before $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related Customer Refunds). In addition, the staff of the Georgia PSC requested, and Georgia Power agreed, to report the results of the cost and schedule validation process to the Georgia PSC (which is expected to occur by May 1, 2019) and to file its twentieth VCM report concurrently with the twenty-first VCM report by August 31, 2019.

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

See RISK FACTORS of Georgia Power in the Form 10-K for a discussion of certain risks associated with the licensing, construction, and operation of nuclear generating units, including potential impacts that could result from a major incident at a nuclear facility anywhere in the world.

DOE Financing

At March 31, 2019, Georgia Power had borrowed $3.46 billion related to Plant Vogtle Units 3 and 4 costs as provided through the Amended and Restated Loan Guarantee Agreement and related multi-advance credit facilities among Georgia Power, the DOE, and the FFB, which provide for borrowings of up to approximately $5.130 billion, subject to the satisfaction of certain conditions. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information, including applicable covenants, events of default, mandatory prepayment events, and conditions to borrowing.

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

Other Matters

Georgia Power is involved in various other matters that could affect future earnings, including matters being litigated and regulatory matters. In addition, Georgia Power is subject to certain claims and legal actions arising in the ordinary course of business. Georgia Power's business activities are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of other natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO₂ and other emissions, CCR, and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters.

The ultimate outcome of such pending or potential litigation or regulatory matters cannot be predicted at this time; however, for current proceedings not specifically reported 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 would have a material effect on Georgia Power's financial statements. See Notes (B) and (C) to the Condensed Financial Statements herein for a discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

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ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Georgia Power prepares its financial statements in accordance with GAAP. Significant accounting policies are described in Notes 1, 5, and 6 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 Georgia Power's results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES – "Application of Critical Accounting Policies and Estimates" of Georgia Power in Item 7 of the Form 10-K for a complete discussion of Georgia Power's critical accounting policies and estimates.

Recently Issued Accounting Standards

See Note (A) to the Condensed Financial Statements herein for information regarding Georgia Power's recently adopted accounting standards.

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" of Georgia Power in Item 7 of the Form 10-K for additional information. Georgia Power's financial condition remained stable at March 31, 2019. Georgia Power intends to continue to monitor its access to short-term and long-term capital markets as well as bank credit agreements to meet future capital and liquidity needs. See "Capital Requirements and Contractual Obligations," "Sources of Capital," and "Financing Activities" herein for additional information.

Net cash provided from operating activities totaled $212 million for the first three months of 2019 compared to $373 million for the corresponding period in 2018. The decrease was primarily due to the timing of fossil fuel stock purchases and higher payments for property taxes and municipal franchise fees. Net cash used for investing activities totaled $980 million for the first three months of 2019 primarily related to installation of equipment to comply with environmental standards and construction of generation, transmission, and distribution facilities, including approximately $360 million related to the construction of Plant Vogtle Units 3 and 4. Net cash provided from financing activities totaled $665 million for the first three months of 2019 primarily due to borrowings from the FFB for construction of Plant Vogtle Units 3 and 4 and the reoffering of pollution control revenue bonds, partially offset by payment of common stock dividends and the redemption of pollution control revenue bonds. Cash flows from financing activities vary from period to period based on capital needs and the maturity or redemption of securities.

Significant balance sheet changes for the first three months of 2019 include recording $1.5 billion in operating lease right-of-use assets, net of amortization and $1.5 billion in operating lease obligations related to the adoption of ASC 842, an increase of $1.1 billion in long-term debt (including securities due within one year) primarily due to borrowings from the FFB for construction of Plant Vogtle Units 3 and 4 and the reoffering of pollution control revenue bonds previously purchased and held by Georgia Power, and an increase of $0.7 billion in property, plant, and equipment to comply with environmental standards and the construction of generation, transmission, and distribution facilities. See Note (L) to the Condensed Financial Statements herein for additional information on the adoption of ASC 842. Also see Notes (B) and (F) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" and "DOE Loan Guarantee Borrowings," respectively, herein for additional information regarding Plant Vogtle Units 3 and 4 and the related Amended and Restated Loan Guarantee Agreement.

Capital Requirements and Contractual Obligations

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" of Georgia Power in Item 7 of the Form 10-K for a description

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of Georgia Power's capital requirements and contractual obligations. Approximately $973 million will be required through March 31, 2020 to fund maturities of long-term debt. See "Sources of Capital" herein for additional information. Also see FUTURE EARNINGS POTENTIAL – "Retail Regulatory Matters – Nuclear Construction" for additional information regarding Plant Vogtle Units 3 and 4.

The construction program is 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 generating plants, including unit retirements and replacements and adding or changing fuel sources at existing generating units, to meet regulatory requirements; changes in FERC rules and regulations; Georgia PSC approvals; changes in the expected environmental compliance program; changes in legislation; the cost and efficiency of construction labor, equipment, and materials; project scope and design changes; storm impacts; and the cost of capital. In addition, there can be no assurance that costs related to capital expenditures will be fully recovered. The construction program also includes Plant Vogtle Units 3 and 4, which includes components based on new technology that only recently began initial operation in the global nuclear industry at this scale and which may be subject to additional revised cost estimates during construction. The ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of new facilities is subject to a number of factors, including, but not limited to, changes in labor costs, availability, and productivity; challenges with management of contractors, subcontractors, or vendors; adverse weather conditions; shortages, increased costs, or inconsistent quality of equipment, materials, and labor; contractor or supplier delay; non-performance under construction, operating, or other agreements; operational readiness, including specialized operator training and required site safety programs; engineering or design problems; design and other licensing-based compliance matters, including the timely resolution of ITAAC and the related approvals by the NRC; challenges with start-up activities, including major equipment failure and system integration; and/or operational performance. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for information regarding additional factors that may impact construction expenditures.

Sources of Capital

Georgia Power plans to obtain the funds required for construction and other purposes from sources similar to those used in the past, which were primarily from operating cash flows, external security issuances, borrowings from financial institutions, equity contributions from Southern Company, and borrowings from the FFB. However, the amount, type, and timing of any future financings, if needed, will depend upon regulatory approvals, prevailing market conditions, and other factors. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" of Georgia Power in Item 7 of the Form 10-K for additional information.

In 2014, Georgia Power entered into a loan guarantee agreement with the DOE and, in March 2019, entered into the Amended and Restated Loan Guarantee Agreement, 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.

Under the Amended and Restated Loan Guarantee Agreement, the DOE has agreed to guarantee the obligations of Georgia Power under note purchase agreements among the DOE, Georgia Power, and the FFB and related promissory notes which provide for two multi-advance term loan facilities (FFB Credit Facilities). Under the FFB Credit Facilities, Georgia Power may make term loan borrowings through the FFB in an amount up to approximately$5.130 billion, provided that total aggregate borrowings under the FFB Credit Facilities may not exceed 70% of (i) Eligible Project Costs minus (ii) approximately $1.492 billion (reflecting the amounts received by Georgia Power under the Guarantee Settlement Agreement less the Customer Refunds).At March 31, 2019, Georgia Power had borrowed $3.46 billion under the FFB Credit Facilities.

See Note (F) to the Condensed Financial Statements under "DOE Loan Guarantee Borrowings" herein for additional information regarding the Amended and Restated Loan Guarantee Agreement, including applicable covenants,

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events of default, mandatory prepayment events, and additional conditions to borrowing. Also see Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information regarding Plant Vogtle Units 3 and 4.

Georgia Power's current liabilities frequently exceed current assets because of scheduled maturities of long-term debt and the periodic use of short-term debt as a funding source, as well as significant seasonal fluctuations in cash needs. At March 31, 2019, Georgia Power's current liabilities exceeded current assets by $1.4 billion primarily due to long-term debt that is due within one year of $973 million and notes payable of $275 million.

At March 31, 2019, Georgia Power had approximately $9 million of cash and cash equivalents. Georgia Power's committed credit arrangement with banks was $1.75 billion at March 31, 2019, of which $1.74 billion was unused. This credit arrangement expires in 2022.

This bank credit arrangement contains a covenant that limits debt levels and contains a cross-acceleration provision to other indebtedness (including guarantee obligations) of Georgia Power. Such cross-acceleration provision to other indebtedness would trigger an event of default if Georgia Power defaulted on indebtedness, the payment of which was then accelerated. At March 31, 2019, Georgia Power was in compliance with this covenant. This bank credit arrangement does not contain a material adverse change clause at the time of borrowing.

Subject to applicable market conditions, Georgia Power expects to renew or replace this credit arrangement as needed prior to expiration. In connection therewith, Georgia Power may extend the maturity date and/or increase or decrease the lending commitments thereunder.

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

A portion of the $1.74 billion unused credit with banks is allocated to provide liquidity support to Georgia Power's pollution control revenue bonds and commercial paper program. The amount of variable rate pollution control revenue bonds outstanding requiring liquidity support as of March 31, 2019 was approximately $550 million. In addition, at March 31, 2019, Georgia Power had $345 million of pollution control revenue bonds outstanding that were required to be remarketed within the next 12 months. Subsequent to March 31, 2019, Georgia Power purchased and held approximately $115 million of outstanding pollution control revenue bonds required to be remarketed.

Georgia Power may also meet short-term cash needs through a Southern Company subsidiary organized to issue and sell commercial paper at the request and for the benefit of Georgia Power and the other traditional electric operating companies. Proceeds from such issuances for the benefit of Georgia Power are loaned directly to Georgia Power. The obligations of each traditional electric operating company under these arrangements are several and there is no cross-affiliate credit support. Short-term borrowings are included in notes payable in the balance sheets.

Details of short-term borrowings were as follows:

	Short-term Debt at March 31, 2019				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)
Commercial paper	$	275	2.8	%	$	437	2.9	%	$	935

(*) Average and maximum amounts are based upon daily balances during the three-month period ended March 31, 2019.

Georgia Power believes the need for working capital can be adequately met by utilizing the commercial paper program, lines of credit, short-term bank notes, and operating cash flows.

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GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Credit Rating Risk

At March 31, 2019, Georgia Power 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 to BBB- and/or Baa3 or below. These contracts are for physical electricity purchases and sales, fuel purchases, fuel transportation and storage, energy price risk management, transmission, interest rate management, and construction of new generation at Plant Vogtle Units 3 and 4.

The maximum potential collateral requirements under these contracts at March 31, 2019 were as follows:

Credit Ratings	Maximum Potential Collateral Requirements
	(in millions)
At BBB- and/or Baa3	$	92
Below BBB- and/or Baa3	$	1,102

Included in these amounts are certain agreements that could require collateral in the event that Georgia Power or Alabama Power (an affiliate of 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 Georgia Power to access capital markets and would be likely to impact the cost at which it does so.

As a result of the Tax Reform Legislation, certain financial metrics, such as the funds from operations to debt percentage, used by the credit rating agencies to assess Southern Company and its subsidiaries, including Georgia Power, may be negatively impacted. A settlement agreement between Georgia Power and the staff of the Georgia PSC regarding the retail rate impact of the Tax Reform Legislation, as approved by the Georgia PSC on April 3, 2018, is expected to help mitigate these potential adverse impacts to certain credit metrics by allowing a higher retail equity ratio until the conclusion of Georgia Power's next base rate case, which is scheduled to be filed by July 1, 2019. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Financing Activities

In January 2019, Georgia Power redeemed approximately $13 million, $20 million, and $75 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 1992, Eighth Series 1994, and Second Series 1995, respectively.

In March 2019, Georgia Power made additional borrowings under the FFB Credit Facilities in an aggregate principal amount of $835 million at an interest rate of 3.213% through the final maturity date of February 20, 2044. The proceeds were used to reimburse Georgia Power for Eligible Project Costs relating to the construction of Plant Vogtle Units 3 and 4.

Also in March 2019, Georgia Power reoffered to the public the following pollution control revenue bonds that previously had been purchased and held by Georgia Power:

• $173 million aggregate principal amount of Development Authority of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Bowen Project), First Series 2009;

• approximately $105 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 2013; and

• $65 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 2008.

80

GEORGIA POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Subsequent to March 31, 2019, Georgia Power purchased and held the following pollution control revenue bonds, which may be reoffered to the public at a later date:

• $55 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1994;

• $30 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1995;

• $20 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Ninth Series 1994; and

• $10 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 1994.

In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Georgia Power plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

81

MISSISSIPPI POWER COMPANY

82

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF OPERATIONS (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Revenues:
Retail revenues	$	203		$	194
Wholesale revenues, non-affiliates	57			68
Wholesale revenues, affiliates	22			34
Other revenues	5			6
Total operating revenues	287			302
Operating Expenses:
Fuel	93			98
Purchased power	3			9
Other operations and maintenance	59			75
Depreciation and amortization	48			41
Taxes other than income taxes	26			28
Estimated loss on Kemper IGCC	2			44
Total operating expenses	231			295
Operating Income (Loss)	56			7
Other Income and (Expense):
Interest expense, net of amounts capitalized	(17		)	(19		)
Other income (expense), net	5			1
Total other income and (expense)	(12		)	(18		)
Earnings (Loss) Before Income Taxes	44			(11		)
Income taxes (benefit)	7			(4		)
Net Income (Loss)	$	37		$	(7	)

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (UNAUDITED)

	For the Three Months Ended March 31,
	2019		2018
	(in millions)
Net Income (Loss)	$	37	$	(7	)
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $- and $(1), respectively	—		(1		)
Total other comprehensive income (loss)	—		(1		)
Comprehensive Income (Loss)	$	37	$	(8	)

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

83

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Activities:
Net income (loss)	$	37		$	(7	)
Adjustments to reconcile net income (loss) to net cash used for operating activities —
Depreciation and amortization, total	50			44
Deferred income taxes	(8		)	155
Estimated loss on Kemper IGCC	6			37
Other, net	(10		)	3
Changes in certain current assets and liabilities —
-Receivables	11			(129		)
-Other current assets	7			(12		)
-Accounts payable	(38		)	(21		)
-Accrued taxes	(62		)	(110		)
-Accrued compensation	(22		)	(22		)
-Other current liabilities	6			—
Net cash used for operating activities	(23		)	(62		)
Investing Activities:
Property additions	(45		)	(33		)
Construction payables	(8		)	(2		)
Other investing activities	(10		)	(17		)
Net cash used for investing activities	(63		)	(52		)
Financing Activities:
Decrease in notes payable, net	—			(4		)
Proceeds —
Senior notes	—			600
Short-term borrowings	—			300
Pollution control revenue bonds	43			—
Redemptions — Other long-term debt	—			(900		)
Return of capital	(38		)	—
Other financing activities	—			(5		)
Net cash provided from (used for) financing activities	5			(9		)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(81		)	(123		)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	293			248
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	212		$	125
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $- and $- capitalized for 2019 and 2018, respectively)	$	13		$	21
Income taxes, net	—			19
Noncash transactions — Accrued property additions at end of period	27			30

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

84

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2019		At December 31, 2018
	(in millions)
Current Assets:
Cash and cash equivalents	$	212	$	293
Receivables —
Customer accounts receivable	29		34
Unbilled revenues	37		41
Affiliated	16		21
Other accounts and notes receivable	36		31
Fossil fuel stock	23		20
Materials and supplies	52		53
Other regulatory assets	102		116
Other current assets	6		19
Total current assets	513		628
Property, Plant, and Equipment:
In service	4,821		4,900
Less: Accumulated provision for depreciation	1,467		1,429
Plant in service, net of depreciation	3,354		3,471
Construction work in progress	110		103
Total property, plant, and equipment	3,464		3,574
Other Property and Investments	123		24
Deferred Charges and Other Assets:
Deferred charges related to income taxes	33		33
Other regulatory assets, deferred	487		474
Accumulated deferred income taxes	148		150
Other deferred charges and assets	17		3
Total deferred charges and other assets	685		660
Total Assets	$	4,785	$	4,886

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

85

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2019		At December 31, 2018
	(in millions)
Current Liabilities:
Securities due within one year	$	339	$	40
Accounts payable —
Affiliated	52		60
Other	50		90
Accrued taxes	33		95
Accrued interest	20		15
Accrued compensation	16		38
Accrued plant closure costs	26		29
Asset retirement obligations	28		34
Over recovered regulatory clause liabilities	14		14
Other current liabilities	55		40
Total current liabilities	633		455
Long-term Debt	1,280		1,539
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	373		378
Deferred credits related to income taxes	367		382
Employee benefit obligations	111		115
Asset retirement obligations, deferred	127		126
Other cost of removal obligations	186		185
Other regulatory liabilities, deferred	80		81
Other deferred credits and liabilities	18		16
Total deferred credits and other liabilities	1,262		1,283
Total Liabilities	3,175		3,277
Common Stockholder's Equity (See accompanying statements)	1,610		1,609
Total Liabilities and Stockholder's Equity	$	4,785	$	4,886

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

86

MISSISSIPPI 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, 2017	1	$	38	$	4,529		$	(3,205	)	$	(4	)	$	1,358
Net loss after dividends on preferred stock	—	—		—			(7		)	—			(7		)
Capital contributions from parent company	—	—		2			—			—			2
Other comprehensive income (loss)	—	—		—			—			(1		)	(1		)
Other	—	—		—			(1		)	—			(1		)
Balance at March 31, 2018	1	$	38	$	4,531		$	(3,213	)	$	(5	)	$	1,351
Balance at December 31, 2018	1	$	38	$	4,546		$	(2,971	)	$	(4	)	$	1,609
Net income	—	—		—			37			—			37
Return of capital to parent company	—	—		(38		)	—			—			(38		)
Capital contributions from parent company	—	—		2			—			—			2
Balance at March 31, 2019	1	$	38	$	4,510		$	(2,934	)	$	(4	)	$	1,610

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

87

MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2019 vs. FIRST QUARTER 2018

OVERVIEW

Mississippi Power operates as a vertically integrated utility providing electric service to retail customers within its traditional service territory located within the State of Mississippi and to wholesale customers in the Southeast.

Many factors affect the opportunities, challenges, and risks of Mississippi Power's business of providing electric service. These factors include Mississippi Power's ability to maintain and grow energy sales and number of customers and to operate in a constructive regulatory environment that provides timely recovery of prudently-incurred costs. These costs include those related to projected long-term demand growth, stringent environmental standards, including CCR rules, reliability, fuel, capital and operations and maintenance expenditures, including expanding and improving transmission and distribution facilities, and restoration following major storms. Appropriately balancing required costs and capital expenditures with customer prices will continue to challenge Mississippi Power for the foreseeable future. Mississippi Power is scheduled to file a base rate case in the fourth quarter 2019 (Mississippi Power 2019 Base Rate Case).

On March 28, 2019, Mississippi Power filed a request with the FERC for a decrease in wholesale base revenues under the MRA tariff as agreed upon in a settlement agreement reached with its wholesale customers resolving all matters related to the Kemper County energy facility similar to the retail rate settlement agreement approved by the Mississippi PSC in February 2018 and reflecting the impacts of the Tax Reform Legislation. The MRA settlement agreement provides that base rates will decrease $3.7 million annually, effective January 1, 2019. Mississippi Power expects the matter to be resolved in the second quarter 2019. The ultimate outcome of this matter cannot be determined at this time. See Note 2 to the financial statements under "FERC Matters" in Item 8 of the Form 10-K for additional information.

Mississippi Power continues to focus on several key performance indicators. In recognition that Mississippi Power's long-term financial success is dependent upon how well it satisfies its customers' needs, Mississippi Power's retail base rate mechanism, PEP, includes performance indicators that directly tie customer service indicators to Mississippi Power's allowed ROE. Mississippi Power also focuses on broader measures of customer satisfaction, plant availability, system reliability, and net income.

RESULTS OF OPERATIONS

Net Income (Loss)

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$44	N/M

N/M - Not meaningful

Mississippi Power's net income for the first quarter 2019 was $37 million compared to a loss of $7 million for the corresponding period in 2018. The increase in net income is primarily attributable to lower charges associated with the Kemper IGCC and a decrease in operations and maintenance expenses.

88

MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Retail Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$9	4.6

In the first quarter 2019, retail revenues were $203 million compared to $194 million for the corresponding period in 2018.

Details of the changes in retail revenues were as follows:

	First Quarter 2019
	(in millions)			(% change)
Retail – prior year	$	194
Estimated change resulting from –
Rates and pricing	15			7.7	%
Sales growth	1			0.5
Weather	(9		)	(4.6	)
Fuel and other cost recovery	2			1.0
Retail – current year	$	203		4.6	%

Revenues associated with changes in rates and pricing increased in the first quarter 2019 when compared to the corresponding period in 2018 primarily due to increases in PEP and ECO Plan rates that became effective for the first billing cycle of September 2018, partially offset by a rate decrease related to the Kemper County energy facility that became effective for the first billing cycle of April 2018 and a new tolling arrangement accounted for as a sales-type lease. See Note 2 to the financial statements under "Mississippi Power – Performance Evaluation Plan," " – Environmental Compliance Overview Plan," and " – Kemper County Energy Facility – Rate Recovery" in Item 8 of the Form 10-K and Note (L) to the Condensed Financial Statements herein for additional information.

Revenues attributable to changes in sales increased in the first quarter 2019 compared to the corresponding period in 2018. Weather-adjusted residential KWH sales increased 1.5% in the first quarter 2019 due to increased customer usage. Weather-adjusted commercial KWH sales decreased 3.4% due to decreased customer usage. Industrial KWH sales decreased 3.9% primarily due to decreased customer usage by several large industrial customers.

Revenues associated with weather decreased in the first quarter2019 compared to the corresponding period in 2018 primarily due to milder weather.

Fuel and other cost recovery revenues increased in the first quarter2019 when compared to the corresponding period in 2018 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.

Wholesale Revenues – Non-Affiliates

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(11)	(16.2)

Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Mississippi Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern

89

MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. In addition, Mississippi Power provides service under long-term contracts with rural electric cooperative associations and municipalities located in southeastern Mississippi under cost-based electric tariffs which are subject to regulation by the FERC. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "FERC Matters" of Mississippi Power in Item 7 of the Form 10-K and FUTURE EARNINGS POTENTIAL – "FERC Matters" herein for additional information.

In the first quarter 2019, wholesale revenues from sales to non-affiliates were $57 million compared to $68 million for the corresponding period in 2018. This decrease primarily resulted from a $6 million decrease due to lower market-based contract capacity and energy sales and fewer opportunity sales and a $5 million decrease in cost-based electric tariff revenues due to decreased customer usage and milder weather.

Wholesale Revenues – Affiliates

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(12)	(35.3)

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

In the first quarter 2019, wholesale revenues from sales to affiliates were $22 million compared to $34 million for the corresponding period in 2018. This decrease was primarily due to a $19 million decrease associated with lower natural gas prices, partially offset by a $7 million increase associated with higher KWH sales due to the dispatch of Mississippi Power's lower cost generation resources to serve the Southern Company system's territorial load.

Fuel and Purchased Power Expenses

	First Quarter 2019 vs. First Quarter 2018
	(change in millions)			(% change)
Fuel	$	(5	)	(5.1)
Purchased power	(6		)	(66.7)
Total fuel and purchased power expenses	$	(11	)

In the first quarter 2019, total fuel and purchased power expenses were $96 million compared to $107 million for the corresponding period in 2018. The decrease was due to lower average costs of natural gas 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.

90

MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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

	First Quarter 2019	First Quarter 2018
Total generation (in millions of KWHs)	3,950	4,003
Total purchased power (in millions of KWHs)	207	194
Sources of generation (percent) –
Coal	4	4
Gas	96	96
Cost of fuel, generated (in cents per net KWH)–
Coal	4.42	3.62
Gas	2.46	2.60
Average cost of fuel, generated (in cents per net KWH)	2.53	2.65
Average cost of purchased power (in cents per net KWH)	1.62	4.74

Fuel

In the first quarter 2019, fuel expense was $93 million compared to $98 million for the corresponding period in 2018. The decrease was primarily due to a 5.6% decrease in the average cost of natural gas.

Purchased Power

In the first quarter 2019, purchased power expense was $3 million compared to $9 million for the corresponding period in 2018. The decrease was primarily due to a 66% decrease in the average cost per KWH purchased as a result of colder weather in the first quarter 2018 as compared to the corresponding period in 2019.

Energy purchases will vary depending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's service territory, and the availability of the Southern Company system's generation. These purchases are made in accordance with the IIC or other contractual agreements, as approved by the FERC.

Other Operations and Maintenance Expenses

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(16)	(21.3)

In the first quarter 2019, other operations and maintenance expenses were $59 million compared to $75 million for the corresponding period in 2018. The decrease was primarily due to decreases of $9 million in generation planned outage expenses and $4 million in employee compensation and benefit expenses related to an employee attrition plan recorded in 2018.

Depreciation and Amortization

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$7	17.1

In the first quarter 2019, depreciation and amortization was $48 million compared to $41 million for the corresponding period in 2018. The increase was primarily related to $6 million of amortization associated with ECO

91

MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Plan regulatory assets. See Note 2 to the financial statements under "Mississippi Power – Environmental Compliance Overview Plan" in Item 8 of the Form 10-K for additional information.

Estimated Loss on Kemper IGCC

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(42)	(95.5)

In the first quarter 2019, estimated losses on the Kemper IGCC were $2 million compared to $44 million for the corresponding period in 2018, resulting from lower charges related to abandonment and closure activities for the mine and gasifier-related assets recorded in 2019 as compared to the corresponding period in 2018.

See Note 2 to the financial statements under "Mississippi Power – Kemper County Energy Facility" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Mississippi Power – Kemper County Energy Facility" herein for additional information.

Other Income (Expense), Net

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$4	N/M

N/M - Not meaningful

In the first quarter 2019, other income (expense), net was $5 million compared to $1 million for the corresponding period in 2018. The increase was primarily due to higher interest income associated with a new tolling arrangement accounted for as a lease. See Note (L) to the Condensed Financial Statements herein for additional information.

Income Taxes (Benefit)

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$11	275.0

In the first quarter 2019, income taxes were $7 million compared to an income tax benefit of $4 million for the corresponding period in 2018. This change was primarily due to higher pre-tax earnings primarily due to lower estimated losses on the Kemper IGCC, partially offset by an increase in the flowback of excess deferred income taxes as a result of a settlement agreement reached with wholesale customers under the MRA tariff. See Note (B) to the Condensed Financial Statements under "Mississippi Power" herein for additional information.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Mississippi Power's future earnings potential. The level of Mississippi Power's future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Mississippi Power's business of providing electric service. These factors include Mississippi Power's ability to recover its prudently-incurred costs in a timely manner during a time of increasing costs and its ability to prevail against legal challenges associated with the Kemper County energy facility. Future earnings will be driven primarily by continued customer growth and the weak pace of growth in electricity use per customer, especially in residential and commercial markets. Earnings 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, both of which could contribute to a net reduction in customer usage. Earnings are subject to a variety of other factors. These factors include weather, competition, developing new and maintaining existing energy contracts and associated load requirements

92

MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

with other utilities and other wholesale customers, energy conservation practiced by customers, the use of alternative energy sources by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth or decline in Mississippi Power's service territory. Demand for electricity is primarily driven by the pace of economic growth that may be affected by changes in regional and global economic conditions, which may impact future earnings.

For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL of Mississippi Power in Item 7 of the Form 10-K.

Environmental Matters

Mississippi Power's operations are regulated by state and federal environmental agencies through a variety of laws and regulations governing air, water, land, and protection of other natural resources. Mississippi Power maintains comprehensive environmental compliance and GHG strategies to assess upcoming requirements and compliance costs associated with these environmental laws and regulations. The costs, including capital expenditures, operations and maintenance costs, and costs reflected in ARO liabilities, required to comply with environmental laws and regulations and to achieve stated goals may impact future electric generating unit retirement and replacement decisions, results of operations, cash flows, and/or financial condition. Related costs may result from the installation of additional environmental controls, closure and monitoring of CCR facilities, unit retirements, or changing fuel sources for certain existing units, as well as related upgrades to Mississippi Power's transmission and distribution systems. A major portion of these costs is expected to be recovered through retail and wholesale rates. The ultimate impact of environmental laws and regulations and GHG goals will depend on various factors, such as state adoption and implementation of requirements, the availability and cost of any deployed technology, fuel prices, and the outcome of pending and/or future legal challenges.

New or revised environmental laws and regulations could affect many areas of Mississippi Power's operations. The impact of any such changes cannot be determined at this time. Environmental compliance costs could affect earnings if such costs cannot continue to be recovered in rates on a timely basis or through long-term wholesale agreements. Further, increased costs that are recovered through regulated rates could contribute to reduced demand for electricity, which could negatively affect results of operations, cash flows, and/or financial condition. Additionally, many commercial and industrial customers may also be affected by existing and future environmental requirements, which for some may have the potential to ultimately affect their demand for electricity. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" of Mississippi Power in Item 7 and Note 3 to the financial statements under "Environmental Matters" in Item 8 of the Form 10-K for additional information.

FERC Matters

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

Municipal and Rural Association Tariff

On March 28, 2019, Mississippi Power filed a request with the FERC for a decrease in wholesale base revenues under the MRA tariff as agreed upon in a settlement agreement reached with its wholesale customers resolving all matters related to the Kemper County energy facility similar to the retail rate settlement agreement approved by the Mississippi PSC in February 2018 and reflecting the impacts of the Tax Reform Legislation. The MRA settlement agreement provides that base rates will decrease $3.7 million annually, effective January 1, 2019. Mississippi Power expects the matter to be resolved in the second quarter 2019. The ultimate outcome of this matter cannot be determined at this time.

Open Access Transmission Tariff

On March 25, 2019, the Alabama Municipal Electric Authority and Cooperative Energy and SCS and the traditional electric operating companies (including Mississippi Power) filed a formal settlement agreement with the FERC

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MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

agreeing to a rate reduction based on a 10.6% ROE, with a retroactive effective date of May 10, 2018, and a five-year moratorium on these parties seeking changes to the OATT formula rate. The ultimate outcome of this matter cannot be determined at this time; however, if approved by the FERC as filed, the OATT settlement would not have a material impact on the financial statements of Mississippi Power.

Retail Regulatory Matters

Mississippi Power's rates and charges for service to retail customers are subject to the regulatory oversight of the Mississippi PSC. Mississippi Power's rates are a combination of base rates under PEP and several separate cost recovery clauses for specific categories of costs. These separate cost recovery clauses address such items as fuel and purchased power, energy efficiency programs, ad valorem taxes, property damage, and the costs of compliance with environmental laws and regulations. Costs not addressed through one of the specific cost recovery clauses are expected to be recovered through Mississippi Power's base rates. Mississippi Power is scheduled to file a base rate case in the fourth quarter 2019.

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

Kemper County Energy Facility

See Note 2 to the financial statements under "Mississippi Power – Kemper County Energy Facility" in Item 8 of the Form 10-K for additional information.

As the mining permit holder, Liberty Fuels Company, LLC has a legal obligation to perform mine reclamation, and Mississippi Power has a contractual obligation to fund all reclamation activities. As a result of the abandonment of the Kemper IGCC, final mine reclamation began in 2018 and is expected to be substantially completed in 2020, with monitoring expected to continue through 2027. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

During the first quarter 2019, Mississippi Power recorded pre-tax charges to income of $2 million ($1 million after tax), primarily resulting from the abandonment and related closure activities and ongoing period costs, net of sales proceeds, for the mine and gasifier-related assets at the Kemper County energy facility. Additional closure costs for the mine and gasifier-related assets, currently estimated at up to $10 million pre-tax (excluding salvage, net of dismantlement costs), may be incurred through the first half of 2020. In addition, period costs, including, but not limited to, costs for compliance and safety, ARO accretion, and property taxes for the mine and gasifier-related assets, are estimated at $11 million for the remainder of 2019 and $2 million to $6 million annually in 2020 through 2023.

In addition, Mississippi Power constructed the CO₂ pipeline for the planned transport of captured CO₂ for use in enhanced oil recovery and is currently evaluating its options regarding the final disposition of the CO₂ pipeline, including removal of the pipeline. This evaluation is expected to be complete later in 2019. If Mississippi Power ultimately decides to remove the CO₂ pipeline, the cost of removal would have a material impact on Mississippi Power's financial statements.

In December 2018, Mississippi Power filed with the DOE its request for property closeout certification under the contract related to the $387 million of grants received. Mississippi Power and the DOE are currently in discussions regarding the requested closeout and property disposition, which may require payment to the DOE for a portion of certain property that is to be retained by Mississippi Power. In connection with the DOE closeout discussions, on April 29, 2019, the Civil Division of the Department of Justice informed Southern Company and Mississippi Power of an investigation related to the Kemper County energy facility. The ultimate outcome of these matters cannot be determined at this time; however, they could have a material impact on Mississippi Power's financial statements.

Other Matters

Mississippi Power is involved in various other matters that could affect future earnings, including matters being litigated and regulatory matters. In addition, Mississippi Power is subject to certain claims and legal actions arising

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FINANCIAL CONDITION AND RESULTS OF OPERATIONS

in the ordinary course of business. Mississippi Power's business activities are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of other natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO₂ and other emissions, CCR, and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters.

The ultimate outcome of such pending or potential litigation or regulatory matters cannot be predicted at this time; however, for current proceedings not specifically reported 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 would have a material effect on Mississippi Power's financial statements. See Notes (B) and (C) to the Condensed Financial Statements herein for a discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

In conjunction with Southern Company's sale of Gulf Power, Mississippi Power and Gulf Power have committed to seek a restructuring of their 50% undivided ownership interests in Plant Daniel such that each of them would, after the restructuring, own 100% of a generating unit. On January 15, 2019, Gulf Power provided notice to Mississippi Power that Gulf Power will retire its share of the generating capacity of Plant Daniel on January 15, 2024. Mississippi Power has the option to purchase Gulf Power's ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior to that date. Mississippi Power is assessing the potential operational and economic effects of Gulf Power's notice. The ultimate outcome of these matters remains subject to completion of Mississippi Power's evaluations and applicable regulatory approvals, including by the FERC and the Mississippi PSC, and cannot be determined at this time. See Note (K) to the Condensed Financial Statements under "Southern Company" herein for information regarding the sale of Gulf Power.

Litigation

See Note 2 to the financial statements under "Mississippi Power – Kemper County Energy Facility" in Item 8 of the Form 10-K for additional information.

In May 2018, Southern Company and Mississippi Power received a notice of dispute and arbitration demand filed by Martin Product Sales, LLC (Martin) based on two agreements, both related to Kemper IGCC byproducts for which Mississippi Power provided termination notices in 2017. Martin alleges breach of contract, breach of good faith and fair dealing, fraud and misrepresentation, and civil conspiracy and makes a claim for damages in the amount of approximately $143 million, as well as additional unspecified damages, attorney's fees, costs, and interest. In the first quarter 2019, Mississippi Power and Southern Company filed motions to dismiss.

In November 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three current members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi. 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. They also allege that Mississippi Power underpaid customers 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. In response to Mississippi Power and the Mississippi PSC each filing a motion to dismiss, the plaintiffs filed an amended complaint on March 14, 2019. The amended complaint included four additional plaintiffs and additional claims for gross negligence, reckless conduct, and intentional wrongdoing. Mississippi Power and the Mississippi PSC have each filed a motion to dismiss the amended complaint.

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FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Mississippi Power believes these legal challenges have no merit; however, an adverse outcome in either of these proceedings could have a material impact on Mississippi Power's results of operations, financial condition, and liquidity. The ultimate outcome of these matters cannot be determined at this time.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Mississippi Power prepares its financial statements in accordance with GAAP. Significant accounting policies are described in Notes 1, 5, and 6 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 Mississippi Power's results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES – "Application of Critical Accounting Policies and Estimates" of Mississippi Power in Item 7 of the Form 10-K for a complete discussion of Mississippi Power's critical accounting policies and estimates.

Recently Issued Accounting Standards

See Note (A) to the Condensed Financial Statements herein for information regarding Mississippi Power's recently adopted accounting standards.

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" of Mississippi Power in Item 7 of the Form 10-K for additional information.

Mississippi Power's cash requirements primarily consist of funding ongoing operations, common stock dividends, capital expenditures, and debt maturities. Capital expenditures and other investing activities include investments to maintain existing generation facilities, to comply with environmental regulations including adding environmental modifications to certain existing generating units and closures of ash ponds, to expand and improve transmission and distribution facilities, and for restoration following major storms.

Net cash used for operating activities totaled $23 million for the first three months of 2019, a decrease of $39 million as compared to the corresponding period in 2018. The decrease in net cash used for operating activities is primarily related to lower income tax and ad valorem tax payments in 2019. Net cash used for investing activities totaled $63 million for the first three months of 2019 primarily due to gross property additions related to distribution and transmission facilities. Net cash provided from financing activities totaled $5 million for the first three months of 2019 primarily due to $43 million of pollution control revenue bonds reoffered to the public, partially offset by a return of capital to Southern Company. Cash flows from financing activities vary from period to period based on capital needs and the maturity or redemption of securities.

Significant balance sheet changes for the first three months of 2019 include a decrease of $259 million in long-term debt, primarily due to the reclassification of $300 million in unsecured senior notes to securities due within one year, partially offset by $43 million in securities reoffered to the public; a decrease of $62 million in accrued taxes primarily due to the payment of ad valorem taxes; and a decrease of $81 million in cash and cash equivalents. Other significant changes include a decrease of $79 million in plant in service and an increase of $99 million in other property and investments primarily due to a new tolling arrangement, effective January 1, 2019, accounted for as a sales-type lease. See Note (L) to the Condensed Financial Statements herein for additional information.

Capital Requirements and Contractual Obligations

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" of Mississippi Power in Item 7 of the Form 10-K for a description of Mississippi Power's capital requirements and contractual obligations. Approximately $300 million

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MISSISSIPPI POWER COMPANY

MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

will be required through March 31, 2020 to fund maturities of long-term debt. See "Sources of Capital" herein for additional information.

The construction program is 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; storm impacts; changes in environmental laws and regulations; the outcome of any legal challenges to environmental rules; changes in 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; Mississippi PSC approvals; changes in the expected environmental compliance program; changes in legislation; the cost and efficiency of construction labor, equipment, and materials; project scope and design changes; and the cost of capital. In addition, there can be no assurance that costs related to capital expenditures will be fully recovered.

Sources of Capital

Mississippi Power plans to obtain the funds to meet its future capital needs from operating cash flows, external securities issuances, borrowings from financial institutions, including commercial paper to the extent Mississippi Power is eligible to participate, and equity contributions from Southern Company. However, the amount, type, and timing of any future financing, if needed, will depend upon prevailing market conditions, regulatory approval, and other factors. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" in Item 7 of the Form 10-K for additional information.

As of March 31, 2019, Mississippi Power's current liabilities exceeded current assets by approximately $120 million primarily as a result of $339 million of long-term debt that is due within one year.

At March 31, 2019, Mississippi Power had approximately $212 million of cash and cash equivalents. Mississippi Power's committed credit arrangements with banks totaled $100 million at March 31, 2019, all of which was unused. These credit arrangements expire in 2019.

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

All of these bank credit arrangements contain covenants that limit debt levels and typically contain cross-acceleration provisions to other indebtedness (including guarantee obligations) of Mississippi Power. Such cross-acceleration provisions to other indebtedness would trigger an event of default if Mississippi Power defaulted on indebtedness, the payment of which was then accelerated. At March 31, 2019, Mississippi Power was in compliance with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowing.

Subject to applicable market conditions, Mississippi Power expects to renew or replace its credit arrangements as needed, prior to expiration. In connection therewith, Mississippi Power may extend the maturity dates and/or increase or decrease the lending commitments thereunder.

A portion of the $100 million unused credit arrangements with banks is allocated to provide liquidity support to Mississippi Power's variable rate revenue bonds. The amount of variable rate revenue bonds outstanding requiring liquidity support as of March 31, 2019 was approximately $40 million.

Short-term debt, including the average amount and maximum amount outstanding, was immaterial at March 31, 2019 and during the three-month period ended March 31, 2019.

Mississippi Power believes the need for working capital can be adequately met by utilizing lines of credit, short-term bank notes, commercial paper to the extent Mississippi Power is eligible to participate, operating cash flows, and other cash.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Credit Rating Risk

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Credit Rating Risk" of Mississippi Power in Item 7 of the Form 10-K for additional information.

At March 31, 2019, Mississippi Power 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 have required or could require collateral, but not accelerated payment, in the event of a credit rating change to BBB and/or Baa2 or below. These contracts are for physical electricity purchases and sales, fuel transportation and storage, energy price risk management, and transmission. At March 31, 2019, the maximum potential collateral requirements at a rating below BBB- and/or Baa3 equaled approximately $281 million.

Included in these amounts are certain agreements that could require collateral in the event that either Alabama Power or Georgia Power (affiliate companies of Mississippi 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 Mississippi Power to access capital markets and would be likely to impact the cost at which it does so.

As a result of the Tax Reform Legislation, certain financial metrics, such as the funds from operations to debt percentage, used by the credit rating agencies to assess Southern Company and its subsidiaries, including Mississippi Power, may be negatively impacted. The settlement agreement approved by the Mississippi PSC in August 2018 with respect to the 2018 PEP filings and all unresolved PEP filings for prior years is expected to help mitigate these potential adverse impacts by allowing Mississippi Power to retain the excess deferred taxes resulting from the Tax Reform Legislation until the conclusion of the Mississippi Power 2019 Base Rate Case. See Note 2 to the financial statements under "Mississippi Power" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Mississippi Power" herein for additional information.

Financing Activities

In March 2019, Mississippi Power reoffered to the public $43 million of Mississippi Business Finance Corporation Pollution Control Revenue Refunding Bonds, Series 2002, that previously had been purchased and held by Mississippi Power.

In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Mississippi Power plans, when economically feasible, to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

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SOUTHERN POWER COMPANY

AND SUBSIDIARY COMPANIES

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SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Revenues:
Wholesale revenues, non-affiliates	$	352		$	424
Wholesale revenues, affiliates	87			83
Other revenues	4			2
Total operating revenues	443			509
Operating Expenses:
Fuel	145			169
Purchased power	24			61
Other operations and maintenance	84			93
Depreciation and amortization	119			114
Taxes other than income taxes	11			12
Total operating expenses	383			449
Operating Income	60			60
Other Income and (Expense):
Interest expense, net of amounts capitalized	(44		)	(47		)
Other income (expense), net	2			3
Total other income and (expense)	(42		)	(44		)
Earnings Before Income Taxes	18			16
Income taxes (benefit)	(9		)	(99		)
Net Income	27			115
Net loss attributable to noncontrolling interests	(29		)	(6		)
Net Income Attributable to Southern Power	$	56		$	121

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Net Income	$	27		$	115
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(10) and $16, respectively	(29		)	48
Reclassification adjustment for amounts included in net income, net of tax of $8 and $(8), respectively	25			(24		)
Total other comprehensive income (loss)	(4		)	24
Comprehensive Income	23			139
Comprehensive loss attributable to noncontrolling interests	(29		)	(6		)
Comprehensive Income Attributable to Southern Power	$	52		$	145

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

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Activities:
Net income	$	27		$	115
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	125			122
Deferred income taxes	17			(50		)
Amortization of investment tax credits	(14		)	(14		)
Other, net	(7		)	2
Changes in certain current assets and liabilities —
-Receivables	10			48
-Prepaid income taxes	(9		)	(32		)
-Other current assets	3			5
-Accounts payable	(32		)	(43		)
-Accrued compensation	(15		)	(13		)
-Other current liabilities	5			9
Net cash provided from operating activities	110			149
Investing Activities:
Business acquisitions	(2		)	(46		)
Property additions	(66		)	(121		)
Change in construction payables	(7		)	25
Payments pursuant to LTSAs	(15		)	(18		)
Other investing activities	11			7
Net cash used for investing activities	(79		)	(153		)
Financing Activities:
Increase in notes payable, net	5			29
Distributions to noncontrolling interests	(36		)	(13		)
Capital contributions from noncontrolling interests	3			8
Payment of common stock dividends	(51		)	(78		)
Net cash used for financing activities	(79		)	(54		)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(48		)	(58		)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	181			140
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	133		$	82
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $4 and $5 capitalized for 2019 and 2018, respectively)	$	28		$	29
Income taxes, net	1			(39		)
Noncash transactions — Accrued property additions at end of period	19			57

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, 2019		At December 31, 2018
	(in millions)
Current Assets:
Cash and cash equivalents	$	133	$	181
Receivables —
Customer accounts receivable	120		111
Affiliated	33		55
Other	116		116
Materials and supplies	218		220
Prepaid income taxes	1,190		25
Other current assets	37		37
Total current assets	1,847		745
Property, Plant, and Equipment:
In service	13,284		13,271
Less: Accumulated provision for depreciation	2,288		2,171
Plant in service, net of depreciation	10,996		11,100
Construction work in progress	409		430
Total property, plant, and equipment	11,405		11,530
Other Property and Investments:
Intangible assets, net of amortization of $67 and $61 at March 31, 2019 and December 31, 2018, respectively	340		345
Other investments	2		—
Total other property and investments	342		345
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	372		—
Prepaid LTSAs	102		98
Accumulated deferred income taxes	17		1,186
Income taxes receivable, non-current	33		30
Assets held for sale	644		576
Other deferred charges and assets	342		373
Total deferred charges and other assets	1,510		2,263
Total Assets	$	15,104	$	14,883

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)

Liabilities and Stockholders' Equity	At March 31, 2019		At December 31, 2018
	(in millions)
Current Liabilities:
Securities due within one year	$	599	$	599
Notes payable	105		100
Accounts payable —
Affiliated	69		92
Other	66		77
Accrued income taxes	11		6
Accrued interest	44		36
Liabilities held for sale	9		15
Other current liabilities	111		106
Total current liabilities	1,014		1,031
Long-term Debt	4,396		4,418
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	107		105
Accumulated deferred ITCs	1,817		1,832
Operating lease obligations	371		—
Other deferred credits and liabilities	181		213
Total deferred credits and other liabilities	2,476		2,150
Total Liabilities	7,886		7,599
Total Stockholders' Equity (See accompanying statements)	7,218		7,284
Total Liabilities and Stockholders' Equity	$	15,104	$	14,883

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

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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, 2017	$	3,662		$	1,478		$	(2	)	$	5,138		$	1,360		$	6,498
Net income attributable to Southern Power	—			121			—			121			—			121
Capital contributions from parent company	1			—			—			1			—			1
Other comprehensive income (loss)	—			—			24			24			—			24
Cash dividends on common stock	—			(78		)	—			(78		)	—			(78		)
Capital contributions from noncontrolling interests	—			—			—			—			9			9
Distributions to noncontrolling interests	—			—			—			—			(13		)	(13		)
Net income (loss) attributable to noncontrolling interests	—			—			—			—			(6		)	(6		)
Other	—			(2		)	5			3			(1		)	2
Balance at March 31, 2018	$	3,663		$	1,519		$	27		$	5,209		$	1,349		$	6,558
Balance at December 31, 2018	$	1,600		$	1,352		$	16		$	2,968		$	4,316		$	7,284
Net income attributable to Southern Power	—			56			—			56			—			56
Capital contributions from parent company	1			—			—			1			—			1
Other comprehensive income (loss)	—			—			(4		)	(4		)	—			(4		)
Cash dividends on common stock	—			(51		)	—			(51		)	—			(51		)
Capital contributions from noncontrolling interests	—			—			—			—			3			3
Distributions to noncontrolling interests	—			—			—			—			(41		)	(41		)
Net income (loss) attributable to noncontrolling interests	—			—			—			—			(29		)	(29		)
Other	(1		)	(1		)	—			(2		)	1			(1		)
Balance at March 31, 2019	$	1,600		$	1,356		$	12		$	2,968		$	4,250		$	7,218

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

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2019 vs. FIRST QUARTER 2018

OVERVIEW

Southern Power develops, constructs, acquires, owns, and manages power generation assets, including renewable energy projects, and sells electricity at market-based rates in the wholesale market. Southern Power continually seeks opportunities to execute its strategy to create value through various transactions including acquisitions, dispositions, and sales of partnership interests, development and construction of new generating facilities, and entry into PPAs primarily with investor-owned utilities, independent power producers, municipalities, electric cooperatives, and other load-serving entities, as well as commercial and industrial customers. In general, Southern Power commits to the construction or acquisition of new generating capacity only after entering into or assuming long-term PPAs for the new facilities.

During the three months ended March 31, 2019, Southern Power continued construction of the 100-MW Wildhorse Mountain wind facility, the 200-MW Reading wind facility, and the expansion of the 385-MW Mankato natural gas facility. See FUTURE EARNINGS POTENTIAL – "Construction Projects" herein for additional information.

In November 2018, Southern Power entered into an agreement to sell all of its equity interests in Plant Mankato (including the 385-MW expansion currently under construction) for an aggregate purchase price of approximately $650 million. The completion of the disposition is subject to the expansion unit reaching commercial operation as well as various other customary conditions to closing, including FERC and state commission approvals. On April 17, 2019, Southern Power entered into an agreement to sell all of its equity interests in the Nacogdoches biomass-fueled facility to Austin Energy for an aggregate purchase price of $460 million, subject to customary closing conditions and working capital adjustments. Each of these sales is expected to close in mid-2019; however, the ultimate outcome of these matters cannot be determined at this time.

At March 31, 2019, Southern Power's average investment coverage ratio for its generating assets (including Plants Mankato and Nacogdoches), based on the ratio of investment under contract to total investment using the respective generation facilities' net book value (or expected in-service value for facilities under construction) as the investment amount, was 93% through 2023 and 91% through 2028, with an average remaining contract duration of approximately 15 years.

Southern Power continues to focus on several key performance indicators, including, but not limited to, peak season equivalent forced outage rate, contract availability, and net income.

RESULTS OF OPERATIONS

Net Income Attributable to Southern Power

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(65)	(53.7)

Net income attributable to Southern Power for the first quarter 2019 was $56 million compared to $121 million for the corresponding period in 2018. The decrease was primarily due to $50 million in state income tax benefits recorded in 2018 arising from the reorganization of Southern Power's legal entities that own and operate certain solar facilities and a reduction in 2019 of $39 million in PTCs, partially offset by $28 million in HLBV income allocations to Southern Power related to tax equity partnerships entered into in 2018. See Notes 7 and 10 to the financial statements in Item 8 of the Form 10-K for additional information on the legal entity reorganization and the tax equity partnerships, respectively.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Operating Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(66)	(13.0)

Total operating revenues include PPA capacity revenues, which are derived primarily from long-term contracts involving natural gas and biomass generating 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 power pool.

Natural Gas and Biomass Capacity and Energy Revenue

Capacity revenues generally represent the greatest contribution to operating income and are designed to provide recovery of fixed costs plus a return on investment.

Energy is generally sold at variable cost or is indexed to published natural gas indices. Energy revenues will vary depending on the energy demand of Southern Power's customers and their generation capacity, as well as the market prices of wholesale energy compared to the cost of Southern Power's energy. Energy revenues also include fees for support services, fuel storage, and unit start charges. Increases and decreases in energy revenues under PPAs that are driven by fuel or purchased power prices are accompanied by an increase or decrease in fuel and purchased power costs and do not have a significant impact on net income.

Solar and Wind Energy Revenue

Southern Power's energy sales from solar and wind generating facilities are predominantly through long-term PPAs that do not have a capacity charge. 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 – "Power Sales Agreements" herein for additional information regarding Southern Power's PPAs.

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

	First Quarter 2019		First Quarter 2018
	(in millions)
PPA capacity revenues	$	127	$	138
PPA energy revenues	227		254
Total PPA revenues	354		392
Non-PPA revenues	85		115
Other revenues	4		2
Total operating revenues	$	443	$	509

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

In the first quarter 2019, total operating revenues were $443 million, reflecting a $66 million, or 13%, decrease from the corresponding period in 2018. The decrease in operating revenues was primarily due to the following:

• PPA capacity revenues decreased $11 million, or 8%, primarily due to a decrease of $17 million attributable to the sale of Plant Oleander and Plant Stanton Unit A (together, the Florida Plants) in December 2018, partially offset by a $5 million increase in new PPA capacity revenues from existing natural gas facilities.

• PPA energy revenues decreased $27 million, or 11%, primarily due to a $22 million decrease in sales related to natural gas facilities, driven by a $51 million decrease in the average cost of fuel and purchased power, partially offset by a $29 million increase in the volume of KWHs sold due to increased customer load.

• Non-PPA revenues decreased $30 million, or 26%, due to a $21 million decrease in the volume of KWHs sold through short-term sales, primarily due to a reduction in uncovered natural gas capacity, and an $8 million decrease in the market price of energy.

Fuel and Purchased Power Expenses

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

	First Quarter 2019	First Quarter 2018
	(in billions of KWHs)
Generation	10.1	9.8
Purchased power	0.7	0.9
Total generation and purchased power	10.8	10.7
Total generation and purchased power, excluding solar, wind, and tolling agreements	6.6	6.7

Southern Power's PPAs for natural gas and biomass 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 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 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 2019 vs. First Quarter 2018
	(change in millions)			(% change)
Fuel	$	(24	)	(14.2)
Purchased power	(37		)	(60.7)
Total fuel and purchased power expenses	$	(61	)

In the first quarter 2019, total fuel and purchased power expenses decreased $61 million, or 27%, compared to the corresponding period in 2018. Fuel expense decreased $24 million primarily due to a decrease associated with the average cost of fuel per KWH generated. Purchased power expense decreased $37 million primarily due to a $24

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million decrease associated with the average cost of purchased power and a $13 million decrease associated with the volume of KWHs purchased.

Other Operations and Maintenance Expenses

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(9)	(9.7)

In the first quarter 2019, other operations and maintenance expenses were $84 million compared to $93 million for the corresponding period in 2018. The decrease was primarily due to lower scheduled outage and maintenance expenses and the recovery of legal costs related to the Roserock settlement agreement. See Note (C) to the Condensed Financial Statements under "General Litigation Matters – Southern Power" herein for additional information.

Income Taxes (Benefit)

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$90	90.9

In the first quarter 2019, income tax benefit was $9 million compared to $99 million for the corresponding period in 2018. This change was primarily due to $50 million in tax benefits recorded in 2018 related to changes in state apportionment rates following the reorganization of Southern Power's legal entities that own and operate certain solar facilities and a $39 million reduction of tax benefits from wind PTCs primarily as a result of the sale of a noncontrolling tax equity interest in SP Wind. See Note (G) to the Condensed Financial Statements herein for additional information.

Net Loss Attributable to Noncontrolling Interests

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$23	N/M

In the first quarter 2019, net loss attributable to noncontrolling interests was $29 million compared to $6 million for the corresponding period in 2018. The increase was primarily related to tax equity partnerships entered into in 2018. See Note 7 to the financial statements in Item 8 of the Form 10-K under "Southern Power" for additional information.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Southern Power's future earnings potential. Future earnings potential will be impacted by the sales of noncontrolling renewable facility interests and the sale of the Florida Plants in 2018 and the pending dispositions of Plants Mankato and Nacogdoches in 2019. The level of Southern Power's future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Southern Power's competitive wholesale business. These factors include: Southern Power's ability to achieve sales growth while containing costs; regulatory matters; creditworthiness of customers; total generating capacity available in Southern Power's market areas; the successful remarketing of capacity as current contracts expire; and Southern Power's ability to execute its growth strategy through the development or acquisition of renewable facilities and other energy projects.

In November 2018, Southern Power entered into an agreement with Northern States Power to sell all of its equity interests in Plant Mankato (including the 385-MW expansion currently under construction) for an aggregate

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purchase price of approximately $650 million. The completion of the disposition is subject to the expansion unit reaching commercial operation as well as various other customary conditions to closing, including working capital and timing adjustments. This transaction is subject to FERC and state commission approvals. On April 17, 2019, Southern Power entered into an agreement to sell all of its equity interests in the Nacogdoches biomass-fueled facility to Austin Energy for an aggregate purchase price of $460 million, subject to customary closing conditions and working capital adjustments. Each of these sales is expected to close in mid-2019; however, the ultimate outcome of these matters cannot be determined at this time.

Demand for electricity is primarily driven by the pace of economic growth that may be affected by changes in regional and global economic conditions, as well as renewable portfolio standards, which may impact future earnings. Other factors that could influence future earnings include weather, transmission constraints, cost of generation from units within the power pool, and operational limitations. For additional information relating to these factors, see RISK FACTORS in Item 1A and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL of Southern Power in Item 7 of the Form 10-K.

Power Sales Agreements

See BUSINESS – "The Southern Company System – Southern Power" in Item 1 of the Form 10-K for additional information regarding Southern Power's PPAs. Generally, under the solar and wind generation PPAs, the purchasing party retains the right to keep or resell the renewable energy credits.

Environmental Matters

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" of Southern Power in Item 7 of the Form 10-K for information on the development by federal and state environmental regulatory agencies of additional control strategies for emissions of air pollution from industrial sources, including electric generating facilities. Compliance with possible additional federal or state legislation or regulations related to global climate change, air quality, water quality, or other environmental and health concerns could also significantly affect Southern Power. While Southern Power's PPAs generally contain provisions that permit charging the counterparty with some of the new costs incurred as a result of changes in environmental laws and regulations, the full impact of any such legislative or regulatory changes cannot be determined at this time.

Construction Projects

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Acquisitions" and "Construction Projects" of Southern Power in Item 7 of the Form 10-K and FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" herein for additional information.

Construction Projects in Progress

During the three months ended March 31, 2019, Southern Power continued construction of the projects set forth in the table below. Total aggregate construction costs, excluding the acquisition costs, are expected to be between $575 million and $640 million for the Plant Mankato expansion and the Wildhorse Mountain and Reading facilities. At March 31, 2019, total costs of construction incurred for these projects were $347 million and are included in CWIP, except for the Plant Mankato expansion, which is included in assets held for sale in the financial statements. The ultimate outcome of these matters cannot be determined at this time.

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Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	Expected COD	PPA Counterparties	PPA Contract Period
Mankato expansion(a)	Natural Gas	385	Mankato, MN	May 2019	Northern States Power Company	20 years
Wildhorse Mountain(b)	Wind	100	Pushmataha County, OK	Fourth quarter 2019	Arkansas Electric Cooperative	20 years
Reading(c)	Wind	200	Osage and Lyon Counties, KS	Second quarter 2020	Royal Caribbean Cruises LTD	12 years

(a) In November 2018, Southern Power entered into an agreement to sell all of its equity interests in Plant Mankato, including this expansion currently under construction. This transaction is subject to FERC and state commission approvals and is expected to close mid-2019. The ultimate outcome of this matter cannot be determined at this time.

(b) In May 2018, Southern Power purchased 100% of the Wildhorse Mountain facility. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

(c) In August 2018, Southern Power purchased 100% of the membership interests of the Reading facility from the joint development arrangement with Renewable Energy Systems Americas, Inc. described below. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

Development Projects

Southern Power continues to evaluate and refine the deployment of the wind turbine equipment purchased in 2016 and 2017 to potential joint development and construction projects as well as the amount of MW capacity to be constructed. During the three months ended March 31, 2019, approximately $53 million of equipment was marketed for sale and, subsequent to March 31, 2019, was sold. At March 31, 2019, the equipment was classified as held for sale on Southern Power's balance sheet.

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

Other Matters

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Other Matters" and "Power Sales Agreements – General" of Southern Power in Item 7 for additional information.

Southern Power is involved in various other matters that could affect future earnings, including matters being litigated, as well as other regulatory and business matters. In addition, Southern Power is subject to certain claims and legal actions arising in the ordinary course of business. Southern Power's business activities are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of other natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO₂ and other emissions and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters.

The ultimate outcome of such pending or potential litigation, regulatory matters, or other business matters cannot be predicted at this time; however, for current proceedings not specifically reported 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 would have a material effect on Southern Power's financial statements.

Southern Power indirectly owns a 51% membership interest in RE Roserock LLC (Roserock), the owner of the Roserock facility in Pecos County, Texas. Prior to the facility being placed in service in 2016, certain solar panels were damaged during installation by the construction contractor, McCarthy Building Companies, Inc. (McCarthy), and certain solar panels were damaged by a hail event that also occurred during construction. In connection therewith, Southern Power withheld payment of approximately $26 million to the construction contractor, which placed a lien on the Roserock facility for the same amount. In 2017, Roserock filed a lawsuit in the state district

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FINANCIAL CONDITION AND RESULTS OF OPERATIONS

court in Pecos County, Texas against XL Insurance America, Inc. and North American Elite Insurance Company seeking recovery from an insurance policy for damages resulting from the hail event and McCarthy's installation practices. In June 2018, the court granted Roserock's motion for partial summary judgment, finding that the insurers were in breach of contract and in violation of the Texas Insurance Code for failing to pay any monies owed for the hail claim. Separate lawsuits were filed between Roserock and McCarthy, as well as other parties, and that litigation was consolidated in the U.S. District Court for the Western District of Texas. On April 18, 2019, Roserock and the parties to the state and federal lawsuits executed a settlement agreement and mutual release that resolves both lawsuits. Under the agreement, the lawsuits will be dismissed and McCarthy will release its lien following payments of all amounts (which are expected to occur in May 2019). Roserock will pay $26 million to McCarthy that was withheld and included in the original construction costs and will receive funds that will cover all related legal costs and the replacement costs of certain solar panels. In addition, during the first quarter 2019, Roserock received a partial payment of approximately $5 million in insurance proceeds toward the hail event. Any additional funds received in excess of the initial replacement costs are expected to be recognized as a gain when received by Roserock in the second quarter 2019, but are not expected to have a material impact on Southern Power's net income.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Southern Power prepares its consolidated financial statements in accordance with GAAP. Significant accounting policies are described in Notes 1, 4, and 10 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 Southern Power's results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES – "Application of Critical Accounting Policies and Estimates" of Southern Power in Item 7 of the Form 10-K for a complete discussion of Southern Power's critical accounting policies and estimates.

Recently Issued Accounting Standards

See Note (A) to the Condensed Financial Statements herein for information regarding Southern Power's recently adopted accounting standards.

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" of Southern Power in Item 7 of the Form 10-K for additional information. Southern Power's financial condition remained stable at March 31, 2019. Southern Power intends to continue to monitor its access to short-term and long-term capital markets as well as bank credit agreements as needed to meet future capital and liquidity needs. See "Sources of Capital" herein for additional information on lines of credit.

Southern Power also utilizes tax equity partnerships, where the tax partner takes significantly all of the federal tax benefits, as a financing source. These tax equity partnerships are consolidated in Southern Power's financial statements and are accounted for using a HLBV methodology to allocate partnership gains and losses. During the first three months of 2019, Southern Power did not receive any material tax equity funding amounts. See Note 1 to the financial statements under "Hypothetical Liquidation at Book Value" in Item 8 of the Form 10-K for additional information on the HLBV methodology.

Net cash provided from operating activities totaled $110 million for the first three months of 2019 compared to $149 million for the first three months of 2018. The decrease in net cash provided from operating activities was primarily due to a reduction in income tax refunds. Net cash used for investing activities totaled $79 million for the first three months of 2019 primarily due to ongoing construction activities. Net cash used for financing activities

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totaled $79 million for the first three months of 2019 primarily due to payment of a common stock dividend and distributions to noncontrolling interests. Cash flows from financing activities may vary from period to period based on capital needs and the maturity or redemption of securities.

Significant balance sheet changes for the first three months of 2019 include a $1.2 billion increase in prepaid income taxes, with an offsetting $1.2 billion reduction in accumulated deferred income tax assets, due to the expected utilization of tax credits for the 2019 tax year, a $372 million increase in operating lease right-of-use assets along with a corresponding increase in operating lease obligations of $371 million, due to the adoption of ASU No. 2016-02, a $68 million increase in assets held for sale due to wind turbine equipment and the continued construction of the Plant Mankato expansion, and a $66 million decrease in noncontrolling interests primarily due to HLBV income allocations to Southern Power and distributions to partners. See Note (K) under "Southern Power" and Note (L) to the Condensed Financial Statements herein for additional information on the Plant Mankato disposition and ASU No. 2016-02, respectively.

See FUTURE EARNINGS POTENTIAL – "Construction Projects" herein for additional information.

Capital Requirements and Contractual Obligations

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" of Southern Power in Item 7 of the Form 10-K for a description of Southern Power's capital requirements and contractual obligations. Approximately $600 million will be required through March 31, 2020 to fund maturities of long-term debt. See "Sources of Capital" herein for additional information.

Southern Power's construction program includes estimates for potential plant acquisitions and placeholder growth, new construction and development, capital improvements, and work to be performed under LTSAs and is subject to periodic review and revision. Actual construction costs, including acquisitions, may vary from these estimates because of numerous factors such as: changes in business conditions; changes in the expected environmental compliance program; changes in environmental laws and regulations; the outcome of any legal challenges to environmental rules; changes in FERC rules and regulations; changes in load projections; changes in legislation; the cost and efficiency of construction labor, equipment, and materials; project scope and design changes; and the cost of capital. See FUTURE EARNINGS POTENTIAL – "Construction Projects" herein for additional information.

Sources of Capital

Southern Power plans to obtain the funds required for acquisitions, construction, development, debt maturities, and other purposes from operating cash flows, external securities issuances, borrowings from financial institutions, tax equity partnership contributions, divestitures, and equity contributions from Southern Company. However, the amount, type, and timing of any future financings, if needed, will depend upon prevailing market conditions, regulatory approval, and other factors. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" of Southern Power in Item 7 of the Form 10-K for additional information.

Southern Power's current liabilities sometimes exceed current assets due to the use of short-term debt as a funding source and construction payables, as well as fluctuations in cash needs due to seasonality. Southern Power believes the need for working capital can be adequately met by utilizing the commercial paper program, the Facility (as defined below), borrowings from financial institutions, equity contributions from Southern Company, external securities issuances, and operating cash flows.

As of March 31, 2019, Southern Power had cash and cash equivalents of approximately $133 million.

Southern Power's commercial paper program is used to finance acquisition and construction costs related to electric generating facilities and for general corporate purposes, including maturing debt. Commercial paper is included in notes payable on the condensed consolidated balance sheets.

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FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Details of short-term borrowings were as follows:

	Short-term Borrowings at March 31, 2019				Short-term Borrowings 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)
Commercial paper	$	5	2.8	%	$	3	2.7	%	$	45
Short-term loans	100		3.1	%	100		3.1	%	100
Total	$	105	3.1	%	$	103	3.1	%

(*) Average and maximum amounts are based upon daily balances during the three-month period ended March 31, 2019.

At March 31, 2019, Southern Power had a committed credit facility (Facility) of $750 million, of which $9 million has been used for letters of credit and $741 million remains unused. The Facility expires in 2022. Proceeds from the Facility may be used for working capital and general corporate purposes as well as liquidity support for Southern Power's commercial paper program. Subject to applicable market conditions, Southern Power expects to renew or replace the Facility, as needed, prior to expiration. In connection therewith, Southern Power may extend the maturity date and/or increase or decrease the lending commitment thereunder. See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements under "Bank Credit Arrangements" herein for additional information.

The Facility, as well as Southern Power's term loan agreements, contains a covenant that limits the ratio of debt to capitalization (as defined in the Facility) to a maximum of 65% and contains a cross-default provision that is restricted only to indebtedness of Southern Power. For purposes of this definition, debt excludes any project debt incurred by certain subsidiaries of Southern Power to the extent such debt is non-recourse to Southern Power, and capitalization excludes the capital stock or other equity attributable to such subsidiary. Southern Power is currently in compliance with all covenants in the Facility.

Southern Power also has a $120 million continuing letter of credit facility expiring in 2021 for standby letters of credit. At March 31, 2019, $96 million has been used for letters of credit, primarily as credit support for PPA requirements, and $24 million remains unused.

In addition, at March 31, 2019, Southern Power had $103 million of cash collateral posted related to PPA requirements.

Southern Power's subsidiaries do not borrow under the commercial paper program and are not parties to, and do not borrow under, the Facility or the continuing letter of credit facility.

Credit Rating Risk

Southern Power does 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 to BBB and/or Baa2, or below. These contracts are for physical electricity purchases and sales, fuel transportation and storage, energy price risk management, and transmission.

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The maximum potential collateral requirements under these contracts at March 31, 2019 were as follows:

Credit Ratings	Maximum Potential Collateral Requirements
	(in millions)
At BBB and/or Baa2	$	29
At BBB- and/or Baa3	$	339
At BB+ and/or Ba1(*)	$	1,041

(*) Any additional credit rating downgrades at or below BB- and/or Ba3 could increase collateral requirements up to an additional $38 million.

Included in these amounts are certain agreements that could require collateral in the event that either Alabama Power or Georgia Power (affiliate companies of Southern 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 Southern Power to access capital markets and would be likely to impact the cost at which it does so.

In addition, Southern Power has a PPA that could require collateral, but not accelerated payment, in the event of a downgrade of Southern Power's credit. The PPA requires credit assurances without stating a specific credit rating. The amount of collateral required would depend upon actual losses resulting from a credit downgrade.

Financing Activities

Southern Power did not issue or redeem any securities during the three months ended March 31, 2019.

In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Southern Power plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

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AND SUBSIDIARY COMPANIES

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Revenues:
Natural gas revenues (includes revenue taxes of $55 and $51, respectively)	$	1,476		$	1,631
Alternative revenue programs	(2		)	(24		)
Other revenues	—			32
Total operating revenues	1,474			1,639
Operating Expenses:
Cost of natural gas	686			720
Cost of other sales	—			7
Other operations and maintenance	235			276
Depreciation and amortization	118			129
Taxes other than income taxes	82			77
Goodwill impairment	—			42
Total operating expenses	1,121			1,251
Operating Income	353			388
Other Income and (Expense):
Earnings from equity method investments	48			42
Interest expense, net of amounts capitalized	(59		)	(59		)
Other income (expense), net	5			12
Total other income and (expense)	(6		)	(5		)
Earnings Before Income Taxes	347			383
Income taxes	77			104
Net Income	$	270		$	279

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Net Income	$	270		$	279
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $- and $-, respectively	—			1
Reclassification adjustment for amounts included in net income, net of tax of $- and $1, respectively	—			2
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax of $- and $-, respectively	(1		)	(1		)
Total other comprehensive income (loss)	(1		)	2
Comprehensive Income	$	269		$	281

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

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Operating Activities:
Net income	$	270		$	279
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	118			129
Deferred income taxes	42			47
Mark-to-market adjustments	45			(59		)
Goodwill impairment	—			42
Other, net	(20		)	(2		)
Changes in certain current assets and liabilities —
-Receivables	238			175
-Natural gas for sale, net of temporary LIFO liquidation	363			413
-Other current assets	59			35
-Accounts payable	(353		)	(119		)
-Accrued taxes	21			28
-Accrued compensation	(50		)	(38		)
-Other current liabilities	(50		)	48
Net cash provided from operating activities	683			978
Investing Activities:
Property additions	(256		)	(268		)
Cost of removal, net of salvage	(12		)	(14		)
Change in construction payables, net	1			(46		)
Investment in unconsolidated subsidiaries	(10		)	(29		)
Other investing activities	(13		)	(4		)
Net cash used for investing activities	(290		)	(361		)
Financing Activities:
Decrease in notes payable, net	(289		)	(483		)
Payment of common stock dividends	(118		)	(118		)
Other financing activities	5			6
Net cash used for financing activities	(402		)	(595		)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(9		)	22
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	70			78
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	61		$	100
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $2 and $1 capitalized for 2019 and 2018, respectively)	$	55		$	52
Income taxes, net	(1		)	—
Noncash transactions — Accrued property additions at end of period	98			89

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

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CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2019			At December 31, 2018
	(in millions)
Current Assets:
Cash and cash equivalents	$	57		$	64
Receivables —
Energy marketing receivables	529			801
Customer accounts receivable	472			370
Unbilled revenues	179			213
Affiliated	9			11
Other accounts and notes receivable	108			142
Accumulated provision for uncollectible accounts	(27		)	(30		)
Natural gas for sale	189			524
Prepaid expenses	99			118
Assets from risk management activities, net of collateral	108			219
Other regulatory assets	46			73
Other current assets	42			50
Total current assets	1,811			2,555
Property, Plant, and Equipment:
In service	15,417			15,177
Less: Accumulated depreciation	4,466			4,400
Plant in service, net of depreciation	10,951			10,777
Construction work in progress	577			580
Total property, plant, and equipment	11,528			11,357
Other Property and Investments:
Goodwill	5,015			5,015
Equity investments in unconsolidated subsidiaries	1,557			1,538
Other intangible assets, net of amortization of $153 and $145 at March 31, 2019 and December 31, 2018, respectively	93			101
Miscellaneous property and investments	20			20
Total other property and investments	6,685			6,674
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	86			—
Other regulatory assets, deferred	657			669
Other deferred charges and assets	185			193
Total deferred charges and other assets	928			862
Total Assets	$	20,952		$	21,448

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

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CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2019		At December 31, 2018
	(in millions)
Current Liabilities:
Securities due within one year	$	354	$	357
Notes payable	361		650
Energy marketing trade payables	532		856
Accounts payable —
Affiliated	31		45
Other	391		402
Customer deposits	91		133
Accrued taxes —
Accrued income taxes	89		66
Other accrued taxes	72		75
Accrued interest	64		55
Accrued compensation	49		100
Liabilities from risk management activities, net of collateral	26		76
Other regulatory liabilities	86		79
Other current liabilities	160		130
Total current liabilities	2,306		3,024
Long-term Debt	5,574		5,583
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,064		1,016
Deferred credits related to income taxes	926		940
Employee benefit obligations	351		357
Operating lease obligations	71		—
Other cost of removal obligations	1,598		1,585
Accrued environmental remediation	261		268
Other deferred credits and liabilities	63		105
Total deferred credits and other liabilities	4,334		4,271
Total Liabilities	12,214		12,878
Common Stockholder's Equity (See accompanying statements)	8,738		8,570
Total Liabilities and Stockholder's Equity	$	20,952	$	21,448

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

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CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDER'S EQUITY (UNAUDITED)

	Paid-In Capital		Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total
	(in millions)
Balance at December 31, 2017	$	9,214	$	(212	)	$	20		$	9,022
Net income	—		279			—			279
Capital contributions from parent company	14		—			—			14
Other comprehensive income (loss)	—		—			2			2
Cash dividends on common stock	—		(118		)	—			(118		)
Other	—		(4		)	4			—
Balance at March 31, 2018	$	9,228	$	(55	)	$	26		$	9,199
Balance at December 31, 2018	$	8,856	$	(312	)	$	26		$	8,570
Net income	—		270			—			270
Capital contributions from parent company	17		—			—			17
Other comprehensive income (loss)	—		—			(1		)	(1		)
Cash dividends on common stock	—		(118		)	—			(118		)
Balance at March 31, 2019	$	8,873	$	(160	)	$	25		$	8,738

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

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FIRST QUARTER 2019 vs. FIRST QUARTER 2018

OVERVIEW

Southern Company Gas is an energy services holding company whose primary business is the distribution of natural gas through utilities in four states – Nicor Gas in Illinois, Atlanta Gas Light in Georgia, Virginia Natural Gas in Virginia, and Chattanooga Gas in Tennessee. Southern Company Gas is also involved in several other complementary businesses.

Southern Company Gas manages its business through four reportable segments – gas distribution operations, gas pipeline investments, wholesale gas services, and gas marketing services – and one non-reportable segment, all other. See Note (M) to the Condensed Financial Statements herein and "BUSINESS – The Southern Company System – Southern Company Gas" in Item 1 of the Form 10-K for additional information.

Many factors affect the opportunities, challenges, and risks of Southern Company Gas' business. These factors include the ability to maintain safety, to maintain constructive regulatory environments, to maintain and grow natural gas sales and number of customers, and to effectively manage and secure timely recovery of costs. These costs include those related to projected long-term demand growth, environmental standards, safety, reliability, resilience, natural gas, and capital expenditures, including updating and expanding the natural gas distribution systems. The natural gas distribution utilities have various regulatory mechanisms that address cost recovery. Effectively operating pursuant to these regulatory mechanisms and appropriately balancing required costs and capital expenditures with customer prices will continue to challenge Southern Company Gas for the foreseeable future.

Nicor Gas filed a rate case in November 2018 and Atlanta Gas Light is required to file a rate case no later than June 3, 2019. These rate cases are both expected to conclude in 2019. The ultimate outcome of these matters cannot be determined at this time. See FUTURE EARNINGS POTENTIAL – "Regulatory Matters" herein and Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

During 2018, Southern Company Gas completed the following sales, resulting in approximately $2.7 billion in aggregate proceeds.

• On June 4, 2018, Southern Company Gas completed the stock sale of Pivotal Home Solutions to American Water Enterprises LLC.

• On July 1, 2018, a Southern Company Gas subsidiary, Pivotal Utility Holdings, completed the sales of the assets of two of its natural gas distribution utilities, Elizabethtown Gas and Elkton Gas, to South Jersey Industries, Inc.

• On July 29, 2018, Southern Company Gas and its wholly-owned direct subsidiary, NUI Corporation, completed the stock sale of Pivotal Utility Holdings, which primarily consisted of Florida City Gas, to NextEra Energy.

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

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. With the exception of Nicor Gas, Southern Company Gas has various regulatory mechanisms, such as

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weather normalization and straight-fixed-variable rate design, which limit its exposure to weather changes within typical ranges in each of its utilities' respective service territory. However, the operating revenues from utility customers in Illinois and gas marketing services customers primarily in Georgia and Illinois can be impacted by warmer- or colder-than-normal weather. Southern Company Gas utilizes weather hedges to limit the negative income impacts in the event of warmer-than-normal weather, while retaining a significant portion of the positive benefits of colder-than-normal weather for these businesses.

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.

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. Wholesale gas services' physical sales volumes represent the daily average natural gas volumes sold to its customers.

See RESULTS OF OPERATIONS herein for additional information on these operating metrics.

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. Occasionally in the summer, wholesale gas services' operating revenues are impacted due to peak usage by power generators in response to summer energy demands. Southern Company Gas' base operating expenses, excluding cost of natural gas, bad debt expense, and certain incentive compensation costs, are incurred relatively evenly throughout the year. Seasonality also affects the comparison of certain balance sheet items across quarters, including receivables, unbilled revenues, natural gas for sale, and notes payable. However, these items are comparable when reviewing Southern Company Gas' annual results. Operating results for the interim periods presented are not necessarily indicative of annual results and can vary significantly from quarter to quarter.

RESULTS OF OPERATIONS

Net Income

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(9)	(3.2)

In the first quarter 2019, net income was $270 million compared to $279 million for the corresponding period in 2018. Excluding an $8 million net loss in the first quarter 2018 from the Southern Company Gas Dispositions, which includes the related goodwill impairment charge of $42 million recorded in contemplation of the sale of Pivotal Home Solutions, net income decreased $17 million. This decrease was driven by a $57 million decrease at wholesale gas services primarily due to significant natural gas price volatility during the first quarter 2018. Excluding the impacts of the Southern Company Gas Dispositions and wholesale gas services, net income increased $40 million. This increase was primarily due to a $52 million increase in revenues, net of gas costs and other cost recovery, primarily from infrastructure replacement programs and base rate changes as well as colder weather in Illinois in the first quarter 2019 compared to the corresponding period in 2018. Partially offsetting these increases were a $7 million contractor litigation settlement recorded in the first quarter 2018 and increased depreciation and amortization.

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Natural Gas Revenues, including Alternative Revenue Programs

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(133)	(8.3)

In the first quarter 2019, natural gas revenues, including alternative revenue programs, were $1.5 billion compared to $1.6 billion for the corresponding period in 2018.

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

	First Quarter 2019
	(in millions)			(% change)
Natural gas revenues – prior year	$	1,607
Estimated change resulting from –
Infrastructure replacement programs and base rate changes	32			2.0
Gas costs and other cost recovery	62			3.9
Weather	7			0.4
Wholesale gas services	(80		)	(5.0	)
Southern Company Gas Dispositions	(167		)	(10.4	)
Other	13			0.8
Natural gas revenues – current year	$	1,474		(8.3	)%

Revenues from infrastructure replacement programs and base rate changes increased in the first quarter 2019 compared to the corresponding period in 2018 primarily due to a $22 million increase at Nicor Gas and a $9 million increase at Atlanta Gas Light. These amounts include gas distribution operations' continued investments recovered through infrastructure replacement programs and base rate increases as well as the effect of revenues deferred in 2018 as a result of the Tax Reform Legislation. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

Revenues associated with gas costs and other cost recovery increased in the first quarter 2019 compared to the corresponding period in 2018 primarily due to higher natural gas prices and increased volumes of natural gas sold for the remaining four natural gas distribution utilities in the first quarter 2019. 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. See "Cost of Natural Gas" herein for additional information. Revenue impacts from weather and customer growth are described further below.

Revenues increased due to colder weather in Illinois in the first quarter 2019 compared to the corresponding period in 2018. See the weather discussion herein for additional information.

Revenues from wholesale gas services decreased in the first quarter 2019 compared to the corresponding period in 2018 primarily due to decreased commercial activity, partially offset by derivative gains. See "Segment Information – Wholesale Gas Services" herein for additional information.

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During Heating Season, natural gas usage and operating revenues are generally higher. Weather typically does not have a significant net income impact other than during the Heating Season. The following table presents the Heating Degree Days information for Illinois and Georgia, the primary locations where Southern Company Gas' operations are impacted by weather.

	First Quarter			2019 vs. 2018		2019 vs. normal
	Normal(*)	2019	2018	colder (warmer)		colder (warmer)
Illinois	3,045	3,297	3,042	8.4	%	8.3	%
Georgia	1,441	1,213	1,364	(11.1	)%	(15.8	)%

(*) Normal represents the 10-year average from January 1, 2009 through March 31, 2018 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.

Southern Company Gas hedged its exposure to warmer-than-normal weather in Illinois for gas distribution operations and in Illinois and Georgia for gas marketing services. The remaining impacts of weather on earnings are reflected in the chart below.

	Gas Distribution Operations					Gas Marketing Services
	First Quarter					First Quarter
	2019		2018			2019		2018
	(in millions)					(in millions)
Pre-tax	$	2	$	(2	)	$	—	$	(3	)
After tax	2		(2		)	—		(2		)

The following table provides the number of customers served by Southern Company Gas at March 31, 2019 and 2018:

	March 31,
	2019		2018		2019 vs. 2018
	(in thousands, except market share %)				(% change)
Gas distribution operations(a)	4,276		4,654		(8.1	)%
Gas marketing services
Energy customers(b)	701		779		(10.0	)%
Market share of energy customers in Georgia	28.8	%	29.2	%

(a) Includes total customers of approximately 407,000 at March 31, 2018 related to Elizabethtown Gas, Elkton Gas, and Florida City Gas, which were sold in July 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

(b) Gas marketing services' customers are primarily located in Georgia and Illinois. Also included are customers in Ohio contracted through an annual auction process to serve for 12 months beginning April 1 of each year. At March 31, 2019 and 2018, there were approximately 70,000 and 140,000 contracted customers, respectively.

Southern Company Gas anticipates overall customer growth trends at the remaining four natural gas distribution utilities in gas distribution operations to continue as it expects continued improvement in the new housing market and low natural gas prices. Southern Company Gas uses a variety of targeted marketing programs to attract new customers and to retain existing customers.

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Other Revenues

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(32)	(100.0)

Other revenues related to Pivotal Home Solutions, which was sold in June 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas – Sale of Pivotal Home Solutions" for additional information.

Cost of Natural Gas

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(34)	(4.7)

Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from gas distribution operations. Cost of natural gas at gas distribution operations represented 87% of total cost of natural gas in the first quarter 2019. See MANAGEMENT'S DISCUSSION AND ANALYSIS – RESULTS OF OPERATIONS – "Cost of Natural Gas" of Southern Company Gas in Item 7 of the Form 10-K and "Natural Gas Revenues, including Alternative Revenue Programs" herein for additional information.

In the first quarter 2019, cost of natural gas was $686 million compared to $720 million for the corresponding period in 2018. Excluding a $79 million decrease related to the Southern Company Gas Dispositions that resulted in a decrease in the volume of natural gas sold as a result of fewer gas distribution operations customers, cost of natural gas increased $45 million. This increase reflects a 4.9% increase in natural gas prices and an increase in the volume of natural gas sold in the first quarter 2019 primarily as a result of colder weather in Illinois compared to the corresponding period in 2018.

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

	First Quarter		2019 vs. 2018
	2019	2018
Gas distribution operations(mmBtu in millions)
Firm	296	314	(5.7	)%
Interruptible	25	25	—	%
Total(*)	321	339	(5.3	)%
Wholesale gas services (mmBtu in millions/day)
Daily physical sales	7.0	6.8	2.9	%
Gas marketing services(mmBtu in millions)
Firm:
Georgia	15	16	(6.3	)%
Illinois	6	6	—	%
Other	8	10	(20.0	)%
Interruptible large commercial and industrial	4	4	—	%
Total	33	36	(8.3	)%

(*) Includes total volumes of natural gas sold of 26 mmBtu for the three months ended March 31, 2018 related to Elizabethtown Gas, Elkton Gas, and Florida City Gas, which were sold in July 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas – Sale of Elizabethtown Gas and Elkton Gas" and " – Sale of Florida City Gas" for additional information.

Cost of Other Sales

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(7)	(100.0)

Cost of other sales related to Pivotal Home Solutions, which was sold in June 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas – Sale of Pivotal Home Solutions" for additional information.

Other Operations and Maintenance Expenses

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(41)	(14.9)

In the first quarter 2019, other operations and maintenance expenses were $235 million compared to $276 million for the corresponding period in 2018. Excluding a $29 million decrease related to the Southern Company Gas Dispositions, other operations and maintenance expenses decreased $12 million. This decrease was primarily due to a one-time adjustment in the first quarter 2018 for the adoption of a new paid time off policy. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Other Matters" of Southern Company Gas in Item 7 of the Form 10-K for additional information.

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Depreciation and Amortization

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(11)	(8.5)

In the first quarter 2019, depreciation and amortization was $118 million compared to $129 million for the corresponding period in 2018. Excluding a $16 million decrease related to the Southern Company Gas Dispositions, depreciation and amortization increased $5 million. This increase was primarily due to continued infrastructure investments at gas distribution operations.

Taxes Other Than Income Taxes

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$5	6.5

In the first quarter 2019, taxes other than income taxes were $82 million compared to $77 million for the corresponding period in 2018. Excluding a $3 million decrease related to the Southern Company Gas Dispositions, taxes other than income taxes increased $8 million. This increase primarily reflects increases in Nicor Gas' invested capital tax and revenue tax expenses as a result of higher natural gas revenues at Nicor Gas, both of which are passed through directly to customers.

Goodwill Impairment

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(42)	N/M

N/M - Not meaningful

In the first quarter 2018, a goodwill impairment charge of $42 million was recorded in contemplation of the sale of Pivotal Home Solutions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas – Sale of Pivotal Home Solutions" for additional information.

Earnings from Equity Method Investments

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$6	14.3

In the first quarter 2019, earnings from equity method investments were $48 million compared to $42 million for the corresponding period in 2018. This increase was primarily due to higher earnings from SNG as a result of rate increases implemented by SNG that became effective September 2018. See Note (E) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information.

Other Income (Expense), Net

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(7)	(58.3)

In the first quarter 2019, other income (expense), net was $5 million compared to $12 million for the corresponding period in 2018. This decrease was primarily due to a contractor litigation settlement in the first quarter 2018.See

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Note 2 to the financial statements under "Southern Company Gas – Infrastructure Replacement Programs and Capital Projects – Atlanta Gas Light – PRP" in Item 8 of the Form 10-K for additional information.

Income Taxes

First Quarter 2019 vs. First Quarter 2018
(change in millions)	(% change)
$(27)	(26.0)%

In the first quarter 2019, income taxes were $77 million compared to $104 million for the corresponding period in 2018. Excluding a $13 million decrease related to the Southern Company Gas Dispositions, income taxes decreased $14 million. This decrease was primarily due to lower pre-tax earnings compared to the prior year and an increase in the flowback of excess deferred income taxes in 2019 primarily at Atlanta Gas Light as previously authorized by the Georgia PSC. See Note (G) to the Condensed Financial Statements herein under "Southern Company Gas" for additional information.

Performance and Non-GAAP Measures

Adjusted operating margin is a non-GAAP measure that is calculated as operating revenues less cost of natural gas, cost of other sales, and revenue tax expense. Adjusted operating margin excludes other operations and maintenance expenses, depreciation and amortization, taxes other than income taxes, and goodwill impairment, which are included in the calculation of operating income as calculated in accordance with GAAP and reflected in the statements of income. The presentation of adjusted operating margin is believed to provide useful information regarding the contribution resulting from base rate changes, infrastructure replacement programs and capital projects, and customer growth at gas distribution operations since the cost of natural gas and revenue tax expense can vary significantly and are generally billed directly to customers. Southern Company Gas further believes that utilizing adjusted operating margin at gas pipeline investments, wholesale gas services, and gas marketing services allows it to focus on a direct measure of performance before overhead costs. The applicable reconciliation of operating income to adjusted operating margin is provided herein.

Adjusted operating margin should not be considered an alternative to, or a more meaningful indicator of, Southern Company Gas' operating performance than operating income as determined in accordance with GAAP. In addition, Southern Company Gas' adjusted operating margin may not be comparable to similarly titled measures of other companies.

	First Quarter 2019			First Quarter 2018
	(in millions)
Operating Income	$	353		$	388
Other operating expenses(a)	435			524
Revenue taxes(b)	(54		)	(50		)
Adjusted Operating Margin	$	734		$	862

(a) Includes other operations and maintenance expenses, depreciation and amortization, taxes other than income taxes, and goodwill impairment.

(b) Nicor Gas' revenue tax expenses, which are passed through directly to customers.

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Segment Information

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

	First Quarter 2019									First Quarter 2018
	Adjusted Operating Margin(a)			Operating Expenses(a)			Net Income (Loss)			Adjusted Operating Margin(a)			Operating Expenses(a)(b)			Net Income (Loss)(b)
	(in millions)									(in millions)
Gas distribution operations	$	524		$	314		$	133		$	557		$	323		$	149
Gas pipeline investments	8			3			32			8			3			27
Wholesale gas services	84			19			47			163			22			104
Gas marketing services	115			31			61			128			95			13
All other	6			17			(3		)	9			34			(14		)
Intercompany eliminations	(3		)	(3		)	—			(3		)	(3		)	—
Consolidated	$	734		$	381		$	270		$	862		$	474		$	279

(a) Adjusted operating margin and operating expenses are adjusted for Nicor Gas' revenue tax expenses, which are passed through directly to customers.

(b) Operating expenses and net income for gas distribution operations and gas marketing services include the impacts of the Southern Company Gas Dispositions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

Gas Distribution Operations

Gas distribution operations is the largest component of Southern Company Gas' business and is subject to regulation and oversight by 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, 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 weather mechanisms, such as weather normalization mechanisms and weather derivative instruments, that limit its exposure to weather changes within typical ranges in its natural gas distribution utilities' service territories.

In July 2018, a Southern Company Gas subsidiary, Pivotal Utility Holdings, completed the sales of the assets of two of its natural gas distribution utilities, Elizabethtown Gas and Elkton Gas, to South Jersey Industries, Inc. In July 2018, Southern Company Gas and its wholly-owned direct subsidiary, NUI Corporation, completed the sale of Pivotal Utility Holdings, which primarily consisted of Florida City Gas, to NextEra Energy. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

First Quarter 2019 vs. First Quarter 2018

In the first quarter 2019, net income decreased $16 million, or 10.7%, compared to the corresponding period in 2018. This decrease primarily relates to a $33 milliondecrease in adjusted operating margin and a $7 million decrease in other income (expense), net, partially offset by a decrease of $16 million in income tax expense and a $9 milliondecrease in operating expenses.

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Excluding an $89 million decrease attributable to the utilities sold during 2018, adjusted operating margin increased $56 million, which primarily reflects additional revenue from continued investments recovered through infrastructure replacement programs and base rate increases, the effect of revenues deferred in 2018 as a result of the Tax Reform Legislation, and colder weather in Illinois during the first quarter 2019 compared to the corresponding period in 2018. Excluding a $40 million decrease attributable to the utilities sold during 2018, operating expenses increased $31 million, which includes increased compensation and benefit costs, higher expenses passed through directly to customers, increased expenses for storage facilities, and additional depreciation primarily due to additional assets placed in service. The decrease in other income (expense), net is due to a contractor litigation settlement in the first quarter 2018. Excluding $6 million of interest expense attributable to the utilities sold during 2018, interest expense increased $7 million primarily from the issuance of first mortgage bonds at Nicor Gas. Excluding a $12 million decrease attributable to the utilities sold in 2018, income tax expense decreased $4 million, primarily due to an increase in the flowback of excess deferred income taxes in 2019, partially offset by higher pre-tax earnings.

Gas Pipeline Investments

Gas pipeline investments consists primarily of joint ventures in natural gas pipeline investments including SNG, Atlantic Coast Pipeline, PennEast Pipeline, and a 50% joint ownership interest in the Dalton Pipeline. See Note (E) to the Condensed Financial Statements herein and Note 7 to the financial statements in Item 8 of the Form 10-K for additional information.

First Quarter 2019 vs. First Quarter 2018

In the first quarter 2019, net income increased $5 million, or 18.5%, compared to the corresponding period in 2018. This increase primarily relates to a $6 million increase in earnings from equity method investments largely due to higher earnings from SNG, partially offset by a $2 million increase in income tax expense due to higher pre-tax earnings.

Wholesale Gas Services

Wholesale gas services is involved in asset management and optimization, storage, transportation, producer and peaking services, natural gas supply, natural gas services, and wholesale gas marketing. Southern Company Gas has positioned the business to generate positive economic earnings on an annual basis even under low volatility market conditions that can result from a number of factors. When market price volatility increases, wholesale gas services is well positioned to capture significant value and generate stronger results. Operating expenses primarily reflect employee compensation and benefits.

First Quarter 2019 vs. First Quarter 2018

In the first quarter 2019, net income decreased $57 million, or 54.8%, compared to the corresponding period in 2018. This decrease primarily relates to a $79 milliondecrease in adjusted operating margin, partially offset by a decrease of $19 million in income tax expense and a $3 milliondecrease in operating expenses. Details of the decrease in adjusted operating margin are provided in the table below. The decrease in operating expenses primarily reflects lower compensation and benefit expense. The decrease in income tax expense was driven by lower pre-tax earnings.

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	First Quarter 2019			First Quarter 2018
	(in millions)
Commercial activity recognized	$	38		$	172
Gain on storage derivatives	3			2
Gain (loss) on transportation and forward commodity derivatives	29			(16		)
LOCOM adjustments, net of current period recoveries	(2		)	(3		)
Purchase accounting adjustments to fair value inventory and contracts	16			8
Adjusted operating margin	$	84		$	163

Change in Commercial Activity

The commercial activity at wholesale gas services includes recognition of storage and transportation values that were generated in prior periods, which reflect the impact of prior period hedge gains and losses as associated physical transactions occur. The positive commercial activity recognized in the first quarter 2019 was primarily due to natural gas price volatility that resulted from intermittent cold weather throughout the period. The decrease in commercial activity in the first quarter 2019 compared to the corresponding period in 2018 was primarily due to significant natural gas price volatility that resulted from prolonged cold weather during the first quarter 2018 coupled with low natural gas supply.

Change in Storage and Transportation Derivatives

Volatility in the natural gas market arises from a number of factors, such as weather fluctuations or changes in supply or demand for natural gas in different regions of the U.S. The volatility of natural gas commodity prices has a significant impact on Southern Company Gas' customer rates, long-term competitive position against other energy sources, and the ability of wholesale gas services to capture value from locational and seasonal spreads. Forward storage or time spreads applicable to the locations of wholesale gas services' specific storage positions in 2019 resulted in storage derivative gains. Transportation and forward commodity derivative gains in 2019 are primarily the result of narrowing transportation spreads due to supply constraints and increases in natural gas supply, which impacted forward prices at natural gas receipt and delivery points, primarily in the Northeast and Midwest regions.

Withdrawal Schedule and Physical Transportation Transactions

The expected natural gas withdrawals from storage and expected offset to prior hedge losses/gains associated with the transportation portfolio of wholesale gas services are presented in the following table, along with the net operating revenues expected at the time of withdrawal from storage and the physical flow of natural gas between contracted transportation receipt and delivery points. Wholesale gas services' expected net operating revenues exclude storage and transportation demand charges, as well as other variable fuel, withdrawal, receipt, and delivery charges, and exclude estimated profit sharing under asset management agreements. Further, the amounts that are realizable in future periods are based on the inventory withdrawal schedule, planned physical flow of natural gas between the transportation receipt and delivery points, and forward natural gas prices at March 31, 2019. A portion of wholesale gas services' storage inventory and transportation capacity is economically hedged with futures contracts, which results in the realization of substantially fixed net operating revenues.

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	Storage withdrawal schedule
	Total storage(a)	Expected net operating gains(b)		Physical transportation transactions – expected net operating losses(c)
	(in mmBtu in millions)	(in millions)		(in millions)
2019	7	$	1	$	(6	)
2020 and thereafter	1	1		(23		)
Total at March 31, 2019	8	$	2	$	(29	)

(a) At March 31, 2019, the WACOG of wholesale gas services' expected natural gas withdrawals from storage was $2.24 per mmBtu.

(b) Represents expected operating gains from planned storage withdrawals associated with existing inventory positions and could change as wholesale gas services adjusts its daily injection and withdrawal plans in response to changes in future market conditions and forward NYMEX price fluctuations.

(c) Represents the transportation derivative gains and losses that will be settled during the period and the physical transportation transactions that offset the derivative gains and losses previously recognized.

The unrealized storage and transportation derivative gains do not change the underlying economic value of wholesale gas services' storage and transportation positions and will be reversed when the related transactions occur and are recognized. For more information on wholesale gas services' energy marketing and risk management activities, see MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Market Price Risk" of Southern Company Gas in Item 7 of the Form 10-K.

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.

On June 4, 2018, Southern Company Gas completed the sale of Pivotal Home Solutions to American Water Enterprises LLC. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

First Quarter 2019 vs. First Quarter 2018

In the first quarter 2019, net income increased $48 million compared to the corresponding period in 2018. This increase primarily relates to a $64 million decrease in operating expenses, partially offset by a $13 million decrease in adjusted operating margin and a $3 million increase in income tax expense.

Excluding a $25 million decrease attributable to the 2018 disposition of Pivotal Home Solutions, adjusted operating margin increased $12 million, which primarily reflects favorable margins and recovery of prior period hedge losses. Excluding a $61 million decrease attributable to the 2018 disposition of Pivotal Home Solutions that includes the related goodwill impairment charge, operating expense decreased $3 million.

All Other

All other includes Southern Company Gas' storage and fuels operations and its investment in Triton, 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.

First Quarter 2019 vs. First Quarter 2018

In the first quarter 2019, net loss decreased $11 million compared to the corresponding period in 2018. This decrease primarily reflects an $17 milliondecrease in operating expenses, partially offset by a $3 million decrease in adjusted operating margin. The decrease in operating expenses primarily reflects a one-time adjustment in

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compensation expense in the first quarter 2018 for the adoption of a new paid time off policy and a decrease in depreciation and amortization. The decrease in adjusted operating margin primarily relates to a decrease in storage revenues.

Segment Reconciliations

Reconciliations of operating income to adjusted operating margin for the first quarter2019 and 2018 are reflected in the following tables. See Note (M) to the Condensed Financial Statements herein for additional information.

	First Quarter 2019
	Gas Distribution Operations			Gas Pipeline Investments		Wholesale Gas Services		Gas Marketing Services		All Other			Intercompany Elimination			Consolidated
	(in millions)
Operating Income (Loss)	$	210		$	5	$	65	$	84	$	(11	)	$	—		$	353
Other operating expenses(a)	368			3		19		31		17			(3		)	435
Revenue tax expense(b)	(54		)	—		—		—		—			—			(54		)
Adjusted Operating Margin	$	524		$	8	$	84	$	115	$	6		$	(3	)	$	734

	First Quarter 2018
	Gas Distribution Operations			Gas Pipeline Investments		Wholesale Gas Services		Gas Marketing Services		All Other			Intercompany Elimination			Consolidated
	(in millions)
Operating Income (Loss)	$	234		$	5	$	141	$	33	$	(25	)	$	—		$	388
Other operating expenses(a)	373			3		22		95		34			(3		)	524
Revenue tax expense(b)	(50		)	—		—		—		—			—			(50		)
Adjusted Operating Margin	$	557		$	8	$	163	$	128	$	9		$	(3	)	$	862

(a) Includes other operations and maintenance expenses, depreciation and amortization, taxes other than income taxes, and goodwill impairment.

(b) Nicor Gas' revenue tax expenses, which are passed through directly to customers.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Southern Company Gas' future earnings potential. The Southern Company Gas Dispositions are expected to materially decrease future earnings and cash flows to Southern Company Gas. In the first quarter 2018,net income attributable to these dispositions, excluding the related goodwill impairment, was $34 million.The level of Southern Company Gas' future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Southern Company Gas' primary business of natural gas distribution and its complementary businesses in the gas pipeline investments, wholesale gas services, and gas marketing services sectors. These factors include Southern Company Gas' ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs, the completion and subsequent operation of ongoing infrastructure and other construction projects, creditworthiness of customers, its ability to optimize its transportation and storage positions, and its ability to re-contract storage rates at favorable prices.

Future earnings will be driven by customer growth and are subject to a variety of other factors. These factors include weather, competition, new energy contracts with other utilities and other wholesale customers, energy conservation practiced by customers, the use of alternative energy sources by customers, the price of natural gas, the price elasticity of demand, and the rate of economic growth or decline in Southern Company Gas' service territories.

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Demand for natural gas is primarily driven by the pace of economic growth that may be affected by changes in regional and global economic conditions, which may impact future earnings.

Volatility of natural gas prices has a significant impact on Southern Company Gas' customer rates, its long-term competitive position against other energy sources, and the ability of its gas marketing services and wholesale gas services segments to capture value from locational and seasonal spreads. Additionally, changes in commodity prices subject a significant portion of Southern Company Gas' operations to earnings variability. Over the longer term, volatility is expected to be low to moderate and locational and/or transportation spreads are expected to decrease as new pipelines are built to reduce the existing supply constraints in the shale areas of the Northeast U.S. To the extent these pipelines are delayed or not built, volatility could increase. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "FERC Matters" of Southern Company Gas in Item 7 of the Form 10-K for additional information on permitting challenges experienced by the Atlantic Coast Pipeline. Additional economic factors may contribute to this environment, including a significant drop in oil and natural gas prices, which could lead to consolidation of natural gas producers or reduced levels of natural gas production. Further, if economic conditions continue to improve, including the new housing market, 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.

As part of its business strategy, Southern Company Gas regularly considers and evaluates joint development arrangements as well as acquisitions and dispositions of businesses and assets.

Due to the seasonal nature of the natural gas business and other factors including, but not limited to, weather, regulation, competition, customer demand, and general economic conditions, the first quarter 2019 results are not necessarily indicative of the results to be expected for any other period.

Environmental Matters

New or revised environmental laws and regulations could affect many areas of Southern Company Gas' operations. The impact of any such changes cannot be determined at this time. Environmental compliance costs could affect earnings if such costs cannot continue to be fully recovered in rates on a timely basis. Further, increased costs that are recovered through regulated rates could contribute to reduced demand for natural gas, which could negatively affect results of operations, cash flows, and/or financial condition. Additionally, many commercial and industrial customers may also be affected by existing and future environmental requirements, which for some may have the potential to ultimately affect their demand for natural gas. See Note (C) to the Condensed Financial Statements under "Environmental Remediation" herein and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" of Southern Company Gas in Item 7 and Note 3 to the financial statements under "Environmental Remediation" in Item 8 of the Form 10-K for additional information.

Regulatory Matters

See Note 2 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information regarding Southern Company Gas' regulatory matters.

Rate Proceedings

Nicor Gas

In November 2018, Nicor Gas filed a general base rate case with the Illinois Commission requesting a$230 millionincrease in annual base rate revenues. The requested increase is based on a projected test year for the12-month period ending September 30, 2020, a ROE of10.6%, and an increase in the equity ratio from52% to 54% to address the negative cash flow and credit metric impacts of the Tax Reform Legislation.

On April 16, 2019, Nicor Gas entered into a stipulation agreement to resolve all related issues with the Staff of the Illinois Commission, including a ROE of9.86% and an equity ratio of 54%. Also on April 16, 2019, Nicor Gas filed its rebuttal testimony with the Illinois Commission incorporating the stipulation agreement and addressing the

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remaining items outstanding with the other two intervenors. As a result of the stipulation agreement and rebuttal testimony, the revised requested annual revenue increase is $180 million.

The Illinois Commission is expected to rule on the requested increase within the statutory time limit of 11 months from the filing of the rate case, after which rate adjustments will be effective. The ultimate outcome of this matter cannot be determined at this time.

Atlanta Gas Light

Atlanta Gas Light is required to file a traditional base rate case no later than June 3, 2019 for rates effective January 1, 2020.

Virginia Natural Gas

In December 2018, the Virginia Commission approved Virginia Natural Gas' annual information form filing, which reduced annual base rates by $14 millioneffective January 1, 2019 due to lower tax expense as a result of the Tax Reform Legislation. This approval also required Virginia Natural Gas to issue customer refunds, via bill credits, for $14 millionrelated to 2018 tax benefits deferred as a regulatory liability, current, on the balance sheet at December 31, 2018. These customer refunds were completed in the first quarter 2019.

Regulatory Infrastructure Programs

In addition to capital expenditures recovered through base rates by each of the natural gas distribution utilities, Nicor Gas and Virginia Natural Gas have separate rate riders that provide for timely recovery of capital expenditures for specific infrastructure replacement programs. Infrastructure expenditures incurred under these programs in the first three months of 2019 were as follows:

Utility	Program	First Quarter 2019
		(in millions)
Nicor Gas	Investing in Illinois	$	29
Virginia Natural Gas	Steps to Advance Virginia's Energy (SAVE)	9
Total		$	38

On April 8, 2019, Virginia Natural Gas filed an application with the Virginia Commission to amend and extend its SAVE program. The proposal would allow Virginia Natural Gas to continue replacing aging pipeline infrastructure and increase its authorized investment under the currently-approved plan. Virginia Natural Gas seeks to amend its currently-approved plan by increasing the authorized investment in 2019 from$35 million to $40 millionand to extend the plan for an additionalfive years until 2024, with proposed annual investments of $50 million in 2020,$60 millionin 2021, and$70 millionin each year from 2022 through 2024, for a maximum total investment over thesix-year term (2019 through 2024) of$370 million. The proposed investment schedule would also allow for variances of up to$6 million in 2019,$8 millionin 2020,$9 millionin 2021, and$10 millionin each year from 2022 through 2024, with a total potential net variance of up to $10 million allowed for the program. The Virginia Commission is expected to rule on the request in the third quarter 2019. The ultimate outcome of this matter cannot be determined at this time.

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Regulatory Matters – Infrastructure Replacement Programs and Capital Projects" of Southern Company Gas in Item 7 and Note 2 to the financial statements under "Southern Company Gas – Infrastructure Replacement Programs and Capital Projects" in Item 8 of the Form 10-K for additional information.

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Affiliate Asset Management Agreements

On March 15, 2019, the Virginia Commission approved an extension of Virginia Natural Gas' asset management agreement with Sequent to March 31, 2021. Southern Company Gas does not expect the new agreement to have a material impact on its financial statements.

FERC Matters

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "FERC Matters" of Southern Company Gas in Item 7 of the Form 10-K and Notes 7 and 9 to the financial statements under "Southern Company Gas – Equity Method Investments" and "Guarantees," respectively, in Item 8 of the Form 10-K for additional information regarding Southern Company Gas' gas pipeline construction projects.

Other Matters

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Other Matters" and "FERC Matters" of Southern Company Gas in Item 7 for additional information.

Southern Company Gas is involved in various other matters that could affect future earnings, including matters being litigated, as well as other regulatory matters and matters that could result in asset impairments. In addition, Southern Company Gas is subject to certain claims and legal actions arising in the ordinary course of business. The ultimate outcome of such pending or potential litigation, regulatory matters, or potential asset impairments cannot be predicted at this time; however, for current proceedings not specifically reported 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 would have a material effect on Southern Company Gas' financial statements. See Notes (B) and (C) to the Condensed Financial Statements herein for a discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Southern Company Gas prepares its financial statements in accordance with GAAP. Significant accounting policies are described in Notes 1, 5, and 6 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 Southern Company Gas' results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES – "Application of Critical Accounting Policies and Estimates" of Southern Company Gas in Item 7 of the Form 10-K for a complete discussion of Southern Company Gas' critical accounting policies and estimates.

Recently Issued Accounting Standards

See Note (A) to the Condensed Financial Statements herein for information regarding Southern Company Gas' recently adopted accounting standards.

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" of Southern Company Gas in Item 7 of the Form 10-K for additional information. Southern Company Gas' financial condition remained stable at March 31, 2019. Southern Company Gas intends to continue to monitor its access to short-term and long-term capital markets as well as bank credit agreements to meet future capital and liquidity needs. See "Capital Requirements and Contractual Obligations," "Sources of Capital," and "Financing Activities" herein for additional information.

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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, 2019, the amount of subsidiary retained earnings restricted to dividend totaled $875 million. This restriction did not impact Southern Company Gas' ability to meet its cash obligations.

Net cash provided from operating activities totaled $683 million for the first three months of 2019, a decrease of $295 million from the corresponding period in 2018. The decrease was primarily due to the impacts of the Southern Company Gas Dispositions and the timing of vendor payments. Net cash used for investing activities totaled $290 million for the first three months of 2019 primarily due to gross property additions related to utility capital expenditures and infrastructure investments recovered through replacement programs at gas distribution operations and capital contributed to equity method pipeline investments. Net cash used for financing activities totaled $402 million for the first three months of 2019 primarily due to repayments of commercial paper borrowings and a common stock dividend payment to Southern Company. Cash flows from financing activities vary from period to period based on capital needs and the maturity or redemption of securities.

Significant balance sheet changes for the first three months of 2019 include a decrease of $363 million in natural gas for sale, net of temporary LIFO liquidation, due to the use of stored natural gas and a $289 million decrease in notes payable primarily related to net repayments of commercial paper borrowings. Other significant balance sheet changes include decreases of $272 million and $324 million in energy marketing receivables and payables, respectively, due to lower natural gas prices and volumes of natural gas sold, and an increase of $171 million in total property, plant, and equipment primarily due to utility capital expenditures and infrastructure investments recovered through replacement programs. Balance sheet changes for the first three months of 2019 also include recording $86 million in operating lease right-of use assets and $84 million in operating lease obligations related to the adoption of ASU No. 2016-02, Leases (Topic 842) (ASC 842). See Note (L) to the Condensed Financial Statements herein for additional information on the adoption of ASC 842.

Capital Requirements and Contractual Obligations

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Capital Requirements and Contractual Obligations" of Southern Company Gas in Item 7 of the Form 10-K for a description of Southern Company Gas' capital requirements and contractual obligations. Approximately $350 million will be required through March 31, 2020 to fund maturities of long-term debt. See "Sources of Capital" herein for additional information.

The regulatory infrastructure programs and other construction programs are subject to periodic review and revision, and actual costs may vary from these estimates because of numerous factors. These factors include: changes in business conditions; changes in FERC rules and regulations; state regulatory approvals; changes in legislation; the cost and efficiency of labor, equipment, and materials; project scope and design changes; and the cost of capital. In addition, there can be no assurance that costs related to capital expenditures will be fully recovered. See Note 2 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein for information regarding additional factors that may impact infrastructure investment expenditures.

Sources of Capital

Southern Company Gas plans to obtain the funds to meet its future capital needs from sources similar to those used in the past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity contributions from Southern Company. However, the amount, type, and timing of any future financings, if needed, depend upon prevailing market conditions, regulatory approval, and other factors. The issuance of securities by Nicor Gas is generally subject to the approval of the Illinois Commission. See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" of Southern Company Gas in Item 7 of the Form 10-K for additional information.

Southern Company Gas' current liabilities exceeded current assets by $495 million primarily as a result of $361 million in notes payable and $354 million in securities due within one year. Southern Company Gas' current

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liabilities frequently exceed current assets because of commercial paper borrowings used to fund daily operations, scheduled maturities of long-term debt, and significant seasonal fluctuations in cash needs.

At March 31, 2019, Southern Company Gas had $57 million of cash and cash equivalents. Committed credit arrangements with banks at March 31, 2019 were as follows:

Company	Expires 2022		Unused
	(in millions)
Southern Company Gas Capital(a)	$	1,400	$	1,395
Nicor Gas	500		500
Total(b)	$	1,900	$	1,895

(a) Southern Company Gas guarantees the obligations of Southern Company Gas Capital.

(b) Pursuant to the credit arrangement, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

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

The multi-year credit arrangement of Southern Company Gas Capital and Nicor Gas (Facility) contains a covenant that limits the debt levels and contains a cross-acceleration provision to other indebtedness (including guarantee obligations) of the applicable company. Such cross-acceleration provision to other indebtedness would trigger an event of default of the applicable company if Southern Company Gas or Nicor Gas defaulted on indebtedness, the payment of which was then accelerated. At March 31, 2019, both companies were in compliance with such covenant. The Facility does not contain a material adverse change clause at the time of borrowings.

Subject to applicable market conditions, the applicable company expects to renew or replace the Facility as needed, prior to expiration. In connection therewith, the applicable company may extend the maturity dates and/or increase or decrease the lending commitments thereunder. A portion of unused credit with banks provides liquidity support to Southern Company Gas.

Southern Company Gas has substantial cash flow from operating activities and access to capital markets, including the commercial paper programs, and financial institutions to meet liquidity needs. Southern Company Gas makes short-term borrowings primarily through commercial paper programs that have the liquidity support of the committed bank credit arrangements described above. Short-term borrowings are included in notes payable in the balance sheets.

Details of short-term borrowings were as follows:

	Short-Term Debt at March 31, 2019				Short-Term Debt During the Period(*)
	Amount Outstanding		Weighted Average Interest Rate		Average Amount Outstanding		Weighted Average Interest Rate		Maximum Amount Outstanding
Commercial paper:	(in millions)				(in millions)				(in millions)
Southern Company Gas Capital	$	326	2.8	%	$	364	2.9	%	$	472
Nicor Gas	35		2.6	%	106		2.9	%	247
Total	$	361	2.8	%	$	470	2.9	%

(*) Average and maximum amounts are based upon daily balances during the three-month period ended March 31, 2019.

Southern Company Gas believes that the need for working capital can be adequately met by utilizing commercial paper programs, lines of credit, and operating cash flows.

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Credit Rating Risk

Southern Company Gas does 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 below BBB- and/or Baa3. These contracts are for physical gas purchases and sales and energy price risk management. The maximum potential collateral requirement under these contracts at March 31, 2019 was approximately $12 million.

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 Southern Company Gas to access capital markets and would be likely to impact the cost at which it does so.

As a result of the Tax Reform Legislation, certain financial metrics, such as the funds from operations to debt percentage, used by the credit rating agencies to assess Southern Company and its subsidiaries, including Southern Company Gas, may be negatively impacted. Southern Company Gas and its regulated subsidiaries have taken actions to mitigate the resulting impacts, which, among other alternatives, include adjusting capital structure. Absent actions by Southern Company and its subsidiaries that fully mitigate the impacts, Southern Company Gas', Southern Company Gas Capital's, and Nicor Gas' credit ratings could be negatively affected. The Georgia PSC's May 15, 2018 approval of a stipulation for Atlanta Gas Light's annual rate adjustment maintained the previously authorized earnings band and increased the equity ratio to address the negative cash flow and credit metric impacts of the Tax Reform Legislation. See Note 2 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements under "Southern Company Gas" herein for information on additional rate proceedings for Nicor Gas and Atlanta Gas Light expected to conclude in 2019.

Financing Activities

The long-term debt on Southern Company Gas' balance sheets includes both principal and non-principal components. As of March 31, 2019, the non-principal components totaled $444 million, which consisted of the unamortized portions of the fair value adjustment recorded in purchase accounting, debt premiums, debt discounts, and debt issuance costs.

Southern Company Gas did not issue or redeem any securities during the three months ended March 31, 2019.

In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Southern Company Gas plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

Market Price Risk

Other than the items discussed below, there were no material changes to Southern Company Gas' disclosures about market price risk during the first quarter2019. For an in-depth discussion of Southern Company Gas' market price risks, see MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Market Price Risk" of Southern Company Gas in Item 7 of the Form 10-K. Also see Notes (I) and (J) to the Condensed Financial Statements herein for information relating to derivative instruments.

Southern Company Gas is exposed to market risks, primarily commodity price risk, interest rate risk, and weather risk. Due to various cost recovery mechanisms, the natural gas distribution utilities of Southern Company Gas that sell natural gas directly to end-use customers have limited exposure to market volatility of natural gas prices. Certain natural gas distribution utilities of Southern Company Gas may manage fuel-hedging programs implemented per the guidelines of their respective state regulatory agencies to hedge the impact of market fluctuations in natural gas prices for customers. For the weather risk associated with Nicor Gas, Southern Company Gas has a corporate weather hedging program that utilizes weather derivatives to reduce the risk of lower operating margins potentially resulting from significantly warmer-than-normal weather. In addition, certain non-regulated operations routinely utilize various types of derivative instruments to economically hedge certain commodity price

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and weather risks inherent in the natural gas industry. These instruments include a variety of exchange-traded and over-the-counter energy contracts, such as forward contracts, futures contracts, options contracts, and swap agreements. Some of these economic hedge activities may not qualify, or are not designated, for hedge accounting treatment. For the periods presented below, the changes in net fair value of Southern Company Gas' derivative contracts were as follows:

	First Quarter 2019			First Quarter 2018
	(in millions)
Contracts outstanding at beginning of period, assets (liabilities), net	$	(167	)	$	(106	)
Contracts realized or otherwise settled	(5		)	49
Current period changes(a)	44			(13		)
Contracts outstanding at the end of period, assets (liabilities), net	$	(128	)	$	(70	)
Netting of cash collateral	190			223
Cash collateral and net fair value of contracts outstanding at end of period(b)	$	62		$	153

(a) Current period changes also include the fair value of new contracts entered into during the period, if any.

(b) Net fair value of derivative contracts outstanding excludes premium and the intrinsic value associated with weather derivatives of $11 million and $4 million at March 31, 2019 and 2018, respectively.

The maturities of Southern Company Gas' energy-related derivative contracts at March 31, 2019 were as follows:

				Fair Value Measurements
				March 31, 2019
	Total Fair Value			Maturity
				Year 1			Years 2 & 3			Years 4 and thereafter
	(in millions)
Level 1(a)	$	(144	)	$	(36	)	$	(76	)	$	(32	)
Level 2(b)	35			26			10			(1		)
Level 3(c)	(19		)	2			(2		)	(19		)
Fair value of contracts outstanding at end of period(d)	$	(128	)	$	(8	)	$	(68	)	$	(52	)

(a) Valued using NYMEX futures prices.

(b) Valued using basis transactions that represent the cost to transport natural gas from a NYMEX delivery point to the contract delivery point. These transactions are based on quotes obtained either through electronic trading platforms or directly from brokers.

(c) Valued using a combination of observable and unobservable inputs.

(d) Excludes cash collateral of $190 million as well as premium and associated intrinsic value associated with weather derivatives of $11 million at March 31, 2019.

140

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 Number
A	Introduction	142
B	Regulatory Matters	146
C	Contingencies	153
D	Revenue from Contracts with Customers	156
E	Consolidated Entities and Equity Method Investments	161
F	Financing	162
G	Income Taxes	167
H	Retirement Benefits	167
I	Fair Value Measurements	170
J	Derivatives	175
K	Acquisitions and Dispositions	186
L	Leases	189
M	Segment and Related Information	194

INDEX TO APPLICABLE NOTES TO FINANCIAL STATEMENTS BY REGISTRANT

The following unaudited notes to the condensed financial statements are a combined presentation. The list below indicates the registrants to which each footnote applies.

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

141

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

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 as of December 31, 2018 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, 2019 and 2018. 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, 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 results of operations, financial position, or cash flows of any registrant.

Recently Adopted Accounting Standards

In 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (ASU 2016-02). ASU 2016-02 requires lessees to recognize on the balance sheet a lease liability and a right-of-use asset for all leases. ASU 2016-02 also changes the recognition, measurement, and presentation of expense associated with leases and provides clarification regarding the identification of certain components of contracts that would represent a lease. The accounting required by lessors is relatively unchanged and there is no change to the accounting for existing leveraged leases. The registrants adopted the new standard effective January 1, 2019. See Note (L) for additional information and related disclosures.

142

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Goodwill and Other Intangible Assets

Goodwill at March 31, 2019 and December 31, 2018 was as follows:

	At March 31, 2019		At December 31, 2018
	(in millions)
Southern Company	$	5,284	$	5,315
Southern Company Gas:
Gas distribution operations	$	4,034	$	4,034
Gas marketing services	981		981
Southern Company Gas total	$	5,015	$	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.

143

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Other intangible assets were as follows:

	At March 31, 2019							At December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net
	(in millions)							(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	211	$	(100	)	$	111	$	223	$	(94	)	$	129
Trade names	70		(22		)	48		70		(21		)	49
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
PPA fair value adjustments	405		(67		)	338		405		(61		)	344
Other	11		(6		)	5		11		(5		)	6
Total other intangible assets subject to amortization	$	761	$	(251	)	$	510	$	773	$	(235	)	$	538
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—			75		75		—			75
Total other intangible assets	$	836	$	(251	)	$	585	$	848	$	(235	)	$	613
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	405	$	(67	)	$	338	$	405	$	(61	)	$	344
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(89	)	$	67	$	156	$	(84	)	$	72
Trade names	26		(8		)	18		26		(7		)	19
Wholesale gas services
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
Total other intangible assets subject to amortization	$	246	$	(153	)	$	93	$	246	$	(145	)	$	101

144

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2019
	(in millions)
Southern Company	$	17
Southern Power(a)	$	6
Southern Company Gas
Gas marketing services(b)	$	6
Wholesale gas services(a)	2
Southern Company Gas total	$	8

(a) Recorded as a reduction to operating revenues.

(b) Included in depreciation and amortization.

Restricted Cash

At December 31, 2018, Georgia Power had restricted cash related to the redemption of pollution control revenue bonds, which were redeemed in January 2019. See Note (F) under "Financing Activities" for additional information. At both March 31, 2019 and December 31, 2018, Southern Company Gas had restricted cash held as collateral for worker's compensation, life insurance, and long-term disability insurance.

The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amounts shown in the condensed statements of cash flows for the registrants that had restricted cash at March 31, 2019 and/or December 31, 2018:

	Southern Company			Southern Company Gas
	(in millions)
At March 31, 2019
Cash and cash equivalents	$	1,361		$	57
Restricted cash:
Other accounts and notes receivable	4			4
Total cash, cash equivalents, and restricted cash	$	1,364	(*)	$	61

(*) Total does not add due to rounding.

	Southern Company		Georgia Power		Southern Company Gas
	(in millions)
At December 31, 2018
Cash and cash equivalents	$	1,396	$	4	$	64
Cash and cash equivalents held for sale	9		—		—
Restricted cash:
Restricted cash	—		108		—
Other accounts and notes receivable	114		—		6
Total cash, cash equivalents, and restricted cash	$	1,519	$	112	$	70

145

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Natural Gas for Sale

Southern Company Gas, with the exception of Nicor Gas, carries natural gas inventory 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. Southern Company Gas had no material adjustment in any period presented.

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. Nicor Gas' inventory decrement at March 31, 2019 is expected to be restored prior to year end.

(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 of Alabama Power's, Georgia Power's, and Mississippi Power's regulatory clauses at March 31, 2019 and December 31, 2018 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2019		December 31, 2018
		(in millions)
Alabama Power
Rate CNP Compliance	Deferred under recovered regulatory clause revenues	$	—	$	42
	Customer accounts receivable	25		—
Rate CNP PPA	Deferred under recovered regulatory clause revenues	21		25
Retail Energy Cost Recovery(*)	Deferred under recovered regulatory clause revenues	—		109
	Other regulatory liabilities, deferred	2		—
Natural Disaster Reserve	Other regulatory liabilities, deferred	22		20
Georgia Power
Fuel Cost Recovery	Receivables – under recovered fuel clause revenues	$	73	$	115
Mississippi Power
Fuel Cost Recovery	Over recovered retail fuel costs	$	10	$	8

(*) In accordance with an accounting order issued on February 5, 2019 by the Alabama PSC, Alabama Power utilized $75 million of the 2018 Rate RSE refund liability to reduce the Rate ECR under recovered balance. See Note 2 to the financial statements under "Alabama Power – Rate ECR" in Item 8 of the Form 10-K for additional information.

Alabama Power

Environmental Accounting Order

In connection with management's decision to retire Plant Gorgas, in February 2019, Alabama Power reclassified approximately $1.3 billion for Plant Gorgas Unit 10 from plant in service, net of depreciation to other utility plant, net and continued to depreciate the asset according to the original depreciation rates. On April 15, 2019, Alabama Power retired Plant Gorgas Units 8, 9, and 10 and reclassified approximately $740 million of the remaining net investment costs of the units to a regulatory asset to be recovered over the units' remaining useful lives as established prior to the decision to retire. Additionally, approximately $700 million of net capitalized asset

146

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

retirement costs will be reclassified to a regulatory asset and recovered in accordance with accounting guidance provided by the Alabama PSC. See Note 2 to the financial statements under "Alabama Power – Environmental Accounting Order" and Note 6 in Item 8 of the Form 10-K for additional information.

Georgia Power

Nuclear Construction

See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information regarding Georgia Power's construction of Plant Vogtle Units 3 and 4, the joint ownership agreements and related funding agreement, VCM reports, and the NCCR tariff.

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4. Georgia Power holds a 45.7% ownership interest in Plant Vogtle Units 3 and 4. 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 March 2017, the EPC Contractor filed for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code. In connection with the EPC Contractor's bankruptcy filing, 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, a cost reimbursable plus fee arrangement, whereby Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, which is 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.

147

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4 by the expected in-service dates of November 2021 and November 2022, respectively, is as follows:

	(in billions)
Base project capital cost forecast(a)(b)	$	8.0
Construction contingency estimate	0.4
Total project capital cost forecast(a)(b)	8.4
Net investment as of March 31, 2019(b)	(4.9		)
Remaining estimate to complete(a)	$	3.5

(a) Excludes financing costs expected to be capitalized through AFUDC of approximately $325 million.

(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 $3.1 billion, of which $1.9 billion had been incurred through March 31, 2019.

In April 2019, Southern Nuclear completed a cost and schedule validation process to verify and update quantities of commodities remaining to install, labor hours to install remaining quantities and related productivity, testing and system turnover requirements, and forecasted staffing needs and related costs. This process confirmed the total estimated project capital cost forecast for Plant Vogtle Units 3 and 4. The expected in-service dates of November 2021 for Unit 3 and November 2022 for Unit 4, as previously approved by the Georgia PSC, remain unchanged.

As construction continues, challenges with management of contractors, subcontractors, and vendors; supervision of craft labor and related craft labor productivity, ability to attract and retain craft labor, and/or related cost escalation; procurement, fabrication, delivery, assembly, and/or installation and the initial testing and start-up, including any required engineering changes, of plant systems, structures, or components (some of which are based on new technology that only recently began initial operation in the global nuclear industry at this scale), any of which may require additional labor and/or materials; or other issues could arise and change the projected schedule and estimated cost. Monthly construction production targets established as part of a strategy to maintain and build margin to the approved in-service dates will continue to increase significantly throughout 2019. To meet these increasing monthly targets, existing craft construction productivity must improve and additional craft laborers must be retained and deployed.

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 assure 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. As a result of such compliance processes, certain license amendment requests have been filed and approved or are pending before the NRC. Various design and other licensing-based compliance matters, including the timely resolution of ITAAC and the related approvals by the NRC, may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues 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 regulatory-approved project schedule is currently estimated to result in additional base capital costs of approximately $50 million per month, based on Georgia Power's ownership interests, and AFUDC of approximately $12 million per month. While Georgia Power is not precluded from seeking recovery of any future capital cost forecast increase, 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.

148

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

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.

As a result of the increase in the total project capital cost forecast and Georgia Power's decision not to seek rate recovery of the increase in the base capital costs in conjunction with the nineteenth VCM report, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 were required to vote to continue construction. In September 2018, the Vogtle Owners unanimously voted to continue construction of Plant Vogtle Units 3 and 4.

Amendments to the Vogtle Joint Ownership Agreements

In connection with the vote to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG'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 and MEAG SPVJ to provide funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. On January 14, 2019, Georgia Power, MEAG, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. On February 18, 2019, Georgia Power, the other Vogtle Owners, and MEAG'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.

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, 2019, Georgia Power had recovered approximately $1.9 billion of financing costs. Financing costs related to capital costs above $4.418 billion will be recovered through AFUDC; however, Georgia Power will not record 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 2018, the Georgia PSC approved Georgia Power's request to increase the NCCR tariff by $88 million annually, effective January 1, 2019.

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

149

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

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 amounts 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 prudence decisions on cost recovery will be made at a later date, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 ARP) 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 upon Unit 3 reaching commercial operation, retail base rates would be adjusted to include carrying costs on those capital costs deemed prudent in the Vogtle Cost Settlement Agreement. 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 $100 million in 2018 and are estimated to have negative earnings impacts of approximately $75 million in 2019 and an aggregate of approximately $635 million from 2020 to 2022.

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 February 2018, Georgia Interfaith Power & Light, Inc. (GIPL) and Partnership for Southern Equity, Inc. (PSE) filed a petition appealing the Georgia PSC's January 11, 2018 order with the Fulton County Superior Court. In March 2018, Georgia Watch filed a similar appeal to the Fulton County Superior Court for judicial review of the Georgia PSC's decision and denial of Georgia Watch's motion for reconsideration. In December 2018, the Fulton County Superior Court granted Georgia Power's motion to dismiss the two appeals. On January 9, 2019, GIPL, PSE, and Georgia Watch filed an appeal of this decision with the Georgia Court of Appeals. Georgia Power believes the appeal has no merit; however, an adverse outcome in the appeal combined with subsequent adverse action by the Georgia PSC could have a material impact on Southern Company's and Georgia Power's results of operations, financial condition, and liquidity.

In August 2018, Georgia Power filed its nineteenth VCM report with the Georgia PSC, which requested approval of $578 million of construction capital costs incurred from January 1, 2018 through June 30, 2018. On February 19, 2019, the Georgia PSC approved the nineteenth VCM, but deferred approval of $51.6 million of expenditures related to Georgia Power's portion of an administrative claim filed in the Westinghouse bankruptcy proceedings. Through the nineteenth VCM, the Georgia PSC has approved total construction capital costs incurred through June 30, 2018 of $5.4 billion (before $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related Customer Refunds). In addition, the staff of the Georgia PSC requested, and Georgia Power agreed, to report the results of the cost and schedule validation process to the Georgia PSC (which is expected to occur by May 1, 2019) and to file its twentieth VCM report concurrently with the twenty-first VCM report by August 31, 2019.

150

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

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

DOE Financing

At March 31, 2019, Georgia Power had borrowed $3.46 billion related to Plant Vogtle Units 3 and 4 costs as provided through the Amended and Restated Loan Guarantee Agreement and related multi-advance credit facilities among Georgia Power, the DOE, and the FFB, which provide for borrowings of up to approximately $5.130 billion, subject to the satisfaction of certain conditions. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K and Note (F) under "DOE Loan Guarantee Borrowings" for additional information, including applicable covenants, events of default, mandatory prepayment events, and conditions to borrowing.

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

Mississippi Power

Municipal and Rural Association Tariff

On March 28, 2019, Mississippi Power filed a request with the FERC for a decrease in wholesale base revenues under the MRA tariff as agreed upon in a settlement agreement reached with its wholesale customers resolving all matters related to the Kemper County energy facility similar to the retail rate settlement agreement approved by the Mississippi PSC in February 2018 and reflecting the impacts of the Tax Reform Legislation. The MRA settlement agreement provides that base rates will decrease $3.7 million annually, effective January 1, 2019. Mississippi Power expects the matter to be resolved in the second quarter 2019. The ultimate outcome of this matter cannot be determined at this time.

Kemper County Energy Facility

As the mining permit holder, Liberty Fuels Company, LLC has a legal obligation to perform mine reclamation, and Mississippi Power has a contractual obligation to fund all reclamation activities. As a result of the abandonment of the Kemper IGCC, final mine reclamation began in 2018 and is expected to be substantially completed in 2020, with monitoring expected to continue through 2027. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

During the first quarter 2019, Mississippi Power recorded pre-tax charges to income of $2 million ($1 million after tax), primarily resulting from the abandonment and related closure activities and ongoing period costs, net of sales proceeds, for the mine and gasifier-related assets at the Kemper County energy facility. Additional closure costs for the mine and gasifier-related assets, currently estimated at up to $10 million pre-tax (excluding salvage, net of dismantlement costs), may be incurred through the first half of 2020. In addition, period costs, including, but not limited to, costs for compliance and safety, ARO accretion, and property taxes for the mine and gasifier-related assets, are estimated at $11 million for the remainder of 2019 and $2 million to $6 million annually in 2020 through 2023.

In addition, Mississippi Power constructed the CO₂ pipeline for the planned transport of captured CO₂ for use in enhanced oil recovery and is currently evaluating its options regarding the final disposition of the CO₂ pipeline, including removal of the pipeline. This evaluation is expected to be complete later in 2019. If Mississippi Power ultimately decides to remove the CO₂ pipeline, the cost of removal would have a material impact on Mississippi Power's financial statements and could have a material impact on Southern Company's financial statements.

In December 2018, Mississippi Power filed with the DOE its request for property closeout certification under the contract related to the$387 million of grants received. Mississippi Power and the DOE are currently in discussions regarding the requested closeout and property disposition, which may require payment to the DOE for a portion of certain property that is to be retained by Mississippi Power. In connection with the DOE closeout discussions, on April 29, 2019, the Civil Division of the Department of Justice informed Southern Company and Mississippi Power of an investigation related to the Kemper County energy facility. The ultimate outcome of these matters cannot be

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

determined at this time; however, they could have a material impact on Mississippi Power's and Southern Company's financial statements.

Southern Company Gas

Rate Proceedings

Nicor Gas

In November 2018, Nicor Gas filed a general base rate case with the Illinois Commission requesting a$230 millionincrease in annual base rate revenues. The requested increase is based on a projected test year for the12-month period ending September 30, 2020, a ROE of10.6%, and an increase in the equity ratio from52% to 54% to address the negative cash flow and credit metric impacts of the Tax Reform Legislation.

On April 16, 2019, Nicor Gas entered into a stipulation agreement to resolve all related issues with the Staff of the Illinois Commission, including a ROE of9.86% and an equity ratio of 54%. Also on April 16, 2019, Nicor Gas filed its rebuttal testimony with the Illinois Commission incorporating the stipulation agreement and addressing the remaining items outstanding with the other two intervenors. As a result of the stipulation agreement and rebuttal testimony, the revised requested annual revenue increase is $180 million.

The Illinois Commission is expected to rule on the requested increase within the statutory time limit of 11 months from the filing of the rate case, after which rate adjustments will be effective. The ultimate outcome of this matter cannot be determined at this time.

Virginia Natural Gas

In December 2018, the Virginia Commission approved Virginia Natural Gas' annual information form filing, which reduced annual base rates by $14 millioneffective January 1, 2019 due to lower tax expense as a result of the Tax Reform Legislation. This approval also required Virginia Natural Gas to issue customer refunds, via bill credits, for $14 millionrelated to 2018 tax benefits deferred as a regulatory liability, current, on the balance sheet at December 31, 2018. These customer refunds were completed in the first quarter 2019.

Regulatory Infrastructure Programs

Southern Company Gas is engaged in various infrastructure programs that update or expand its gas distribution systems to improve reliability and help ensure the safety of its utility infrastructure, and recovers in rates its investment and a return associated with these infrastructure programs. In addition to capital expenditures recovered through base rates by each of the natural gas distribution utilities, Nicor Gas and Virginia Natural Gas have separate rate riders that provide for timely recovery of capital expenditures for specific infrastructure replacement programs.

Virginia Natural Gas

On April 8, 2019, Virginia Natural Gas filed an application with the Virginia Commission to amend and extend its Steps to Advance Virginia's Energy program. The proposal would allow Virginia Natural Gas to continue replacing aging pipeline infrastructure and increase its authorized investment under the currently-approved plan. Virginia Natural Gas seeks to amend its currently-approved plan by increasing the authorized investment in 2019 from$35 million to $40 millionand to extend the plan for an additionalfive years until 2024, with proposed annual investments of $50 million in 2020,$60 millionin 2021, and$70 millionin each year from 2022 through 2024, for a maximum total investment over thesix-year term (2019 through 2024) of$370 million. The proposed investment schedule would also allow for variances of up to$6 million in 2019,$8 millionin 2020,$9 millionin 2021, and$10 millionin each year from 2022 through 2024, with a total potential net variance of up to $10 million allowed for the program. The Virginia Commission is expected to rule on the request in the third quarter 2019. The ultimate outcome of this matter cannot be determined at this time.

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(UNAUDITED)

Affiliate Asset Management Agreements

On March 15, 2019, the Virginia Commission approved an extension of Virginia Natural Gas' asset management agreement with Sequent to March 31, 2021.

FERC Matters

See Note 2 to the financial statements under "FERC Matters – Open Access Transmission Tariff" in Item 8 of the Form 10-K for additional information.

On March 25, 2019, the Alabama Municipal Electric Authority and Cooperative Energy and SCS and the traditional electric operating companiesfiled a formal settlement agreement with the FERC agreeing to a rate reduction based on a 10.6% ROE, with a retroactive effective date of May 10, 2018, and a five-year moratorium on these parties seeking changes to the OATT formula rate. The ultimate outcome of this matter cannot be determined at this time; however, if approved by the FERC as filed, the OATT settlement would not have a material impact on the financial statements of any of the traditional electric operating companies or Southern Company.

(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

Each registrant is subject to certain claims and legal actions arising in the ordinary course of business. In addition, the business activities of Southern Company's subsidiaries are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO₂ and other emissions, CCR, and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters.

The ultimate outcome of such pending or potential litigation against each registrant and any subsidiaries cannot be predicted 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.

Southern Company

In January 2017, a putative securities class action complaint was filed against Southern Company, certain of its officers, and certain former Mississippi Power officers in the U.S. District Court for the Northern District of Georgia by Monroe County Employees' Retirement System on behalf of all persons who purchased shares of Southern Company's common stock between April 25, 2012 and October 29, 2013. The complaint alleges that Southern Company, certain of its officers, and certain former Mississippi Power officers made materially false and misleading statements regarding the Kemper County energy facility in violation of certain provisions under the Securities Exchange Act of 1934, as amended. The complaint seeks, among other things, compensatory damages and litigation costs and attorneys' fees. In 2017, the plaintiffs filed an amended complaint that provided additional detail about their claims, increased the purported class period by one day, and added certain other former Mississippi Power officers as defendants. Also in 2017, the defendants filed a motion to dismiss the plaintiffs' amended complaint with prejudice, to which the plaintiffs filed an opposition. In March 2018, the court issued an order granting, in part, the defendants' motion to dismiss. The court dismissed certain claims against certain officers of Southern Company and Mississippi Power and dismissed the allegations related to a number of the statements that plaintiffs challenged as being false or misleading. In April 2018, the defendants filed a motion for reconsideration of the court's order, seeking dismissal of the remaining claims in the lawsuit. In August 2018, the court denied the motion for reconsideration and denied a motion to certify the issue for interlocutory appeal.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of Georgia. The complaints allege that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints allege that the defendants were unjustly enriched and caused the waste of corporate assets and also allege that the individual defendants violated their fiduciary duties. Each plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. Each plaintiff also seeks certain changes to Southern Company's corporate governance and internal processes. In April 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action.

In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. The complaint alleges that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleges that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. The plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and disgorgement of profits and, on its behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiff also seeks certain unspecified changes to Southern Company's corporate governance and internal processes. In May 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action.

Southern Company believes these legal challenges have no merit; however, an adverse outcome in any of these proceedings could have an impact on Southern Company's results of operations, financial condition, and liquidity. The ultimate outcome of these matters cannot be determined at this time.

Georgia Power

In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state tort law claims. In 2016, the Georgia Court of Appeals reversed the trial court's previous dismissal of the case and remanded the case to the trial court. Georgia Power filed a petition for writ of certiorari with the Georgia Supreme Court, which was granted in 2017. In June 2018, the Georgia Supreme Court affirmed the judgment of the Georgia Court of Appeals and remanded the case to the trial court for further proceedings. Following a motion by Georgia Power, on February 13, 2019, the Superior Court of Fulton County ordered the parties to submit petitions to the Georgia PSC for a declaratory ruling to address certain terms the court previously held were ambiguous as used in the Georgia PSC's orders. The order entered by the Superior Court of Fulton County also conditionally certified the proposed class. In March 2019, Georgia Power and the plaintiffs filed petitions with the Georgia PSC seeking confirmation of the proper application of the municipal franchise fee schedule pursuant to the Georgia PSC's orders. Georgia Power and the plaintiffs also have filed notices of appeal with the Georgia Court of Appeals regarding the Superior Court of Fulton County's February 2019 order. Georgia Power believes the plaintiffs' claims have no merit. The amount of any possible losses cannot be calculated at this time because, among other factors, it is unknown whether conditional class certification will be upheld and the ultimate composition of any class and whether any losses would be subject to recovery from any municipalities. The ultimate outcome of this matter cannot be determined at this time.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Mississippi Power

In May 2018, Southern Company and Mississippi Power received a notice of dispute and arbitration demand filed by Martin Product Sales, LLC (Martin) based on two agreements, both related to Kemper IGCC byproducts for which Mississippi Power provided termination notices in 2017. Martin alleges breach of contract, breach of good faith and fair dealing, fraud and misrepresentation, and civil conspiracy and makes a claim for damages in the amount of approximately $143 million, as well as additional unspecified damages, attorney's fees, costs, and interest. In the first quarter 2019, Mississippi Power and Southern Company filed motions to dismiss. Southern Company and Mississippi Power believe this legal challenge has no merit; however, an adverse outcome in this proceeding could have a material impact on Southern Company's and Mississippi Power's results of operations, financial condition, and liquidity. The ultimate outcome of this matter cannot be determined at this time.

In November 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three current members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi. 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. They also allege that Mississippi Power underpaid customers 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. In response to Mississippi Power and the Mississippi PSC each filing a motion to dismiss, the plaintiffs filed an amended complaint on March 14, 2019. The amended complaint included four additional plaintiffs and additional claims for gross negligence, reckless conduct, and intentional wrongdoing. Mississippi Power and the Mississippi PSC have each filed a motion to dismiss the amended complaint. Mississippi Power believes this legal challenge has no merit; however, an adverse outcome in this proceeding could have a material impact on Mississippi Power's results of operations, financial condition, and liquidity. The ultimate outcome of this matter cannot be determined at this time.

Southern Power

Southern Power indirectly owns a 51% membership interest in RE Roserock LLC (Roserock), the owner of the Roserock facility in Pecos County, Texas. Prior to the facility being placed in service in 2016, certain solar panels were damaged during installation by the construction contractor, McCarthy Building Companies, Inc. (McCarthy), and certain solar panels were damaged by a hail event that also occurred during construction. In connection therewith, Southern Power withheld payment of approximately $26 million to the construction contractor, which placed a lien on the Roserock facility for the same amount. In 2017, Roserock filed a lawsuit in the state district court in Pecos County, Texas against XL Insurance America, Inc. and North American Elite Insurance Company seeking recovery from an insurance policy for damages resulting from the hail event and McCarthy's installation practices. In June 2018, the court granted Roserock's motion for partial summary judgment, finding that the insurers were in breach of contract and in violation of the Texas Insurance Code for failing to pay any monies owed for the hail claim. Separate lawsuits were filed between Roserock and McCarthy, as well as other parties, and that litigation was consolidated in the U.S. District Court for the Western District of Texas. On April 18, 2019, Roserock and the parties to the state and federal lawsuits executed a settlement agreement and mutual release that resolves both lawsuits. Under the agreement, the lawsuits will be dismissed and McCarthy will release its lien following payments of all amounts (which are expected to occur in May 2019). Roserock will pay $26 million to McCarthy that was withheld and included in the original construction costs and will receive funds that will cover all related legal costs and the replacement costs of certain solar panels. In addition, during the first quarter 2019, Roserock received a partial payment of approximately $5 million in insurance proceeds toward the hail event. Any additional funds received in excess of the initial replacement costs are expected to be recognized as a gain when received by Roserock in the second quarter 2019, but are not expected to have a material impact on Southern Power's net income.

155

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

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 compliance 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 $18 million and $23 million as of March 31, 2019 and December 31, 2018, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected.

Southern Company Gas' environmental remediation liability was $289 million and $294 million as of March 31, 2019 and December 31, 2018, respectively, based on the estimated cost of environmental investigation and remediation associated with known current and former manufactured gas plant operating sites. These environmental remediation expenditures are recoverable from customers through rate mechanisms approved by the applicable state regulatory agencies of the natural gas distribution utilities, with the exception of one site representing $2 million of the total accrued remediation costs.

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 Southern Company, Georgia Power, or Southern Company Gas.

Other Matters

Mississippi Power

In conjunction with Southern Company's sale of Gulf Power, Mississippi Power and Gulf Power have committed to seek a restructuring of their 50% undivided ownership interests in Plant Daniel such that each of them would, after the restructuring, own 100% of a generating unit. On January 15, 2019, Gulf Power provided notice to Mississippi Power that Gulf Power will retire its share of the generating capacity of Plant Daniel on January 15, 2024. Mississippi Power has the option to purchase Gulf Power's ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior to that date. Mississippi Power is assessing the potential operational and economic effects of Gulf Power's notice. The ultimate outcome of these matters remains subject to completion of Mississippi Power's evaluations and applicable regulatory approvals, including by the FERC and the Mississippi PSC, and cannot be determined at this time. See Note (K) under "Southern Company" for information regarding the sale of Gulf Power.

(D) REVENUE FROM CONTRACTS WITH CUSTOMERS

The registrants generate revenues from a variety of sources, some of which are excluded from the scope of ASC 606, Revenue from Contracts with Customers (ASC 606), such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 to the financial statements under "Recently Adopted Accounting Standards – Revenue" in Item 8 of the Form 10-K for additional information on the adoption of ASC 606 for revenue from contracts with customers and Note 1 to the financial statements under "Revenues" and "Other Taxes" in Item 8 of the Form 10-K for additional information on the revenue policies of the registrants. For additional information on revenues accounted for under other accounting guidance, see Notes (J) and (L) for energy-related derivative contracts and lessor revenues, respectively, Note 1 to the financial statements under "Revenues – Southern Company Gas" in Item 8 of the Form 10-K for alternative revenue programs at the natural gas distribution utilities, and Note 2 to the financial statements in Item 8 of the Form 10-K for cost recovery mechanisms.

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(UNAUDITED)

The following tables disaggregate revenue sources for the three months ended March 31, 2019 and 2018:

	For the Three Months Ended March 31, 2019			For the Three Months Ended March 31, 2018
	(in millions)
Southern Company
Operating revenues
Retail electric revenues(a)
Residential	$	1,288		$	1,539
Commercial	1,093			1,243
Industrial	677			756
Other	26			30
Natural gas distribution revenues	1,163			1,224
Alternative revenue programs(b)	(2		)	(24		)
Total retail electric and gas distribution revenues	$	4,245		$	4,768
Wholesale energy revenues(c)(d)	367			472
Wholesale capacity revenues(d)	132			151
Other natural gas revenues(e)(f)	313			407
Other revenues(g)	355			574
Total operating revenues	$	5,412		$	6,372

(a) Retail electric revenues include $8 million and $18 million of revenues accounted for as leases for the three months ended March 31, 2019 and 2018, respectively, and a (net reduction) or net increase of $(103) million and $117 million for the three months ended March 31, 2019 and 2018, respectively, from certain cost recovery mechanisms that are not accounted for as revenue under ASC 606.

(b) Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period.

(c) Wholesale energy revenues include $53 million and $93 million for the three months ended March 31, 2019 and 2018, respectively, of revenues accounted for as derivatives, primarily related to physical energy sales in the wholesale electricity market.

(d) Wholesale energy and wholesale capacity revenues include $66 million and $25 million, respectively, for the three months ended March 31, 2019 and $69 million and $30 million, respectively, for the three months ended March 31, 2018 related to PPAs accounted for as leases.

(e) Other natural gas revenues related to Southern Company Gas' energy and risk management activities are presented net of the related costs of those activities and include gross third-party revenues of $1.9 billion for each of the three months ended March 31, 2019 and 2018, of which $1.2 billion and $1.1 billion, respectively, relates to contracts that are accounted for as derivatives. See Note (M) under "Southern Company Gas" for additional information on the components of wholesale gas services operating revenues.

(f) Other natural gas revenues for the three months ended March 31, 2019 include $9 million of revenues accounted for as leases.

(g) Other revenues include $96 million and $90 million for the three months ended March 31, 2019 and 2018, respectively, of revenues not accounted for under ASC 606, including $31 million and $33 million in 2019 and 2018, respectively, accounted for as leases.

157

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(UNAUDITED)

	Alabama Power		Georgia Power		Mississippi Power
	(in millions)
For the Three Months Ended March 31, 2019
Operating revenues
Retail revenues(a)(b)
Residential	$	540	$	688	$	60
Commercial	354		674		65
Industrial	313		289		74
Other	6		17		4
Total retail electric revenues	$	1,213	$	1,668	$	203
Wholesale energy revenues(c)	94		18		78
Wholesale capacity revenues	27		14		1
Other revenues(b)(d)	74		133		5
Total operating revenues	$	1,408	$	1,833	$	287
For the Three Months Ended March 31, 2018
Operating revenues
Retail revenues(a)(b)
Residential	$	570	$	744	$	60
Commercial	371		717		62
Industrial	338		316		70
Other	6		21		2
Total retail electric revenues	$	1,285	$	1,798	$	194
Wholesale energy revenues(c)	101		40		98
Wholesale capacity revenues	24		14		4
Other revenues(b)(d)	63		109		6
Total operating revenues	$	1,473	$	1,961	$	302

(a) Retail revenues at Alabama Power, Georgia Power, and Mississippi Power include a net increase or (net reduction) of $(57) million, $(47) million, and $1 million, respectively, for the three months ended March 31, 2019 and $47 million, $10 million, and $76 million, respectively, for the three months ended March 31, 2018 related to certain cost recovery mechanisms that are not accounted for as revenue under ASC 606.

(b) Retail revenues and other revenues at Georgia Power include $8 million and $11 million, respectively, for the three months ended March 31, 2019 and $18 million and $33 million, respectively, for the three months ended March 31, 2018 of revenues accounted for as leases.

(c) Wholesale energy revenues at Alabama Power, Georgia Power, and Mississippi Power include $3 million, $4 million, and $1 million, respectively, for the three months ended March 31, 2019 and $5 million, $7 million, and $1 million, respectively, for the three months ended March 31, 2018 accounted for as derivatives primarily related to physical energy sales in the wholesale electricity market.

(d) Other revenues at Alabama Power and Georgia Power include $28 million and $31 million, respectively, for the three months ended March 31, 2019 and $25 million and $26 million, respectively, for the three months ended March 31, 2018 of revenues not accounted for under ASC 606.

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(UNAUDITED)

	For the Three Months Ended March 31, 2019		For the Three Months Ended March 31, 2018
	(in millions)
Southern Power
PPA capacity revenues(a)	$	127	$	138
PPA energy revenues(a)	227		254
Non-PPA revenues(b)	85		115
Other revenues	4		2
Total operating revenues	$	443	$	509

(a) PPA capacity revenues and PPA energy revenues include $41 million and $72 million, respectively, for the three months ended March 31, 2019 and $47 million and $76 million, respectively, for the three months ended March 31, 2018 related to PPAs accounted for as leases.

(b) Non-PPA revenues include $45 million and $79 million for the three months ended March 31, 2019 and 2018, respectively, of revenues from short-term sales related to physical energy sales from uncovered capacity in the wholesale electricity market.

	For the Three Months Ended March 31, 2019			For the Three Months Ended March 31, 2018
	(in millions)
Southern Company Gas
Operating revenues
Natural gas distribution revenues
Residential	$	601		$	660
Commercial	170			192
Transportation	256			277
Industrial	17			17
Other	119			78
Alternative revenue programs(a)	(2		)	(24		)
Total natural gas distribution revenues	$	1,161		$	1,200
Gas pipeline investments(b)	8			8
Wholesale gas services(c)	66			146
Gas marketing services(d)	229			271
Other revenues	10			14
Total operating revenues	$	1,474		$	1,639

(a) Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period.

(b) Revenues from gas pipeline investments include $8 million for the three months ended March 31, 2019 accounted for as leases.

(c) Wholesale gas services revenues are presented net of the related costs associated with its energy trading and risk management activities. Operating revenues, as presented, include gross third-party revenues of $1.9 billion for each of the three months ended March 31, 2019 and 2018, of which $1.2 billion and $1.1 billion, respectively, relates to contracts accounted for as derivatives. See Note (M) under "Southern Company Gas" for additional information on the components of wholesale gas services operating revenues.

(d) Gas marketing services includes $6 million and $4 million for the three months ended March 31, 2019 and 2018, respectively, of revenues not accounted for under ASC 606.

159

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Contract Balances

The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers as of March 31, 2019 and December 31, 2018:

	Receivables				Contract Assets				Contract Liabilities
	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018
	(in millions)
Southern Company(*)	$	2,522	$	2,630	$	84	$	102	$	62	$	32
Alabama Power	514		520		1		—		10		12
Georgia Power	668		721		41		58		25		7
Mississippi Power	85		100		—		—		—		—
Southern Power	99		118		—		—		4		11
Southern Company Gas	948		952		—		—		1		2

(*) Includes amounts related to held for sale investments.

As of March 31, 2019 and December 31, 2018, Georgia Power had contract assets primarily related to unregulated service agreements where payment is contingent on project completion and fixed retail customer bill programs where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over the one-year contract term. Alabama Power had contract liabilities for outstanding performance obligations primarily related to extended service agreements. Contract liabilities for Georgia Power and Southern Power relate to cash collections recognized in advance of revenue for certain unregulated service agreements and certain levelized PPAs, respectively. Southern Company's unregulated distributed generation business had $34 million and $39 million of contract assets and $25 million and $11 million of contract liabilities at March 31, 2019 and December 31, 2018, respectively, remaining for outstanding performance obligations.

The following table reflects revenue from contracts with customers recognized in the three-month period ended March 31, 2019 included in the contract liability at December 31, 2018:

	Three Months Ended March 31, 2019
	(in millions)
Southern Company	$	17
Southern Power	10

Revenues recognized in the three-month period ended March 31, 2019, which were included in contract liabilities at December 31, 2018, were immaterial for Alabama Power, Georgia Power, and Southern Company Gas.

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(UNAUDITED)

Remaining Performance Obligations

The traditional electric operating companies and Southern Power have long-term contracts with customers in which revenues are recognized when the performance obligations are satisfied during the contract term. These contracts primarily relate to PPAs whereby the traditional electric operating companies and Southern Power provide electricity and generation capacity to a customer. The revenue recognized for the delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Registrants with revenues from contracts with customers related to these performance obligations remaining at March 31, 2019 expect the revenues to be recognized as follows:

	2019 (remaining)		2020		2021		2022		2023		Thereafter
	(in millions)
Southern Company(*)	$	451	$	349	$	315	$	310	$	301	$	2,219
Alabama Power	16		22		27		23		22		140
Georgia Power	30		38		40		30		31		82
Mississippi Power	2		3		1		—		—		—
Southern Power	248		295		270		276		269		2,143

(*) Includes amounts related to held for sale investments.

(E) CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS

Southern Power

Variable Interest Entities

See Note 7 to the financial statements in Item 8 of the Form 10-K for additional information on Southern Power's VIEs.

Southern Power has certain wholly-owned 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. Southern Power previously consolidated SP Solar and SP Wind. Southern Power continues to consolidate them following the 2018 sales of noncontrolling interests in each entity, as the primary beneficiary of each VIE, since it controls the most significant activities of each entity, including operating and maintaining their assets. Transfers and sales of the assets in the VIEs are subject to limited 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.

SP Solar

At March 31, 2019, SP Solar had total assets of $6.5 billion, total liabilities of $373 million, and noncontrolling interests of $1.2 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves.

SP Wind

At March 31, 2019, SP Wind had total assets of $2.6 billion, total liabilities of $141 million, and noncontrolling interests of $46 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

161

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(UNAUDITED)

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 Company Gas

See Note 7 to the financial statements in Item 8 of the Form 10-K for additional information on Southern Company Gas' equity method investments.

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments as of March 31, 2019 and December 31, 2018 and related income from those investments for the three-month periods ended March 31, 2019 and 2018 were as follows:

Investment Balance	March 31, 2019		December 31, 2018
	(in millions)
SNG	$	1,262	$	1,261
Atlantic Coast Pipeline	96		83
PennEast Pipeline	75		71
Other	124		123
Total	$	1,557	$	1,538

Earnings from Equity Method Investments	Three Months Ended March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
SNG	$	42	$	39
Atlantic Coast Pipeline	3		1
PennEast Pipeline	2		1
Other	1		1
Total	$	48	$	42

SNG

Selected financial information of SNG for the three months ended March 31, 2019 and 2018 is as follows:

Income Statement Information	Three Months Ended March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
Revenues	$	166	$	160
Operating income	106		99
Net income	84		78

(F) FINANCING

Bank Credit Arrangements

Bank credit arrangements provide liquidity support to the registrants' commercial paper borrowings and the traditional electric operating companies' revenue bonds. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support as of March 31, 2019 was approximately $1.4 billion (comprised of approximately $854 million at Alabama Power, $550 million at Georgia

162

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(UNAUDITED)

Power, and $40 million at Mississippi Power). In addition, at March 31, 2019, the traditional electric operating companies had approximately $432 million (comprised of approximately $87 million at Alabama Power and $345 million at Georgia Power) of revenue bonds outstanding that were required to be remarketed within the next 12 months. Subsequent to March 31, 2019, Georgia Power purchased and held approximately $115 million of outstanding pollution control revenue bonds required to be remarketed. See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K and "Financing Activities" herein for additional information.

The following table outlines the committed credit arrangements by company as of March 31, 2019:

	Expires
Company	2019		2020		2022		Total		Unused(d)
	(in millions)
Southern Company(a)	$	—	$	—	$	2,000	$	2,000	$	1,999
Alabama Power	33		500		800		1,333		1,333
Georgia Power	—		—		1,750		1,750		1,736
Mississippi Power	100		—		—		100		100
Southern Power(b)	—		—		750		750		741
Southern Company Gas(c)	—		—		1,900		1,900		1,895
Other	30		—		—		30		30
Southern Company Consolidated	$	163	$	500	$	7,200	$	7,863	$	7,834

(a) Represents the Southern Company parent entity.

(b) Does not include Southern Power Company's $120 million continuing letter of credit facility for standby letters of credit expiring in 2021, of which $24 million was unused at March 31, 2019. Southern Power's subsidiaries are not parties to its bank credit arrangement.

(c) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $1.4 billion of this arrangement. Southern Company Gas' committed credit arrangement also includes $500 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to this multi-year credit arrangement, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

(d) Amounts used are for letters of credit.

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.

DOE Loan Guarantee 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 regarding Georgia Power's 2014 loan guarantee agreement.

Pursuant to the loan guarantee program established under Title XVII of the Energy Policy Act of 2005 (Title XVII Loan Guarantee Program), Georgia Power and the DOE entered into a loan guarantee agreement in 2014 and the Amended and Restated Loan Guarantee Agreement in March 2019. Under the Amended and Restated Loan Guarantee Agreement, the DOE has agreed to guarantee the obligations of Georgia Power under note purchase agreements among the DOE, Georgia Power, and the FFB and related promissory notes which provide for two multi-advance term loan facilities (FFB Credit Facilities). Under the FFB Credit Facilities, Georgia Power may make term loan borrowings through the FFB in an amount up to approximately $5.130 billion, provided that total aggregate borrowings under the FFB Credit Facilities may not exceed 70% of (i) Eligible Project Costs minus (ii) approximately $1.492 billion (reflecting the amounts received by Georgia Power under the Guarantee Settlement Agreement less the Customer Refunds).

In March 2019, Georgia Power made borrowings under the FFB Credit Facilities in an aggregate principal amount of $835 million at an interest rate of 3.213% through the final maturity date of February 20, 2044. At March 31, 2019, Georgia Power had a total of $3.46 billion of borrowings outstanding under the FFB Credit Facilities.

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(UNAUDITED)

All borrowings under the FFB Credit Facilities are full recourse to Georgia Power, and Georgia Power is obligated to reimburse the DOE for any payments the DOE is required to make to the FFB under its guarantee. Georgia Power's reimbursement obligations to the DOE are full recourse and secured by a first priority lien on (i) Georgia Power's 45.7% undivided ownership interest in Plant Vogtle Units 3 and 4 (primarily the units under construction, the related real property, and any nuclear fuel loaded in the reactor core) and (ii) Georgia Power's rights and obligations under the principal contracts relating to Plant Vogtle Units 3 and 4. There are no restrictions on Georgia Power's ability to grant liens on other property.

In addition to the conditions described above, future advances are subject to satisfaction of customary conditions, as well as certification of compliance with the requirements of the Title XVII Loan Guarantee Program, including accuracy of project-related representations and warranties, delivery of updated project-related information, and evidence of compliance with the prevailing wage requirements of the Davis-Bacon Act of 1931, as amended, and certification from the DOE's consulting engineer that proceeds of the advances are used to reimburse Eligible Project Costs.

Upon satisfaction of all conditions described above, advances may be requested on a quarterly basis through 2023. The final maturity date for each advance under the FFB Credit Facilities is February 20, 2044. Interest is payable quarterly and principal payments will begin on February 20, 2020. Borrowings under the FFB Credit Facilities will bear interest at the applicable U.S. Treasury rate plus a spread equal to 0.375%.

Under the Amended and Restated Loan Guarantee Agreement, Georgia Power is subject to customary borrower affirmative and negative covenants and events of default. In addition, Georgia Power is subject to project-related reporting requirements and other project-specific covenants and events of default.

In the event certain mandatory prepayment events occur, the FFB's commitment to make further advances under the FFB Credit Facilities will terminate and Georgia Power will be required to prepay the outstanding principal amount of all borrowings under the FFB Credit Facilities over a period of five years (with level principal amortization). Among other things, these mandatory prepayment events include (i) the termination of the Vogtle Services Agreement or rejection of the Vogtle Services Agreement in any Westinghouse bankruptcy if Georgia Power does not maintain access to intellectual property rights under the related intellectual property licenses; (ii) termination of the Bechtel Agreement, unless the Vogtle Owners enter into a replacement agreement; (iii) cancellation of Plant Vogtle Units 3 and 4 by the Georgia PSC or by Georgia Power; (iv) failure of the holders of 90% of the ownership interests in Plant Vogtle Units 3 and 4 to vote to continue construction following certain schedule extensions; (v) cost disallowances by the Georgia PSC that could have a material adverse effect on completion of Plant Vogtle Units 3 and 4 or Georgia Power's ability to repay the outstanding borrowings under the FFB Credit Facilities; or (vi) loss of or failure to receive necessary regulatory approvals. Under certain circumstances, insurance proceeds and any proceeds from an event of taking must be applied to immediately prepay outstanding borrowings under the FFB Credit Facilities. In addition, if Georgia Power discontinues construction of Plant Vogtle Units 3 and 4, Georgia Power would be obligated to immediately repay a portion of the outstanding borrowings under the FFB Credit Facilities to the extent such outstanding borrowings exceed 70% of Eligible Project Costs, net of the proceeds received by Georgia Power under the Guarantee Settlement Agreement less the Customer Refunds. Georgia Power also may voluntarily prepay outstanding borrowings under the FFB Credit Facilities. Under the FFB Credit Facilities, any prepayment (whether mandatory or optional) will be made with a make-whole premium or discount, as applicable.

In connection with any cancellation of Plant Vogtle Units 3 and 4, the DOE may elect to continue construction of Plant Vogtle Units 3 and 4. In such an event, the DOE will have the right to assume Georgia Power's rights and obligations under the principal agreements relating to Plant Vogtle Units 3 and 4 and to acquire all or a portion of Georgia Power's ownership interest in Plant Vogtle Units 3 and 4.

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(UNAUDITED)

Financing Activities

The following table outlines the long-term debt financing activities for Southern Company and its subsidiaries for the first three months of 2019:

Company	Senior Note Maturities, Redemptions, and Repurchases		Revenue Bond Issuances and Reofferings of Purchased Bonds		Revenue Bond Maturities, Redemptions, and Repurchases		Other Long-Term Debt Issuances		Other Long-Term Debt Redemptions and Maturities(a)
	(in millions)
Southern Company(b)	$	2,100	$	—	$	—	$	—	$	—
Alabama Power	200		—		—		—		—
Georgia Power	—		343		108		835		2
Mississippi Power	—		43		—		—		—
Other	—		—		—		—		19
Southern Company Consolidated	$	2,300	$	386	$	108	$	835	$	21

(a) Includes reductions in finance lease obligations resulting from cash payments under finance leases.

(b) Represents the Southern Company parent entity.

Except as otherwise described herein, Southern Company and its subsidiaries 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 subsidiaries also used the proceeds for their construction programs.

Southern Company

In January 2019, Southern Company repaid a $250 million short-term uncommitted bank credit arrangement and a $1.5 billion short-term floating rate bank loan.

Also in January 2019, through cash tender offers, Southern Company repurchased and retired approximately $522 million of the $1.0 billion aggregate principal amount outstanding of its 1.85% Senior Notes due July 1, 2019 (1.85% Notes), approximately $180 million of the $350 million aggregate principal amount outstanding of its Series 2014B 2.15% Senior Notes due September 1, 2019 (Series 2014B Notes), and approximately $504 million of the $750 million aggregate principal amount outstanding of its Series 2018A Floating Rate Notes due February 14, 2020 (Series 2018A Notes), for an aggregate purchase price, excluding accrued and unpaid interest, of approximately $1.2 billion. In addition, following the completion of the cash tender offers, in February 2019, Southern Company completed the redemption of all of the Series 2018A Notes, 1.85% Notes, and Series 2014B Notes remaining outstanding.

Georgia Power

In January 2019, Georgia Power redeemed approximately $13 million, $20 million, and $75 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 1992, Eighth Series 1994, and Second Series 1995, respectively.

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(UNAUDITED)

In March 2019, Georgia Power reoffered to the public the following pollution control revenue bonds that previously had been purchased and held by Georgia Power:

• $173 million aggregate principal amount of Development Authority of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Bowen Project), First Series 2009;

• approximately $105 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 2013; and

• $65 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 2008.

Subsequent to March 31, 2019, Georgia Power purchased and held the following pollution control revenue bonds, which may be reoffered to the public at a later date:

• $55 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1994;

• $30 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1995;

• $20 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Ninth Series 1994; and

• $10 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 1994.

Mississippi Power

In March 2019, Mississippi Power reoffered to the public $43 million of Mississippi Business Finance Corporation Pollution Control Revenue Refunding Bonds, Series 2002, that previously had been purchased and held by Mississippi Power.

Earnings per Share

For Southern Company, the only difference in computing basic and diluted earnings per share is attributable to awards outstanding under stock-based compensation plans. See Note 12 to the financial statements in Item 8 of the Form 10-K for information on stock-based compensation plans. The effect of stock-based compensation plans was determined using the treasury stock method. Shares used to compute diluted earnings per share were as follows:

	Three Months Ended March 31, 2019	Three Months Ended March 31, 2018
	(in millions)
As reported shares	1,038	1,011
Effect of stock-based compensation	7	5
Diluted shares	1,045	1,016

There were no stock-based compensation awards that were not included in the diluted earnings per share calculation because they were anti-dilutive for the three months ended March 31, 2019 and an immaterial amount of such awards was not included for the three months ended March 31, 2018.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

(G) INCOME TAXES

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

Effective Tax Rate

Details of significant changes in the effective tax rate for the applicable registrants are provided herein.

Southern Company

Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity and flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs, primarily at Southern Power.

Southern Company's effective tax rate was 39.8% for the three months ended March 31, 2019 compared to 10.8% for the corresponding period in 2018. The effective tax rate increase was primarily due to the tax impact from the sale of Gulf Power. See Note (K) for additional information.

Alabama Power

Alabama Power's effective tax rate was 21.9% for the three months ended March 31, 2019 compared to 26.3% for the corresponding period in 2018. The effective tax rate decrease was primarily due to the application in 2018 of the accounting order approved by the Alabama PSC in May 2018 related to the Tax Reform Legislation. See Note 2 to the financial statements under "Alabama Power – Tax Reform Accounting Order" in Item 8 of the Form 10-K for additional information.

Mississippi Power

Mississippi Power's effective tax rate was 15.5% for the three months ended March 31, 2019 compared to a benefit rate of (34.7)% for the corresponding period in 2018. The effective tax rate increase was primarily due to lower estimated losses on the Kemper IGCC in 2019, partially offset by an increase in the flowback of excess deferred income taxes as a result of a settlement agreement reached with wholesale customers under the MRA tariff. See Note (B) under "Mississippi Power" for additional information.

Southern Power

Southern Power's effective tax benefit rate was (49.8)% for the three months ended March 31, 2019 compared to (647.0)% for the corresponding period in 2018. The effective tax benefit rate decrease was primarily due to changes in state apportionment rates following the reorganization of Southern Power's legal entities that own and operate certain solar facilities and a reduction of tax benefits from wind PTCs primarily as a result of the sale of a noncontrolling tax equity interest in SP Wind.

Southern Company Gas

Southern Company Gas' effective tax rate was 22.3% for the three months ended March 31, 2019 compared to 27.2% for the corresponding period in 2018. This decrease was primarily related to tax impacts of the goodwill impairment charge recorded in the first quarter 2018 and an increase in the flowback of excess deferred income taxes in 2019 primarily at Atlanta Gas Light as previously authorized by the Georgia PSC. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

(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, 2019. The Southern

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(UNAUDITED)

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.

Components of the net periodic benefit costs for the three months ended March 31, 2019 and 2018 are presented in the following tables.

Three Months Ended March 31, 2019	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Power			Southern Company Gas
	(in millions)
Pension Plans
Service cost	$	73		$	17		$	19		$	3		$	2		$	6
Interest cost	123			28			39			6			1			9
Expected return on plan assets	(221		)	(51		)	(73		)	(10		)	(2		)	(15		)
Amortization:
Prior service costs	—			—			—			—			—			(1		)
Regulatory asset	—			—			—			—			—			3
Net (gain)/loss	30			9			11			1			—			1
Net periodic pension cost (income)	$	5		$	3		$	(4	)	$	—		$	1		$	3
Postretirement Benefits
Service cost	$	5		$	1		$	1		$	—		$	—		$	1
Interest cost	17			4			7			1			—			2
Expected return on plan assets	(16		)	(6		)	(6		)	—			—			(2		)
Amortization:
Prior service costs	1			1			—			—			—			—
Regulatory asset	—			—			—			—			—			2
Net (gain)/loss	(1		)	—			—			—			—			(1		)
Net periodic postretirement benefit cost	$	6		$	—		$	2		$	1		$	—		$	2

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Three Months Ended March 31, 2018	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Power			Southern Company Gas
	(in millions)
Pension Plans
Service cost	$	90		$	19		$	22		$	4		$	2		$	8
Interest cost	116			25			35			5			1			10
Expected return on plan assets	(236		)	(51		)	(74		)	(10		)	(3		)	(18		)
Amortization:
Prior service costs	1			—			—			—			—			(1		)
Regulatory asset	—			—			—			—			—			3
Net (gain)/loss	53			14			17			3			1			3
Net periodic pension cost (income)	$	24		$	7		$	—		$	2		$	1		$	5
Postretirement Benefits
Service cost	$	6		$	1		$	2		$	—		$	—		$	1
Interest cost	19			4			7			1			—			2
Expected return on plan assets	(17		)	(6		)	(6		)	—			—			(2		)
Amortization:
Prior service costs	2			1			—			—			—			—
Regulatory asset	—			—			—			—			—			1
Net (gain)/loss	3			—			2			—			—			—
Net periodic postretirement benefit cost	$	13		$	—		$	5		$	1		$	—		$	2

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

(I) FAIR VALUE MEASUREMENTS

As of March 31, 2019, 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:
As of March 31, 2019:	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)(b)	$	322	$	128	$	4	$	—	$	454
Foreign currency derivatives	—		38		—		—		38
Investments in trusts:(c)(d)
Domestic equity	682		120		—		—		802
Foreign equity	60		195		—		—		255
U.S. Treasury and government agency securities	—		283		—		—		283
Municipal bonds	—		73		—		—		73
Pooled funds – fixed income	—		14		—		—		14
Corporate bonds	24		298		—		—		322
Mortgage and asset backed securities	—		72		—		—		72
Private equity	—		—		—		48		48
Cash and cash equivalents	1		—		—		—		1
Other	28		4		—		—		32
Cash equivalents	907		3		—		—		910
Other investments	9		14		—		—		23
Total	$	2,033	$	1,242	$	4	$	48	$	3,327
Liabilities:
Energy-related derivatives(a)(b)	$	466	$	106	$	23	$	—	$	595
Interest rate derivatives	—		35		—		—		35
Foreign currency derivatives	—		24		—		—		24
Contingent consideration	—		—		21		—		21
Total	$	466	$	165	$	44	$	—	$	675

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

	Fair Value Measurements Using:
As of March 31, 2019:	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	$	—	$	6	$	—	$	—	$	6
Nuclear decommissioning trusts:(c)
Domestic equity	446		108		—		—		554
Foreign equity	60		57		—		—		117
U.S. Treasury and government agency securities	—		18		—		—		18
Municipal bonds	—		1		—		—		1
Corporate bonds	24		139		—		—		163
Mortgage and asset backed securities	—		24		—		—		24
Private equity	—		—		—		48		48
Other	5		—		—		—		5
Cash equivalents	569		3		—		—		572
Other investments	—		14		—		—		14
Total	$	1,104	$	370	$	—	$	48	$	1,522
Liabilities:
Energy-related derivatives	$	—	$	7	$	—	$	—	$	7
Georgia Power
Assets:
Energy-related derivatives	$	—	$	9	$	—	$	—	$	9
Nuclear decommissioning trusts:(c)(d)
Domestic equity	236		1		—		—		237
Foreign equity	—		134		—		—		134
U.S. Treasury and government agency securities	—		265		—		—		265
Municipal bonds	—		72		—		—		72
Corporate bonds	—		160		—		—		160
Mortgage and asset backed securities	—		47		—		—		47
Other	23		4		—		—		27
Total	$	259	$	692	$	—	$	—	$	951
Liabilities:
Energy-related derivatives	$	—	$	16	$	—	$	—	$	16
Interest rate derivatives	—		2		—		—		2
Total	$	—	$	18	$	—	$	—	$	18

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

	Fair Value Measurements Using:
As of March 31, 2019:	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	$	—	$	3	$	—	$	—	$	3
Cash equivalents	202		—		—		—		202
Total	$	202	$	3	$	—	$	—	$	205
Liabilities:
Energy-related derivatives	$	—	$	6	$	—	$	—	$	6
Southern Power
Assets:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1
Foreign currency derivatives	—		38		—		—		38
Cash equivalents	10		—		—		—		10
Total	$	10	$	39	$	—	$	—	$	49
Liabilities:
Energy-related derivatives	$	—	$	3	$	—	$	—	$	3
Foreign currency derivatives	—		24		—		—		24
Contingent consideration	—		—		21		—		21
Total	$	—	$	27	$	21	$	—	$	48
Southern Company Gas
Assets:
Energy-related derivatives(a)(b)	$	322	$	108	$	4	$	—	$	434
Non-qualified deferred compensation trusts:
Domestic equity	—		11		—		—		11
Foreign equity	—		4		—		—		4
Pooled funds – fixed income	—		14		—		—		14
Cash equivalents	1		—		—		—		1
Cash equivalents	13		—		—		—		13
Total	$	336	$	137	$	4	$	—	$	477
Liabilities:
Energy-related derivatives(a)(b)	$	466	$	73	$	23	$	—	$	562

(a) Energy-related derivatives exclude $11 million associated with premiums and certain weather derivatives accounted for based on intrinsic value rather than fair value.

(b) Energy-related derivatives exclude cash collateral of $190 million.

(c) 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.

(d) Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. As of March 31, 2019, approximately $72 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

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 for the three months ended March 31, 2019 and decreased for the three months ended March 31, 2018 by the amounts shown in the table below. 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 March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
Southern Company	$	152	$	(11	)
Alabama Power	87		(5		)
Georgia Power	65		(6		)

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 Southern Power 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 obligation is 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.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

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.

As of March 31, 2019, the fair value measurements of private equity investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $48 million and unfunded commitments related to the private equity investments totaled $49 million. Private equity funds include funds-of-funds that invest in high-quality private equity funds across several market sectors, funds that invest in real estate assets, and a fund that acquires companies to create resale value. Private equity funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated.

As of March 31, 2019, 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 millions)
Long-term debt, including securities due within one year:
Carrying amount	$	42,535	$	7,921	$	10,910	$	1,619	$	4,995	$	5,928
Fair value	43,910		8,424		11,249		1,619		5,131		6,176

(*) The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the Merger. Southern Company Gas amortizes the fair value adjustments over the lives of the respective bonds.

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 Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas.

Commodity Contracts with Level 3 Valuation Inputs

As of March 31, 2019, the fair value of Southern Company Gas' Level 3 physical natural gas forward contracts was $19 million. Since commodity contracts classified as Level 3 typically include a combination of observable and unobservable components, the changes in fair value may include amounts due in part to observable market factors, or changes to assumptions on the unobservable components. The following table includes transfers to Level 3, which represent the fair value of Southern Company Gas' commodity derivative contracts that include a significant unobservable component for the first time during the period.

	Three Months Ended March 31, 2019
	(in millions)
Beginning balance	$	—
Transfers to Level 3	(30		)
Changes in fair value	11
Ending balance	$	(19	)

Changes in fair value of Level 3 instruments represent changes in gains and losses for the periods that are reported on Southern Company Gas' statements of income in natural gas revenues.

The valuation of certain commodity contracts requires the use of certain unobservable inputs. All forward pricing used in the valuation of such contracts is directly based on third-party market data, such as broker quotes and exchange settlements, when that data is available. If third-party market data is not available, then industry standard methodologies are used to develop inputs that maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Observable inputs, including some forward prices used for determining fair value, reflect the best available market information. Unobservable inputs are updated using industry standard techniques such as

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(UNAUDITED)

extrapolation, combining observable forward inputs supplemented by historical market and other relevant data. Level 3 physical natural gas forward contracts include unobservable forward price inputs (ranging from $0.07 to $1.15 per mmBtu). Forward price increases (decreases) as of March 31, 2019 would have resulted in higher (lower) values on a net basis.

(J) DERIVATIVES

Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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. Southern Company Gas' wholesale gas operations use various contracts in its commercial activities that generally meet the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with 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 traditional electric operating companies, Southern Power, and Southern Company Gas 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 of operating margins 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.

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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 the respective fuel cost recovery clauses.

• 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, 2019, 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(*)	538	2022	2029
Alabama Power	72	2022	—
Georgia Power	153	2022	—
Mississippi Power	61	2022	—
Southern Power	9	2020	—
Southern Company Gas(*)	243	2021	2029

(*) Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 3.8 billion mmBtu and short natural gas positions of 3.6 billion mmBtu as of March 31, 2019, 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 40 million mmBtu for Southern Company, which includes 6 million mmBtu for Alabama Power, 12 million mmBtu for Georgia Power, 5 million mmBtu for Mississippi Power, and 13 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 next 12-month period ending March 31, 2020 are immaterial for all registrants.

Interest Rate Derivatives

Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. The derivatives employed as hedging instruments are structured to minimize ineffectiveness. Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow

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(UNAUDITED)

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, 2019, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2019
	(in millions)					(in millions)
Fair Value Hedges of Existing Debt
Southern Company(*)	$	300	2.75%	3-month LIBOR+0.92%	June 2020	$	(3	)
Southern Company(*)	1,500		2.35%	1-month LIBOR+0.87%	July 2021	(30		)
Georgia Power	200		4.25%	3-month LIBOR+2.46%	December 2019	(2		)
Southern Company Consolidated	$	2,000				$	(35	)

(*) Represents the Southern Company parent entity.

The estimated pre-tax gains (losses) related to interest rate derivatives expected to be reclassified from accumulated OCI to interest expense for the next 12-month period ending March 31, 2020 are $(19) million for Southern Company and immaterial for all other registrants. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2046 for the Southern Company parent entity, 2035 for Alabama Power, 2037 for 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. The derivatives employed as hedging instruments are structured to minimize ineffectiveness.

At March 31, 2019, 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, 2019
	(in millions)			(in millions)				(in millions)
Cash Flow Hedges of Existing Debt
Southern Power	$	677	2.95%	€	600	1.00%	June 2022	$	2
Southern Power	564		3.78%	500		1.85%	June 2026	11
Total	$	1,241		€	1,100			$	13

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(UNAUDITED)

The estimated pre-tax gains (losses) related to Southern Power's foreign currency derivatives expected to be reclassified from accumulated OCI to earnings for the next 12-month period ending March 31, 2020 are $(24) million.

Derivative Financial Statement Presentation and Amounts

Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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 sheet are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.

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(UNAUDITED)

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

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	12		$	10		$	8		$	23
Other deferred charges and assets/Other deferred credits and liabilities	11			21			9			26
Assets held for sale, current/Liabilities held for sale, current	—			—			—			6
Total derivatives designated as hedging instruments for regulatory purposes	$	23		$	31		$	17		$	55
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	1		$	3		$	3		$	7
Other deferred charges and assets/Other deferred credits and liabilities	—			1			1			2
Interest rate derivatives:
Other current assets/Other current liabilities	—			20			—			19
Other deferred charges and assets/Other deferred credits and liabilities	—			15			—			30
Foreign currency derivatives:
Other current assets/Other current liabilities	—			24			—			23
Other deferred charges and assets/Other deferred credits and liabilities	38			—			75			—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	39		$	63		$	79		$	81
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	259		$	291		$	561		$	575
Other deferred charges and assets/Other deferred credits and liabilities	171			269			180			325
Total derivatives not designated as hedging instruments	$	430		$	560		$	741		$	900
Gross amounts recognized	$	492		$	654		$	837		$	1,036
Gross amounts offset(a)	$	(333	)	$	(523	)	$	(524	)	$	(801	)
Net amounts recognized in the Balance Sheets(b)	$	159		$	131		$	313		$	235

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(UNAUDITED)

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	3		$	2		$	3		$	4
Other deferred charges and assets/Other deferred credits and liabilities	3			5			3			6
Total derivatives designated as hedging instruments for regulatory purposes	$	6		$	7		$	6		$	10
Gross amounts recognized	$	6		$	7		$	6		$	10
Gross amounts offset	$	(5	)	$	(5	)	$	(4	)	$	(4	)
Net amounts recognized in the Balance Sheets	$	1		$	2		$	2		$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	4		$	5		$	2		$	8
Other deferred charges and assets/Other deferred credits and liabilities	5			11			4			13
Total derivatives designated as hedging instruments for regulatory purposes	$	9		$	16		$	6		$	21
Derivatives designated as hedging instruments in cash flow and fair value hedges
Interest rate derivatives:
Other current assets/Other current liabilities	$	—		$	2		$	—		$	2
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	—		$	2		$	—		$	2
Gross amounts recognized	$	9		$	18		$	6		$	23
Gross amounts offset	$	(8	)	$	(8	)	$	(6	)	$	(6	)
Net amounts recognized in the Balance Sheets	$	1		$	10		$	—		$	17

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(UNAUDITED)

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	2		$	2		$	1		$	3
Other deferred charges and assets/Other deferred credits and liabilities	1			4			2			6
Total derivatives designated as hedging instruments for regulatory purposes	$	3		$	6		$	3		$	9
Gross amounts recognized	$	3		$	6		$	3		$	9
Gross amounts offset	$	(3	)	$	(3	)	$	(2	)	$	(2	)
Net amounts recognized in the Balance Sheets	$	—		$	3		$	1		$	7
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	1		$	2		$	3		$	6
Other deferred charges and assets/Other deferred credits and liabilities	—			1			1			2
Foreign currency derivatives:
Other current assets/Other current liabilities	—			24			—			23
Other deferred charges and assets/Other deferred credits and liabilities	38			—			75			—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	39		$	27		$	79		$	31
Gross amounts recognized	$	39		$	27		$	79		$	31
Gross amounts offset	$	(1	)	$	(1	)	$	(3	)	$	(3	)
Net amounts recognized in the Balance Sheets	$	38		$	26		$	76		$	28
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	$	3		$	1		$	2		$	8
Other deferred charges and assets/Other deferred credits and liabilities	1			—			—			1
Total derivatives designated as hedging instruments for regulatory purposes	$	4		$	1		$	2		$	9
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-current	$	—		$	1		$	—		$	1
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	—		$	1		$	—		$	1

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(UNAUDITED)

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	$	259		$	291		$	559		$	574
Other deferred charges and assets/Other deferred credits and liabilities	171			269			180			325
Total derivatives not designated as hedging instruments	$	430		$	560		$	739		$	899
Gross amounts of recognized	$	434		$	562		$	741		$	909
Gross amounts offset(a)	$	(316	)	$	(506	)	$	(508	)	$	(785	)
Net amounts recognized in the Balance Sheets(b)	$	118		$	56		$	233		$	124

(a) Gross amounts offset include cash collateral held on deposit in broker margin accounts of $190 million and $277 million as of March 31, 2019 and December 31, 2018, respectively.

(b) Net amounts of derivative instruments outstanding exclude premium and intrinsic value associated with weather derivatives of $11 million and $8 million as of March 31, 2019 and December 31, 2018, respectively.

At March 31, 2019 and December 31, 2018, 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 at March 31, 2019
Derivative Category and Balance Sheet Location	Southern Company(*)			Alabama Power			Georgia Power			Mississippi Power			Southern Company Gas(*)
	(in millions)
Energy-related derivatives:
Other regulatory assets, current	$	(5	)	$	(1	)	$	(2	)	$	(1	)	$	(1	)
Other regulatory assets, deferred	(11		)	(2		)	(6		)	(3		)	—
Other regulatory liabilities, current	7			1			1			1			4
Total energy-related derivative gains (losses)	$	(9	)	$	(2	)	$	(7	)	$	(3	)	$	3

(*) Fair value gains and losses recorded in regulatory assets and liabilities include cash collateral held on deposit in broker margin accounts of $2 million at March 31, 2019.

Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet at December 31, 2018
Derivative Category and Balance Sheet Location	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Company Gas
	(in millions)
Energy-related derivatives:
Other regulatory assets, current	$	(19	)	$	(3	)	$	(6	)	$	(2	)	$	(8	)
Other regulatory assets, deferred	(16		)	(3		)	(9		)	(4		)	—
Assets held for sale, current	(6		)	—			—			—			—
Other regulatory liabilities, current	1			—			—			—			1
Total energy-related derivative gains (losses)	$	(40	)	$	(6	)	$	(15	)	$	(6	)	$	(7	)

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(UNAUDITED)

For the three months ended March 31, 2019 and 2018, the pre-tax effects of cash flow hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Southern Company
Energy-related derivatives	$	—		$	12
Interest rate derivatives	—			(2		)
Foreign currency derivatives	(39		)	53
Total	$	(39	)	$	63
Southern Power
Energy-related derivatives	$	—		$	11
Foreign currency derivatives	(39		)	53
Total	$	(39	)	$	64

For the three months ended March 31, 2019 and 2018, the pre-tax effects of energy-related derivatives and interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other registrants.

For the three months ended March 31, 2019 and 2018, 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,
	2019			2018
	(in millions)
Southern Company
Total depreciation and amortization	$	751		$	769
Gain (loss) on energy-related cash flow hedges(a)	(3		)	1
Total interest expense, net of amounts capitalized	(430		)	(458		)
Gain (loss) on interest rate cash flow hedges(a)	(5		)	(5		)
Gain (loss) on foreign currency cash flow hedges(a)	(6		)	(5		)
Gain (loss) on interest rate fair value hedges(b)	14			(24		)
Total other income (expense), net	78			60
Gain (loss) on foreign currency cash flow hedges(a)(c)	(24		)	36
Southern Power
Total depreciation and amortization	$	119		$	114
Gain (loss) on energy-related cash flow hedges(a)	(3		)	1
Total interest expense, net of amounts capitalized	(44		)	(47		)
Gain (loss) on foreign currency cash flow hedges(a)	(6		)	(5		)
Total other income (expense), net	2			3
Gain (loss) on foreign currency cash flow hedges(a)(c)	(24		)	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.

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(UNAUDITED)

For the three months ended March 31, 2019 and 2018, 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 and Southern Company Gas.

As of March 31, 2019 and December 31, 2018, 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	As of March 31, 2019			As of December 31, 2018			As of March 31, 2019		As of December 31, 2018
	(in millions)						(in millions)
Southern Company
Securities due within one year	$	(499	)	$	(498	)	$	1	$	2
Long-term debt	(2,065		)	(2,052		)	28		41
Georgia Power
Securities due within one year	$	(499	)	$	(498	)	$	1	$	2
Long-term debt	—			—			—		—

For the three months ended March 31, 2019 and 2018, 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	2019		2018
		(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	33	$	(15	)
	Cost of natural gas	8		2
Total derivatives in non-designated hedging relationships		$	41	$	(13	)

(*) Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for the three months ended March 31, 2019 and 2018.

For the three months ended March 31, 2019 and 2018, the pre-tax effects of energy-related derivatives and interest rate derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies and Southern Power.

Contingent Features

Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas do not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. At March 31, 2019, the registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For the registrants with interest rate derivatives at March 31, 2019, 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, was immaterial. At March 31, 2019, the fair value of 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 for all

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(UNAUDITED)

registrants. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Following the sale of Gulf Power to NextEra Energy, Gulf Power is continuing to participate in the Southern Company power pool for a defined transition period that, subject to certain potential adjustments, is scheduled to end on January 1, 2024.

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

Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Alabama Power and Southern Power may be required to post collateral. At March 31, 2019, cash collateral posted in these accounts was immaterial. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At March 31, 2019, cash collateral held on deposit in broker margin accounts was $190 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. Prior to entering into a physical transaction, Southern Company Gas assigns physical wholesale counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch Ratings Inc. ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.

In addition, Southern Company Gas conducts credit evaluations and obtains appropriate internal approvals for the counterparty's line of credit before any transaction with the counterparty is executed. In most cases, the counterparty must have an investment grade rating, which includes a minimum long-term debt rating of Baa3 from Moody's and BBB- from S&P. Generally, Southern Company Gas requires credit enhancements by way of a guaranty, cash deposit, or letter of credit for transaction counterparties that do not have investment grade ratings.

Southern Company Gas also utilizes master netting agreements whenever possible to mitigate exposure to counterparty credit risk. When Southern Company Gas is engaged in more than one outstanding derivative transaction with the same counterparty and it also has a legally enforceable netting agreement with that counterparty, the "net" mark-to-market exposure represents the netting of the positive and negative exposures with that counterparty and a reasonable measure of Southern Company Gas' credit risk. Southern Company Gas also uses other netting agreements with certain counterparties with whom it conducts significant transactions. Master netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty. Southern Company Gas also nets across product lines and against cash collateral provided the master netting and cash collateral agreements include such provisions. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.

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

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(UNAUDITED)

(K) ACQUISITIONS AND DISPOSITIONS

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

Southern Company

On January 1, 2019, Southern Company completed the sale of all of the capital stock of Gulf Power to 700 Universe, LLC, a wholly-owned subsidiary of NextEra Energy, for an aggregate cash purchase price of approximately $5.8 billion (less $1.3 billion of indebtedness assumed), subject to customary working capital adjustments. The preliminary gain associated with the sale of Gulf Power totaled $2.5 billion pre-tax ($1.3 billion after tax). The assets and liabilities of Gulf Power were classified as assets held for sale and liabilities held for sale on Southern Company's balance sheet as of December 31, 2018.

Management has started the process to sell one of PowerSecure's business units; therefore, the related assets and liabilities have been reclassified as held for sale on Southern Company's balance sheet as of March 31, 2019. The ultimate outcome of this matter cannot be determined at this time; however, any related gain or loss on the potential sale is not expected to have a material effect on Southern Company's financial statements.

See "Assets Held for Sale" herein for additional information.

Southern Power

Construction Projects in Progress

During the three months ended March 31, 2019, Southern Power continued construction of the projects set forth in the table below. Total aggregate construction costs, excluding the acquisition costs, are expected to be between $575 million and $640 million for the Plant Mankato expansion and the Wildhorse Mountain and Reading facilities. At March 31, 2019, total costs of construction incurred for these projects were $347 million and are included in CWIP, except for the Plant Mankato expansion, which is included in assets held for sale in the financial statements. The ultimate outcome of these matters cannot be determined at this time.

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	Expected COD	PPA Contract Period
Mankato expansion(a)	Natural Gas	385	Mankato, MN	May 2019	20 years
Wildhorse Mountain(b)	Wind	100	Pushmataha County, OK	Fourth quarter 2019	20 years
Reading(c)	Wind	200	Osage and Lyon Counties, KS	Second quarter 2020	12 years

(a) In November 2018, Southern Power entered into an agreement to sell all of its equity interests in Plant Mankato, including this expansion currently under construction. This transaction is subject to FERC and state commission approvals and is expected to close mid-2019. The ultimate outcome of this matter cannot be determined at this time. See "Sales of Natural Gas and Biomass Plants" below.

(b) In May 2018, Southern Power purchased 100% of the Wildhorse Mountain facility. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

(c) In August 2018, Southern Power purchased 100% of the membership interests of the Reading facility from the joint development arrangement with Renewable Energy Systems Americas, Inc. described below. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

Development Projects

Southern Power continues to evaluate and refine the deployment of the wind turbine equipment purchased in 2016 and 2017 to potential joint development and construction projects as well as the amount of MW capacity to be constructed. During the three months ended March 31, 2019, approximately $53 million of equipment was marketed for sale and, subsequent to March 31, 2019, was sold. At March 31, 2019, the equipment was classified as held for

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(UNAUDITED)

sale on Southern Company's and Southern Power's balance sheets. See "Assets Held for Sale" herein for additional information.

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

Sales of Natural Gas and Biomass Plants

In November 2018, Southern Power entered into an agreement with Northern States Power to sell all of its equity interests in Plant Mankato (including the 385-MW expansion currently under construction) for an aggregate purchase price of approximately $650 million. The completion of the disposition is subject to the expansion unit reaching commercial operation as well as various other customary conditions to closing, including working capital and timing adjustments.This transaction is subject to FERC and state commission approvals. The assets and liabilities of Plant Mankato are classified as assets held for sale and liabilities held for sale on Southern Company's and Southern Power's balance sheets as of March 31, 2019 and December 31, 2018. See "Assets Held for Sale" herein for additional information.

On April 17, 2019, Southern Power entered into an agreement to sell all of its equity interests in the Nacogdoches biomass-fueled facility to Austin Energy for an aggregate purchase price of $460 million, subject to customary closing conditions and working capital adjustments.

Each of these sales is expected to close in mid-2019; however, the ultimate outcome of these matters cannot be determined at this time.

Assets Subject to Lien

Under the terms of the PPA and the expansion PPA for Plant Mankato, approximately $538 million of assets, primarily related to property, plant, and equipment, are subject to lien at March 31, 2019.

Assets Held for Sale

As discussed above, Southern Company and Southern Power each have assets and liabilities held for sale on their balance sheets at March 31, 2019 and December 31, 2018. Assets and liabilities held for sale have been classified separately on each company's balance sheet at the lower of carrying value or fair value less costs to sell at the time the criteria for held-for-sale classification were met. For assets and liabilities held for sale recorded at fair value on a nonrecurring basis, the fair value of assets held for sale is based primarily on unobservable inputs (Level 3), which includes the agreed upon sales prices in executed sales agreements.

Upon classification as held for sale in November 2018 for Plant Mankato, Southern Power ceased recognizing depreciation and amortization on the long-lived assets to be sold.

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(UNAUDITED)

The following table provides Southern Company's and Southern Power's major classes of assets and liabilities classified as held for sale at March 31, 2019 and December 31, 2018:

	Southern Company		Southern Power
	(in millions)
At March 31, 2019
Assets Held for Sale:
Current assets	$	55	$	11
Total property, plant, and equipment	637		604
Goodwill and other intangible assets	82		40
Other non-current assets	44		—
Total Assets Held for Sale	$	818	$	655
Liabilities Held for Sale:
Current liabilities	$	38	$	9
Other non-current liabilities	39		—
Total Liabilities Held for Sale	$	77	$	9
At December 31, 2018
Assets Held for Sale:
Current assets	$	393	$	8
Total property, plant, and equipment	4,583		536
Goodwill and other intangible assets	40		40
Other non-current assets	727		—
Total Assets Held for Sale	$	5,743	$	584
Liabilities Held for Sale:
Current liabilities	$	425	$	15
Long-term debt	1,286		—
Accumulated deferred income taxes	618		—
Other non-current liabilities	932		—
Total Liabilities Held for Sale	$	3,261	$	15

Southern Company and Southern Power each concluded that the sale of their assets, both individually and combined, did not represent a strategic shift in operations that has, or is expected to have, a major effect on its operations and financial results; therefore, none of the assets related to the sales have been classified as discontinued operations for any of the periods presented.

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(UNAUDITED)

Gulf Power and Southern Power's equity interests in Plant Oleander and Plant Stanton Unit A (together, the Florida Plants) represented individually significant components of Southern Company and Southern Power, respectively; therefore, pre-tax profit for these components for the three months ended March 31, 2018 is presented below:

	For the Three Months Ended March 31, 2018
	(in millions)
Earnings before income taxes:
Gulf Power	$	55
Southern Power's Florida Plants	$	8

(L) LEASES

On January 1, 2019, the registrants adopted the provisions of FASB ASC Topic 842 (as amended), Leases (ASC 842), which require lessees to recognize leases with a term of greater than 12 months on the balance sheet as lease obligations, representing the discounted future fixed payments due, along with right-of-use (ROU) assets that will be amortized over the term of each lease.

The registrants elected the transition methodology provided by ASC 842, whereby the applicable requirements are applied on a prospective basis as of the adoption date of January 1, 2019, without restating prior periods. The registrants also elected the package of practical expedients provided by ASC 842 that allows prior determinations of whether existing contracts are, or contain, leases and the classification of existing leases to continue without reassessment. Additionally, the registrants applied the use-of-hindsight practical expedient in determining lease terms as of the date of adoption and elected the practical expedient that allows existing land easements not previously accounted for as leases not to be reassessed.

Lessee

As lessee, the registrants lease certain electric generating units (including renewable energy facilities), real estate/land, communication towers, railcars, and other equipment and vehicles. The major categories of lease obligations are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Electric generating units	$	1,094	$	159	$	1,606	$	—	$	—	$	—
Real estate/land	803		3		63		2		393		83
Communication towers	131		1		3		—		—		—
Railcars	55		25		26		3		—		—
Other	153		10		16		3		—		1
Total	$	2,236	$	198	$	1,714	$	8	$	393	$	84

Real estate/land leases primarily consist of commercial real estate leases at Southern Company, Georgia Power, and Southern Company Gas and various land leases primarily associated with renewable energy facilities at Southern Power. The commercial real estate leases have remaining terms of up to 25 years while the land leases have remaining terms of up to 48 years, including renewal periods.

Communication towers are leased for the installation of equipment to provide cellular phone service to customers and to support the automated meter infrastructure programs at the traditional electric operating companies. Communication tower leases have terms of up to 10 years with options to renew for periods up to 20 years.

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(UNAUDITED)

While renewal options exist in many of the leases, other than for land leases associated with renewable energy facilities, the expected term used in calculating the lease obligation generally reflects only the noncancelable period of the lease as it is not considered reasonably certain that the lease will be extended. The expected term of land leases associated with renewable energy facilities includes renewal periods reasonably certain of exercise resulting in an expected lease term at least equal to the expected life of the renewable energy facilities.

Contracts that Contain a Lease

While not specifically structured as a lease, some of the PPAs at Alabama Power and Georgia Power are deemed to represent a lease of the underlying electric generating units when the terms of the PPA convey the right to control the use of the underlying assets. Amounts recorded for leases of electric generating units are generally based on the amount of scheduled capacity payments due over the remaining term of the affiliate PPA, which varies between four and 18 years. Georgia Power has several PPAs with Southern Power that Georgia Power accounts for as leases with a lease obligation of approximately $670 million at March 31, 2019. The amount paid for energy under these affiliate PPAs reflects a price that would be paid in an arm's-length transaction as those amounts have been reviewed and approved by the Georgia PSC.

Short-term Leases

Leases with an initial term of 12 months or less are not recorded on the balance sheet; the registrants generally recognize lease expense for these leases on a straight-line basis over the lease term.

Residual Value Guarantees

Residual value guarantees exist primarily in railcar leases at Alabama Power and Georgia Power and the amounts probable of being paid under those guarantees are included in the lease payments. All such amounts are immaterial as of March 31, 2019.

Lease and Nonlease Components

For all asset categories, with the exception of electric generating units, gas pipelines, and real estate leases, the registrants combine lease payments and any nonlease components, such as asset maintenance, for purposes of calculating the lease obligation and the right-of-use asset.

Balance sheet amounts recorded for operating and finance leases are as follows:

	As of March 31, 2019
	Southern  Company(*)		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Operating Leases
Operating lease ROU assets, net	$	1,926	$	160	$	1,519	$	8	$	372	$	86
Operating lease obligations - current	$	239	$	47	$	139	$	3	$	22	$	13
Operating lease obligations - non current	1,752		147		1,404		5		371		71
Total operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance Leases
Finance lease ROU assets, net	$	242	$	4	$	145	$	—	$	—	$	—
Finance lease obligations - current	$	38	$	1	$	10	$	—	$	—	$	—
Finance lease obligations - noncurrent	207		3		161		—		—		—
Total finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

(*) Includes operating lease ROU assets, net and operating lease obligations classified as held for sale.

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(UNAUDITED)

Lease costs for the three months ended March 31, 2019, which includes both amounts recognized as operations and maintenance expense and amounts capitalized as part of the cost of another asset, are as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease cost
Operating lease cost	$	69	$	7	$	49	$	1	$	7	$	4
Finance lease cost:
Amortization of ROU assets	7		—		4		—		—		—
Interest on lease obligations	3		—		4		—		—		—
Total finance lease cost	10		—		8		—		—		—
Short-term lease costs	14		5		3		—		—		—
Variable lease cost	19		—		16		—		1		—
Sublease income	—		—		—		—		—		—
Total lease cost	$	112	$	12	$	76	$	1	$	8	$	4

Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities subject to PPAs.

Other information with respect to cash and noncash activities related to leases, as well as weighted-average lease terms and discount rates, is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Other information
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$	74	$	13	$	32	$	1	$	7	$	4
Operating cash flows from finance leases	6		—		13		—		—		—
Financing cash flows from finance leases	8		—		2		—		—		—
ROU assets obtained in exchange for new operating lease obligations	15		2		4		—		—		—
ROU assets obtained in exchange for new finance lease obligations	29		—		28		—		—		—

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
Weighted-average remaining lease term in years:
Operating leases	13.5		3.8		10.1		6.8		33.7		9.0
Finance leases	18.5		14.8		11.3		—		—		—
Weighted-average discount rate:
Operating leases	4.49	%	3.33	%	4.42	%	4.03	%	5.68	%	3.70	%
Finance leases	5.00	%	3.75	%	10.68	%	—	%	—	%	—	%

Maturities of lease liabilities are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Maturity Analysis
Operating leases:
2019 (remaining)	$	253	$	46	$	182	$	2	$	17	$	12
2020	291		53		202		2		22		16
2021	274		52		197		1		23		16
2022	263		52		195		1		23		12
2023	198		3		196		1		24		10
Thereafter	1,637		1		984		2		848		36
Total	2,916		207		1,956		9		957		102
Less: Present value discount	925		13		413		1		564		18
Operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance leases:
2019 (remaining)	$	24	$	1	$	22	$	—	$	—	$	—
2020	32		1		28		—		—		—
2021	26		1		25		—		—		—
2022	22		1		25		—		—		—
2023	18		1		25		—		—		—
Thereafter	273		—		165		—		—		—
Total	395		5		290		—		—		—
Less: Present value discount	150		1		119		—		—		—
Finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

Payments made under PPAs at Georgia Power for energy generated from certain renewable energy facilities accounted for as operating and finance leases are considered variable lease costs and are therefore not reflected in the above maturity analysis. As of March 31, 2019, Southern Company and Southern Power have additional operating leases, primarily for land, that have not yet commenced. These operating leases are expected to commence during the remainder of 2019 through 2021, with lease terms of up to 30 years, and have estimated total obligations of $77 million.

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(UNAUDITED)

For additional information on each registrant's operating lease obligations at December 31, 2018, see Note 9 to the financial statements in Item 8 of the Form 10-K.

Lessor

With the exception of Southern Company Gas, the registrants are each considered lessors in various arrangements that have been determined to contain a lease due to the customer's ability to control the use of the underlying asset owned by the applicable registrant. For the traditional electric operating companies, these arrangements consist of outdoor lighting contracts accounted for as operating leases with initial terms of up to five years, after which the contracts renew on a month-to-month basis at the customer's option. For Mississippi Power, these arrangements also include tolling arrangements related to electric generating units accounted for as sales-type leases with terms of up to 20 years. For Southern Power, these arrangements consist of PPAs related to electric generating units, including renewable energy facilities, accounted for as operating leases with terms of up to 28 years. For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as operating leases with terms of up to 15 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with remaining terms of up to 24 years.

Lease income for the three months ended March 31, 2019 is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease income - interest income on sales-type leases	$	2	$	—	$	2	$	—	$	—
Lease income - operating leases	71		19		—		41		9
Variable lease income	66		—		—		72		—
Total lease income	$	139	$	19	$	2	$	113	$	9

No profit or loss was recognized by Mississippi Power upon commencement of a sales-type lease during the first quarter 2019.

Lease income for Southern Power is included in wholesale revenues. 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. Scheduled payments to be received under outdoor lighting contracts, tolling arrangements, and PPAs accounted for as leases are presented in the following maturity analyses.

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(UNAUDITED)

The undiscounted cash flows to be received under tolling arrangements accounted for as sales-type leases are as follows:

	As of March 31, 2019
	Southern Company		Mississippi Power
	(in millions)
2019 (remaining)	$	11	$	11
2020	14		14
2021	14		14
2022	13		13
2023	12		12
Thereafter	135		135
Total undiscounted cash flows	$	199	$	199
Lease receivable	108		108
Difference between undiscounted cash flows and discounted cash flows	$	91	$	91

The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases (adjusted for intercompany eliminations) are as follows:

	As of March 31, 2019
	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
2019 (remaining)	$	163	$	20	$	123	$	26
2020	188		26		128		34
2021	183		18		131		34
2022	174		8		134		34
2023	171		2		137		34
Thereafter	1,809		—		1,017		498
Total	$	2,688	$	74	$	1,670	$	660

Southern Power receives payments for renewable energy under PPAs accounted for as operating leases that are considered contingent rents and are therefore not reflected in the table above. Southern Power allocates revenue to the nonlease components of PPAs based on the stand-alone selling price of capacity and energy. The undiscounted cash flows to be received under outdoor lighting contracts accounted for as operating leases at Alabama Power and Mississippi Power are immaterial.

(M) 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 – Alabama Power, Georgia Power, and Mississippi Power – 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 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, wholesale gas services, and gas marketing services.

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

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 $87 million for the three months ended March 31, 2019 and $83 million for the three months ended March 31, 2018. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for each of the three months ended March 31, 2019 and 2018. Revenues from sales of natural gas from Southern Company Gas to Southern Power were $17 million for the three months ended March 31, 2019 and $36 million for the three months ended March 31, 2018. 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 energy technologies and services to electric utilities and large industrial, commercial, institutional, and municipal customers, as well as investments in telecommunications and 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, 2019 and 2018 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, 2019:
Operating revenues	$	3,445	$	443	$	(93	)	$	3,795	$	1,474	$	182		$	(39	)	$	5,412
Segment net income (loss)(a)(b)(c)	565		56		—			621		270		1,195			(2		)	2,084
At March 31, 2019:
Goodwill	$	—	$	2	$	—		$	2	$	5,015	$	268		$	(1	)	$	5,284
Total assets	76,798		15,104		(779		)	91,123		20,952		3,391			(1,370		)	114,096
Three Months Ended March 31, 2018:
Operating revenues	$	3,979	$	509	$	(106	)	$	4,382	$	1,639	$	401		$	(50	)	$	6,372
Segment net income (loss)(a)(b)(d)	612		121		—			733		279		(74		)	—			938
At December 31, 2018:
Goodwill	$	—	$	2	$	—		$	2	$	5,015	$	298		$	—		$	5,315
Total assets	79,382		14,883		(306		)	93,959		21,448		3,285			(1,778		)	116,914

(a) Attributable to Southern Company.

(b) Segment net income (loss) for the traditional electric operating companies includes pre-tax charges for estimated losses on plants under construction of $2 million ($1 million after tax) and $44 million ($33 million after tax) for the three months ended March 31, 2019 and 2018, respectively. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) under "Mississippi Power – Kemper County Energy Facility" for additional information.

(c) Segment net income (loss) for the "All Other" column includes the preliminary pre-tax gain associated with the sale of Gulf Power of $2.5 billion ($1.3 billion after tax) for the three months ended March 31, 2019. See Note (K) under "Southern Company" for additional information.

(d) Segment net income (loss) for Southern Company Gas includes a goodwill impairment charge of $42 million for the three months ended March 31, 2018 related to the sale of Pivotal Home Solutions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

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(UNAUDITED)

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2019	$	3,084	$	499	$	212	$	3,795
Three Months Ended March 31, 2018	3,568		623		191		4,382

	Southern Company Gas' Revenues
	Gas Distribution Operations(a)		Gas Marketing Services(b)		Other		Total
	(in millions)
Three Months Ended March 31, 2019	$	1,161	$	229	$	84	$	1,474
Three Months Ended March 31, 2018	1,200		271		168		1,639

(a) Operating revenues for the three gas distribution operations dispositions were $167 million for the three months ended March 31, 2018.

(b) Operating revenues for Pivotal Home Solutions were $32 million for the three months ended March 31, 2018.

Southern Company Gas

Southern Company Gas manages its business through four reportable segments – gas distribution operations, gas pipeline investments, wholesale gas services, 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, two significant pipeline construction projects, 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.

Wholesale gas services provides natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engages in natural gas storage and gas pipeline arbitrage and related activities.

Gas marketing services provides natural gas marketing to end-use customers primarily in Georgia and Illinois through SouthStar Energy Services, LLC.

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

196

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(UNAUDITED)

Business segment financial data for the three months ended March 31, 2019 and 2018 was as follows:

	Gas Distribution Operations(a)		Gas Pipeline Investments		Wholesale Gas Services(b)		Gas Marketing Services(c)(d)		Total		All Other			Eliminations			Consolidated
	(in millions)
Three Months Ended March 31, 2019:
Operating revenues	$	1,172	$	8	$	86	$	229	$	1,495	$	11		$	(32	)	$	1,474
Segment net income (loss)	133		32		47		61		273		(3		)	—			270
Total assets at March 31, 2019:	17,379		1,781		821		1,611		21,592		10,900			(11,540		)	20,952
Three Months Ended March 31, 2018:
Operating revenues	$	1,212	$	8	$	166	$	271	$	1,657	$	15		$	(33	)	$	1,639
Segment net income (loss)	149		27		104		13		293		(14		)	—			279
Total assets at December 31, 2018:	17,266		1,763		1,302		1,587		21,918		11,112			(11,582		)	$	21,448

(a) Operating revenues for the three gas distribution operations dispositions were $167 million for the three months ended March 31, 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

(b) The revenues for wholesale gas services are netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended March 31, 2019	$	1,926	$	88	$	2,014	$	1,928	$	86
Three Months Ended March 31, 2018	1,938		167		2,105		1,939		166

(c) Operating revenues for the gas marketing services disposition were $32 million for the three months ended March 31, 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

(d) Segment net income (loss) for gas marketing services includes a goodwill impairment charge of $42 million for the three months ended March 31, 2018 related to the sale of Pivotal Home Solutions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

197

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.

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
		Georgia Power
		(c)1	-	Amended and Restated Loan Guarantee Agreement, dated as of March 22, 2019, between Georgia Power and the DOE. (Designated in Form 8-K dated March 22, 2019, File No. 1-6468, as Exhibit 4.1.)
		(c)2	-	Note Purchase Agreement, dated as of March 22, 2019, between Georgia Power, the DOE, and the FFB. (Designated in Form 8-K dated March 22, 2019, File No. 1-6468, as Exhibit 4.2.)
		(c)3	-	Promissory Note of Georgia Power, dated as of March 22, 2019. (Designated in Form 8-K dated March 22, 2019, File No. 1-6468, as Exhibit 4.3.)
		(c)4	-	Amended and Restated Deed to Secure Debt, Security Agreement and Fixture Filing, dated as of March 22, 2019, by Georgia Power to PNC Bank, National Association, doing business as Midland Loan Services, Inc., a division of PNC Bank, National Association. (Designated in Form 8-K dated March 22, 2019, File No. 1-6468, as Exhibit 4.4.)
		(c)5	-	Amended and Restated Owners Consent to Assignment and Direct Agreement and Amendment to Plant Alvin W. Vogtle Additional Units Ownership Participation Agreement, dated as of March 22, 2019, among Georgia Power, the other Vogtle Owners, the DOE, and PNC Bank, National Association, doing business as Midland Loan Services, Inc., a division of PNC Bank, National Association. (Designated in Form 8-K dated March 22, 2019, File No. 1-6468, as Exhibit 4.5.)
		(10) Material Contracts
		Southern Company
#	*	(a)1	-	Performance Stock Units Agreement, dated May 23, 2018, between Southern Company and Stephen E. Kuczynski.
#	*	(a)2	-	Retention and Restricted Stock Unit Agreement, dated May 23, 2018, between Southern Company and Stephen E. Kuczynski.
#	*	(a)3	-	Form of Terms for 2018 Named Executive Officer Equity Awards granted under the Southern Company 2011 Omnibus Incentive Compensation Plan.

198

		Alabama Power
#		(b)1	-	Form of Terms for 2018 Named Executive Officer Equity Awards granted under the Southern Company 2011 Omnibus Incentive Compensation Plan. See Exhibit 10(a)3 herein.
		(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, 2018, File No. 1-3526 as Exhibit 24(a)1.)
		Alabama Power
		(b)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2018, File No. 1-3164 as Exhibit 24(b).)
		Georgia Power
		(c)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2018, File No. 1-6468 as Exhibit 24(c).)
		Mississippi Power
		(d)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2018, File No. 001-11229 as Exhibit 24(d).)
		Southern Power
		(e)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2018, 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, 2018, File No. 1-14174 as Exhibit 24(f)1.)
		(f)2	-	Power of Attorney of Daniel S. Tucker. (Designated in the Form 10-K for the year ended December 31, 2018, File No. 1-14174 as Exhibit 24(f)2.)
		(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.

199

	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.
	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.

200

	(101) Interactive Data Files
*	INS	-	XBRL Instance Document
*	SCH	-	XBRL Taxonomy Extension Schema Document
*	CAL	-	XBRL Taxonomy Calculation Linkbase Document
*	DEF	-	XBRL Definition Linkbase Document
*	LAB	-	XBRL Taxonomy Label Linkbase Document
*	PRE	-	XBRL Taxonomy Presentation Linkbase Document

201

THE SOUTHERN COMPANY

SIGNATURES

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

	THE SOUTHERN COMPANY
By	Thomas A. Fanning
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Andrew W. Evans
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 30, 2019

202

ALABAMA POWER COMPANY

SIGNATURES

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

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

Date: April 30, 2019

203

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	W. Paul Bowers
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	David P. Poroch
	Executive Vice President, Chief Financial Officer, Treasurer, and Comptroller
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 30, 2019

204

MISSISSIPPI POWER COMPANY

SIGNATURES

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

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

Date: April 30, 2019

205

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	Mark S. Lantrip
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	William C. Grantham
	Senior Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 30, 2019

206

SOUTHERN COMPANY GAS

SIGNATURES

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

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

Date: April 30, 2019

207

EX-10.A1

Exhibit 10(a)1

THE SOUTHERN COMPANY

Performance Stock Units Agreement

Retention Award

This PERFORMANCE STOCK UNITS AGREEMENT (this “Agreement”) is made by and between The Southern Company (the “Company”), and Stephen E. Kuczynski (“Employee”).

1.Certain Definitions. Capitalized terms used, but not otherwise defined, in this Agreement will have the meanings given to such terms in the Southern Company Omnibus Incentive Compensation Plan (the “Plan”).

2.Grant of PSUs. Subject to and upon the terms, conditions and restrictions set forth in this Agreement and in the Plan, pursuant to authorization under a resolution of the Compensation and Management Succession Committee of the Board of Directors of the Company (“Compensation Committee”), the Company has granted to Employee effective as of May 23, 2018 (the “Date of Grant”) the number of performance-based Restricted Stock Units (“PSUs”) valued at $1,200,000.00 based on the Fair Market Value on the Date of Grant (rounded to the nearest whole PSU). Subject to the degree of attainment of the performance goals established for these PSUs, as approved by the Compensation Committee and communicated to Employee (the “Statement of Performance Goals”), Employee may earn from 0% to 100% of the PSUs. Each PSU shall then represent the right of Employee to receive one share of Common Stock subject to and upon the terms and conditions of this Agreement.

3.Payment of PSUs. The PSUs will become payable in accordance with the provisions of Section 6 of this Agreement if the Period of Restriction lapses and Employee’s right to receive payment for the PSUs becomes nonforfeitable (“Vest,” “Vesting” or “Vested”) in accordance with Section 5 of this Agreement.

4.Restrictions on Transfer of PSUs. Subject to Section 18.12 of the Plan, neither the PSUs evidenced hereby nor any interest therein or in the Common Stock underlying such PSUs shall be transferable prior to payment to Employee pursuant to Section 6 hereof other than by will or pursuant to the laws of descent and distribution.

5.Vesting of PSUs.

(a) Subject to the terms and conditions of this Agreement, the PSUs covered by this Agreement shall Vest to the extent that the applicable performance goals described in the Statement of Performance Goals for such PSUs (the “Performance Goals”) are achieved, once determined and certified by the Chief Executive Officer of the Company or the Compensation Committee, as applicable (and as described in the Statement of Performance Goals), in his or its sole discretion, conditioned upon Employee’s continuous employment with the Company or a Subsidiary through the date of such certification with respect to the applicable portion of the PSUs (each such date, a “Vesting Date”). Any PSUs that do not so Vest will be forfeited, including if Employee ceases to be continuously employed by the Company or a Subsidiary prior to the Vesting of the PSUs. For purposes of this

Agreement, “continuously employed” (or substantially similar terms) means the absence of any interruption or termination of Employee’s employment with the Company or a Subsidiary, including Employee receiving long-term disability benefits under the Southern Company Services, Inc. Health and Welfare Benefits Plan regardless of Employee’s employment status with the Company or a Subsidiary. Continuous employment shall not be considered interrupted or terminated in the case of transfers between locations of the Company and its Subsidiaries or in situations where the interruption of Employee’s employment is protected by law.

(b) Any PSUs that have not Vested pursuant to this Section 5 by the last date on which the applicable Performance Goal may be achieved with respect to such PSUs (as set forth in the Statement of Performance Goals) will be forfeited automatically and without further notice after the end of such date (or earlier if, and on such date that, Employee ceases to be an employee of the Company or a Subsidiary prior to the Vesting of the PSUs for any reason).

(c) Notwithstanding anything in this Agreement to the contrary, the Compensation Committee explicitly reserves the right to modify, terminate, or accelerate the Award evidenced by this Agreement prior to the Vesting or forfeiture of the Award, in accordance with the terms of the Plan, including but not limited to the case of abandonment of the Vogtle project after an amendment to, or revocation, withdrawal, or cancellation of, the Vogtle Certificate of Public Convenience and Necessity by the Georgia Public Service Commission.

6.Form and Time of Payment of PSUs.

(a) Payment for the PSUs, after and to the extent they have Vested, shall be made in the form of shares of Common Stock. Payment shall be made as soon as practicable following Vesting of the PSUs, but no later than March 15 of the calendar year following the calendar year in which the PSUs Vest.

(b) Except to the extent provided by Section 409A of the Code and permitted by the Compensation Committee, no Common Stock may be issued to Employee at a time earlier than otherwise expressly provided in this Agreement.

(c) The Company’s obligations to Employee with respect to the PSUs will be satisfied in full upon the issuance of Common Stock corresponding to such PSUs.

7.Dividend Equivalents; Voting and Other Rights.

(a) Employee shall have no rights of ownership in the shares of Common Stock underlying the PSUs and no right to vote the shares of Common Stock underlying the PSUs until the date on which the shares of Common Stock underlying the PSUs are issued or transferred to Employee pursuant to Section 6 above.

(b) From and after the Date of Grant and until the earlier of (i) the time when the PSUs Vest and are paid in accordance with Section 6 hereof or (ii) the time when

Employee’s right to receive Common Stock in payment of the PSUs is forfeited in accordance with Section 5 hereof, on the date that the Company pays a cash dividend (if any) to holders of Common Stock generally, Employee shall be credited with additional PSUs equal in value (subject to rounding) to the amount of such dividend. Any PSUs credited pursuant to the immediately preceding sentence shall be subject to the same applicable terms and conditions (including Vesting, payment and forfeitability) as apply to the PSUs based on which the dividend equivalents were credited, and such amounts shall be paid in Common Stock at the same time as the PSUs to which they relate.

(c) The obligations of the Company under this Agreement will be merely that of an unfunded and unsecured promise of the Company to deliver Common Stock in the future, and the rights of Employee will be no greater than that of an unsecured general creditor. No assets of the Company will be held or set aside as security for the obligations of the Company under this Agreement.

8.Detrimental Activity.

(a) In the event that, as determined by the Compensation Committee, Employee shall engage in Detrimental Activity during employment with the Company or a Subsidiary, the PSUs will be forfeited automatically and without further notice at the time of that determination notwithstanding any other provision of this Agreement.

(b) For purposes of this Agreement, “Detrimental Activity” shall mean the occurrence of any of the following events:

(i) the failure of Employee to adhere to all policies, procedures, regulations and laws of and applicable to the Company from the Date of Grant to the applicable Vesting Date, including without limitation: (A) ethical and legal compliance expectations; (B) equal employment / harassment; (C) workplace threats and violence; (D) electronic communications; (E) safety and the environment; (F) drugs and alcohol; and (G) conflict of interest;

(ii) the failure of Employee to demonstrate consistent commitment to the Company’s standards of personal and workplace safety, process safety management and ethical conduct, and effective execution of related policies and practices; or

(iii) the failure of Employee to timely notify the Vogtle Executive Oversight Committee of any relevant information on the Plant Vogtle Units 3 and 4 project, or the omission of any relevant facts from such a notification (in each case, as determined in the reasonable, good faith discretion of the Compensation Committee).

9.Confidentiality. Employee represents and agrees that Employee will keep all terms and provisions of this Agreement confidential, except for possible disclosures to Employee’s legal and financial advisors and his spouse or to the extent required by law, and Employee further agrees

that Employee will not disclose the terms, provisions or information contained in or concerning the Agreement to anyone other than those persons named above, including, but not limited to, any past, present or prospective employee or applicant for employment with the Company or any affiliate of the Company. Notwithstanding anything in this Agreement to the contrary, nothing in this Agreement prohibits, penalizes, or otherwise discourages Employee from reporting, providing testimony, participating in an investigation or proceeding, or otherwise communicating, without prior notice to the Company, information regarding any nuclear safety concern, workplace safety concern, public safety concern, or any concern about the legal or ethical management of the Company or any affiliate or Subsidiary of the Company to the United States Nuclear Regulatory Commission, Securities and Exchange Commission, U.S. Department of Labor, Equal Employment Opportunity Commission, National Labor Relations Board, Occupational Safety and Health Administration, or any other local, state, or federal agency. This Agreement does not limit Employee’s rights to receive an award for information provided to any government agency.

10.Adjustments. The PSUs and the number of shares of Common Stock issuable for each PSU and the other terms and conditions of the grant evidenced by this Agreement are subject to adjustment as provided in Section 14.2 of the Plan.

11.Withholding Taxes. To the extent permitted under Section 409A of the Code, there shall be deducted from the Vested PSUs the number of shares of Common Stock necessary to cover the amount of any tax required by any governmental authority to be withheld from Employee and paid over by the Company to such governmental authority for the account of Employee. The Company makes no representations or guarantees regarding the tax implications of the Agreement and advises Employee to consult with his attorney and/or tax advisor regarding the tax implications of the Agreement. In addition, Employee agrees to hold harmless the Company with respect to any tax liability for any and all federal, state or local taxes or assessments, interest or penalties of any kind arising from the Agreement.

12.Compliance With Law. The Company shall make reasonable efforts to comply with all applicable federal and state securities laws; provided, however, notwithstanding any other provision of the Plan and this Agreement, the Company shall not be obligated to issue any Common Stock pursuant to this Agreement if the issuance thereof would result in a violation of any such law.

13.Compliance With Section 409A of the Code. To the extent applicable, it is intended that this Agreement and the Plan comply with or be exempt from the provisions of Section 409A of the Code. This Agreement and the Plan shall be administered in a manner consistent with this intent, and any provision that would cause this Agreement or the Plan to fail to satisfy Section 409A of the Code shall have no force or effect until amended to comply with or be exempt from Section 409A of the Code (which amendment may be retroactive to the extent permitted by Section 409A of the Code and may be made by the Company without the consent of Employee). For greater certainty, it is intended that the Award evidenced by this Agreement be exempt from Section 409A of the Code as a short-term deferral, and settlement of the Award in all cases notwithstanding anything to the contrary will be made at a time consistent with such intent within the short-term deferral period set forth in Treasury Regulation Section 1.409A-1(b)(4).

14.Interpretation. Any reference in this Agreement to Section 409A of the Code will also include any proposed, temporary or final regulations, or any other guidance, promulgated with

respect to such Section by the U.S. Department of the Treasury or the Internal Revenue Service. Except as expressly provided in this Agreement, capitalized terms used herein will have the meaning ascribed to such terms in the Plan.

15.No Right to Future Awards or Employment. The grant of the PSUs under this Agreement to Employee is a voluntary, discretionary award being made on a one-time basis and it does not constitute a commitment to make any future awards. The grant of the PSUs and any payments made hereunder will not be considered salary or other compensation for purposes of any severance pay or similar allowance, except as otherwise required by law. Nothing contained in this Agreement shall confer upon Employee any right to be employed or remain employed by the Company or any of its Subsidiaries, nor limit or affect in any manner the right of the Company or any of its Subsidiaries to terminate the employment or adjust the compensation of Employee.

16.Relation to Other Benefits. Any economic or other benefit to Employee under this Agreement or the Plan shall not be taken into account in determining any benefits to which Employee may be entitled under any profit-sharing, retirement or other benefit or compensation plan maintained by the Company or any of its Subsidiaries and shall not affect the amount of any life insurance coverage available to any beneficiary under any life insurance plan covering employees of the Company or any of its Subsidiaries.

17.Amendments. Any amendment to the Plan shall be deemed to be an amendment to this Agreement to the extent that the amendment is applicable hereto; provided, however, that (a) no amendment shall adversely affect the rights of Employee under this Agreement without Employee’s written consent, and (b) Employee’s consent shall not be required to an amendment that is deemed necessary by the Company to ensure compliance with Section 409A of the Code or Section 10D of the Exchange Act.

18.Severability. In the event that one or more of the provisions of this Agreement shall be invalidated for any reason by a court of competent jurisdiction, any provision so invalidated shall be deemed to be separable from the other provisions hereof, and the remaining provisions hereof shall continue to be valid and fully enforceable.

19.Relation to Plan. This Agreement is subject to the terms and conditions of the Plan. In the event of any inconsistency between the provisions of this Agreement and the Plan, the Plan shall govern. The Compensation Committee acting pursuant to the Plan, as constituted from time to time, shall, except as expressly provided otherwise herein or in the Plan, have the right to determine any questions which arise in connection with this Agreement. Notwithstanding anything in this Agreement to the contrary, Employee acknowledges and agrees that this Agreement and the Award described herein (and any settlement thereof) are subject to the terms and conditions of the Company’s clawback policy (if any) as may be in effect from time to time specifically to implement Section 10D of the Exchange Act and any applicable rules or regulations promulgated thereunder (including applicable rules and regulations of any national securities exchange on which the Common Stock may be traded) (the “Compensation Recovery Policy”), and that relevant sections of this Agreement shall be deemed superseded by and subject to the terms and conditions of the Compensation Recovery Policy from and after the effective date thereof.

20.Electronic Delivery. The Company may, in its sole discretion, deliver any documents related to the PSUs and Employee’s participation in the Plan, or future awards that may be granted under the Plan, by electronic means or request Employee’s consent to participate in the Plan by electronic means. Employee hereby consents to receive such documents by electronic delivery and, if requested, agrees to participate in the Plan through an on-line or electronic system established and maintained by the Company or another third party designated by the Company.

21.Governing Law. This Agreement shall be governed by and construed with the internal substantive laws of the State of Delaware, without giving effect to any principle of law that would result in the application of the law of any other jurisdiction.

22.Successors and Assigns. Without limiting Section 4 hereof, the provisions of this Agreement shall inure to the benefit of, and be binding upon, the successors, administrators, heirs, legal representatives and assigns of Employee, and the successors and assigns of the Company.

23.Acknowledgement. Employee acknowledges that Employee (a) has received a copy of the Plan, (b) has had an opportunity to review the terms of this Agreement and the Plan, (c) understands the terms and conditions of this Agreement and the Plan and (d) agrees to such terms and conditions.

24.Counterparts. This Agreement may be executed in one or more counterparts, each of which shall be deemed to be an original but all of which together will constitute one and the same agreement.

THE SOUTHERN COMPANY
By:	/s/Thomas A. Fanning
Name:	Thomas A. Fanning
Title:	Chairman, President and Chief Executive
	Officer, The Southern Company
Date:	May 23, 2018
Employee Acknowledgment and Acceptance
By:	/s/Stephen E. Kuczynski
Name:	Stephen E. Kuczynski
Title:	Chairman, President and Chief Executive
	Officer, Southern Nuclear Operating
	Company, Inc.
Date:	May 23, 2018

Statement of Performance Goals

This Statement of Performance Goals applies to the PSUs granted to Employee on the Date of Grant and applies with respect to the Performance Stock Units Agreement between the Company and Employee (the “Agreement”). Capitalized terms used in this Statement of Performance Goals that are not specifically defined in this Statement of Performance Goals have the meanings assigned to them in the Agreement.

1. Definitions. For purposes hereof:

(a) “Fuel Load Authorization” means receipt of the finding by the United States Nuclear Regulatory Commission (“USNRC”) described in the Code of Federal Regulations at 10 C.F.R. 52.103(g).

2. Number of PSUs Earned. From 0% to 100% of the PSUs will be earned based on achievement of the Performance Goals as follows:

(a) Vogtle 3 PSUs. 50% of the PSUs (the “Vogtle 3 PSUs”) will become Vested if there is a Fuel Load Authorization with respect to Plant Vogtle Unit 3 on or before December 31, 2021 and such Fuel Load Authorization is determined and certified by the Compensation Committee (upon recommendation of the Operations, Environmental and Safety Committee of the Board). Except as otherwise determined by the Compensation Committee pursuant to the terms of the Agreement, the Vogtle 3 PSUs will be forfeited if there is not a Fuel Load Authorization with respect to Plant Vogtle Unit 3 on or before December 31, 2021.

(b) Vogtle 4 PSUs. 50% of the PSUs (the “Vogtle 4 PSUs”) will become Vested if there is a Fuel Load Authorization with respect to Plant Vogtle Unit 4 on or before December 31, 2022 and such Fuel Load Authorization is determined and certified by the Compensation Committee (upon recommendation of the Operations, Environmental and Safety Committee of the Board). Except as otherwise determined by the Compensation Committee pursuant to the terms of the Agreement, the Vogtle 4 PSUs will be forfeited if there is not a Fuel Load Authorization with respect to Plant Vogtle Unit 4 on or before December 31, 2022.

EX-10.A2

Exhibit 10(a)2

RETENTION AND RESTRICTED STOCK UNIT AWARD AGREEMENT

THIS RETENTION AND RESTRICTED STOCK UNIT AWARD AGREEMENT (“Agreement”) made and entered into by and between THE SOUTHERN COMPANY (“Company”) and STEPHEN E. KUCZYNSKI (“Employee”) shall be effective as of May 23, 2018 (“Effective Date”).

1.    Award. Employee is awarded under this Agreement the number of Restricted Stock Units (“RSUs”) valued at $1,800,000.00 at the closing price of The Southern Company common stock (“Common Stock”) on the New York Stock Exchange on the Effective Date. Employee shall become vested in the RSUs on the applicable Vesting Dates set forth below, subject to Employee’s continuous employment through the applicable Vesting Date, as defined in Paragraph 2(c). Any RSUs that do not vest will be forfeited.

Amount	Vesting Date
20% of Award amount	December 31, 2018
20% of Award amount	December 31, 2019
20% of Award amount	December 31, 2020
20% of Award amount	December 31, 2021
20% of Award amount	December 31, 2022

The deemed dividends associated with the RSUs shall be credited and treated as reinvested in additional RSUs until each Award amount is paid in accordance with Paragraph 2.

The Award amount under this Paragraph 1 is an award of RSUs under the Southern Company Omnibus Incentive Compensation Plan, as amended from time to time (“Plan”), and is governed by the terms of the Plan. Capitalized terms used, but not otherwise defined, in this Agreement will have the meanings given to such terms in the Plan.

2.    Timing and Form of Payment of Award Amount.

(a)    Generally. Unless modified by the provisions set forth in Paragraph 2(b), the applicable Award amount shall be paid in shares of Common Stock to Employee within 30 days following the applicable Vesting Date (each, a “Scheduled Payment Date”).

(b)    If the Company or a subsidiary of the Company receives the finding by the United States Nuclear Regulatory Commission described in the Code of Federal Regulations under 10 C.F.R. 52.103(g) with respect to both Plant Vogtle Unit 3 and Unit 4 on or prior to the final Vesting Date (and prior to the forfeiture of the Award) and such findings are determined and certified by the Compensation and Management Succession Committee of the Board of Directors of the Company (“Compensation Committee”) (upon recommendation of the Operations, Environmental and Safety Committee of the Board), notwithstanding anything to the contrary in the Agreement, Employee shall be treated as fully vested in the unvested Award set forth in Paragraph 1. The amount(s) vested under this Paragraph 2(b) shall be paid on the earlier of (i) the next Scheduled Payment Date or (ii) within 30 days following the date of the Compensation Committee certification described in the immediately preceding sentence.

(c)    Continuous Employment. For purposes of this Agreement, “continuously employed” (or substantially similar terms) means the absence of any interruption or termination of Employee’s employment with the Company or a Subsidiary, including Employee receiving long-term disability benefits under the Southern Company Services, Inc. Health and Welfare Benefits Plan regardless of Employee’s employment Status with the Company or a Subsidiary. Continuous employment shall not be considered interrupted or terminated in the case of transfers between locations of the Company and its Subsidiaries or in situations where the interruption of Employee’s employment is protected by law.

(d)    Any Voluntary or Involuntary Termination. If Employee separates from service for any reason prior to the final Vesting Date, whether voluntary or involuntary and including but not limited to retirement, Employee shall forfeit all remaining unvested Award amounts.

3.    Confidentiality. Employee represents and agrees that Employee will keep all terms and provisions of this Agreement confidential, except for possible disclosures to Employee’s legal and financial advisors and his spouse or to the extent required by law, and Employee further agrees that Employee will not disclose the terms, provisions or information contained in or concerning the Agreement to anyone other than those persons named above, including, but not limited to, any past, present or prospective employee or applicant for employment with the Company or any affiliate of the Company. Notwithstanding anything in this Agreement to the contrary, nothing in this Agreement prohibits, penalizes, or otherwise discourages Employee from reporting, providing testimony, participating in an investigation or proceeding, or otherwise communicating, without prior notice to the Company, information regarding any nuclear safety concern, workplace safety concern, public safety concern, or any concern about the legal or ethical management of the Company or any affiliate or Subsidiary of the Company to the United States Nuclear Regulatory Commission, Securities and Exchange Commission, U.S. Department of Labor, Equal Employment Opportunity Commission, National Labor Relations Board, Occupational Safety and Health Administration, or any other local, state, or federal agency. This Agreement does not limit Employee’s rights to receive an award for information provided to any government agency.

4.    Assignability. Neither Employee, his estate, his beneficiaries nor his legal representatives shall have any rights to commute, sell, assign, transfer or otherwise convey the right to receive any payments hereunder, which payments and the rights thereto are expressly declared to be nonassignable and nontransferable. Any attempt to assign or transfer the right to payments under the Agreement shall be void and have no effect.

5.    Detrimental Activity.

(a)    In the event that, as determined by the Compensation Committee, Employee shall engage in Detrimental Activity during employment with the Company or a Subsidiary, the RSUs will be forfeited automatically and without further notice at the time of that determination notwithstanding any other provision of this Agreement.

(b)    For purposes of this Agreement, “Detrimental Activity” shall mean the occurrence of any of the following events:

(i)    the failure of Employee to adhere to all policies, procedures, regulations

and laws of and applicable to the Company, including without limitation: (A) ethical and legal compliance expectations; (B) equal employment / harassment; (C) workplace threats and violence; (D) electronic communications; (E) safety and the environment; (F) drugs and alcohol; and (G) conflict of interest;

(ii)    the failure of Employee to demonstrate consistent commitment to the Company’s standards of personal and workplace safety, process safety management and ethical conduct, and effective execution of related policies and practices; or

(iii)    the failure of Employee to timely notify the Vogtle Executive Oversight Committee of any relevant information on the Plant Vogtle Units 3 and 4 project, or the omission of any relevant facts from such a notification (in each case, as determined in the reasonable, good faith discretion of the Compensation Committee).

6.    Unsecured General Creditor. The Company shall neither reserve nor specifically set aside funds for the payment of its obligations under the Agreement, and such obligations shall be paid solely from the general assets of the Company. Notwithstanding that Employee may be entitled to receive payments under the terms and conditions of the Agreement, the assets from which such amounts may be paid shall at all times be subject to the claims of the Company’s creditors.

7.    No Effect on Other Arrangements. It is expressly understood and agreed that any payments made in accordance with the Agreement are in addition to any other benefits or compensation to which Employee may be entitled or for which he may be eligible, whether funded or unfunded, by reason of his employment with the Company.

8.     Tax Withholding and Implications. To the extent permitted under Section 409A of the Internal Revenue Code, there shall be deducted from the vested Award amount the number of shares of Common Stock necessary to cover the amount of any tax required by any governmental authority to be withheld from Employee and paid over by the Company to such governmental authority for the account of Employee. The Company makes no representations or guarantees regarding the tax implications of the Agreement and advises Employee to consult with his attorney and/or tax advisor regarding the tax implications of the Agreement. In addition, Employee agrees to hold harmless the Company with respect to any tax liability for any and all federal, state or local taxes or assessments, interest or penalties of any kind arising from the Agreement.

9.    Compensation. Any compensation paid to Employee pursuant to the Agreement shall not be considered “Compensation” as defined in The Southern Company Employee Savings Plan or “Earnings” as defined in The Southern Company Pension Plan. Payments to Employee shall not be considered wages, salary or compensation under any other Company-sponsored employee benefit or compensation plan or program, unless the explicit terms of such plan or program provide otherwise.

10.    No Guarantee of Employment. No provision of the Agreement shall be construed to affect in any manner the existing rights of the Company to suspend, terminate, alter or modify, whether or not for cause, Employee’s employment relationship with the Company.

11.    Governing Law. The Agreement, and all rights under it, shall be governed by and construed in accordance with the laws of the State of Delaware, without giving effect to principles of conflicts of laws.

12.    Section 409A. Any payment provided under this Agreement is intended to be a short-term deferral as provided by Section 409A of the Internal Revenue Code and the regulations promulgated thereunder, and the parties agree that the terms and provisions of the Agreement will be construed and interpreted to the maximum extent permitted in order to have this effect. Notwithstanding anything to the contrary, any payment provided under this Agreement will be made within the short-term deferral period specified in Treasury Regulation Section 1.409A-1(b)(4).

IN WITNESS WHEREOF, this Agreement has been executed by the parties first listed above, this 23^rd day of May, 2018.

THE SOUTHERN COMPANY
By:	/s/Thomas A. Fanning
Name:	Thomas A. Fanning
Title:	Chairman, President and Chief Executive
	Officer, The Southern Company
Employee Acknowledgment and Acceptance
By:	/s/Stephen E. Kuczynski
Name:	Stephen E. Kuczynski
Title:	Chairman, President and Chief Executive
	Officer, Southern Nuclear Operating
	Company, Inc.

EX-10.A3

Exhibit 10(a)3

SOUTHERN COMPANY

OMNIBUS INCENTIVE COMPENSATION PLAN

FORM OF TERMS

PERFORMANCE SHARE AWARD

A Performance Share Award is subject to the following terms and conditions:

1. Award. A target number of performance share units (“Performance Shares” or “Performance Share Award”) is granted by the Compensation and Management Succession Committee (“Committee”) of The Southern Company (“Company”) Board of Directors to a Participant. The Performance Share Award provides the Participant an opportunity to earn shares of Common Stock based on Company performance over a three-year Performance Period (as defined below) against the performance goal measures set forth in Exhibit 1. Performance Share Awards are granted pursuant to and are governed by the Southern Company Omnibus Incentive Compensation Plan, as amended from time to time (“Plan”).

2. Terms. Terms used in this Form of Terms that are defined in the Plan will have the meanings ascribed to them in the Plan. The Long-Term Incentive Program Document (the “LTI Program Document”), an administrative document adopted by the Committee which is set forth at https:/mysource.southernco.com, contains additional provisions that apply to Performance Share Awards. Performance Share Awards are subject to the terms and conditions set forth in the Plan and any other administrative documents adopted by the Committee from time to time. If there is any inconsistency between the terms herein and the terms of the Plan or any administrative document adopted by the Committee, the Plan’s terms and the administrative document’s terms will supersede and replace the conflicting terms of this Form of Terms.

3. Performance Period. The period during which the performance goal measures apply (“Performance Period”) will be a three-year period that begins on January 1 of the year the Performance Share Award is granted to a Participant and ends on December 31 of the three-year period.

4. Number of Target Performance Shares and Deemed Dividends. A target number of Performance Shares are awarded to a Participant and allocated among the goals established by the Committee as set forth in Exhibit 1. No actual shares of Common Stock are issued to, or otherwise set aside for, the Participant at the time of grant.

The deemed dividends associated with the Performance Shares during the Performance Period shall be credited and treated as reinvested in additional Performance Shares. Reinvested dividends will not be received until the Performance Share Award is paid out and will depend on Company achievement of the performance goals. If no Performance Shares are earned and paid out, no dividends will be paid out.

5. Establishing Performance Goal Measures. The performance goal measures will be established by the Committee.

6. Determining Payment of Performance Share Award. After the end of the Performance Period, a Participant shall receive between 0% and 200% of the Performance Share Award, as adjusted to reflect deemed dividend reinvestment, depending on Company performance measured against the performance goals approved by the Committee set forth on Exhibit 1. Each goal result will be determined and a payment percentage determined relative to the target amount of Performance Shares granted to the Participant. Prior to payment, the Committee shall certify that the requirements necessary to receive a payment under each performance goal have been met. Payment for performance between points is interpolated on a straight-line basis.

7. Vesting and Payment of Award. The Performance Share Award does not vest until the last day of the Performance Period (“Vesting Date”). A Participant must be an Employee on the Vesting Date to receive payment, except as follows:

Employment Termination Event	Impact on Performance Shares	Vesting and Timing of Payment
Retirement	Full payment of earned Award	No change to vesting and payment schedule
Disability	Earned Award is prorated based on months of actual employment during Performance Period	No change to vesting and payment schedule
Death	Earned Award is prorated based on months of actual employment during Performance Period	No change to vesting and payment schedule
Other voluntary or involuntary separation	Forfeit unvested Award	N/A
Cause	Forfeit unpaid Award, even if vested	N/A

See the LTI Program Document for additional information on the impact of certain employment events on the vesting of Performance Share Awards.

Performance Share Awards will be paid in unrestricted shares of Common Stock as soon as practicalfollowing the end of the Performance Period, but in no event later than March 15 immediately following the end of the Performance Period.

The Performance Share Award payment is subject to applicable withholding taxes. For purposes of tax calculations, the value of the Common Stock earned by a Participant will be determined based on the Fair Market Value on the payment date. The actual number of shares a Participant may receive will be reduced by the number of shares reflecting the amount of withholding taxes.

8. Deferral of Payment. Participants in the Southern Company Deferred Compensation Plan may not defer receipt of Performance Share Award payments.

9. Transferability and Share Ownership. Performance Shares are not transferable or assignable in any manner except by will or the laws of descent and distribution. A Participant is not considered to own any shares of Common Stock based on the

Performance Share Award until the Common Stock is issued to a Participant.

10. No Right to Employment. Neither a Performance Share Award nor this Form of Terms creates any right to employment or continuation of current employment or the right to any future Awards under the Plan. No provision of this Form of Terms shall be construed to affect in any manner the existing rights of the Company or its affiliates to suspend, terminate, alter or modify, whether or not for cause, the Participant’s employment relationship with the Company or its affiliates.

11. Impact on Other Plans. Neither the Performance Share Award nor the final payment of the Performance Share Award in Common Stock is considered “Compensation” for purposes of the Southern Company Employee Savings Plan or “Earnings” as defined in The Southern Company Pension Plan. Payments to Participants shall not be considered wages, salary, or compensation under any other Company-sponsored employee benefit or compensation plan or program, unless the explicit terms of such plan or program provide otherwise.

Exhibit 1 – Performance Goals

Performance Measures. The number of shares of Common Stock that can be earned by a Participant under this Performance Share Award is based on the achievement of two separate performance goals established by the Committee, as well as achievement of the Credit Quality Threshold Goal described below.

a. Company Relative Total Shareholder Return (TSR) measures Company stock price performance plus dividends relative to a peer group approved by the Committee. Relative TSR performance accounts for 40% of a Participant’s long-term incentive grant value.

b. Return on Equity (ROE) measures the Southern Company ROE during the Performance Period. ROE performance accounts for 30% of a Participant’s long-term incentive grant value.

Credit Quality Threshold Goals. The ROE goal described above is subject to credit quality threshold goals established by the Committee at the time of the grant. If, at the end of the performance period, the credit ratings for the Company, Alabama Power Company and Georgia Power Company are below specified levels approved by the Committee, there will be no payment associated with the ROE goal.

SOUTHERN COMPANY

OMNIBUS INCENTIVE COMPENSATION PLAN

FORM OF TERMS

PERFORMANCE SHARE AWARD

(Southern Company Chief Executive Officer)

A Performance Share Award is subject to the following terms and conditions:

1. Award. A target number of performance share units (“Performance Shares” or “Performance Share Award”) is granted by the Compensation and Management Succession Committee (“Committee”) of The Southern Company (“Company”) Board of Directors to the Southern Company Chief Executive Officer (“Participant”). The Performance Share Award provides the Participant an opportunity to earn shares of Common Stock based on Company performance over a three-year Performance Period (as defined below) against the performance goal measures set forth in Exhibit 1. Performance Share Awards are granted pursuant to and are governed by the Southern Company Omnibus Incentive Compensation Plan, as amended from time to time (“Plan”).

2. Terms. Terms used in this Form of Terms that are defined in the Plan will have the meanings ascribed to them in the Plan. The Long-Term Incentive Program Document (the “LTI Program Document”), an administrative document adopted by the Committee which is set forth at https:/mysource.southernco.com, contains additional provisions that apply to Performance Share Awards. Performance Share Awards are subject to the terms and conditions set forth in the Plan and any other administrative documents adopted by the Committee from time to time. If there is any inconsistency between the terms herein and the terms of the Plan or any administrative document adopted by the Committee, the Plan’s terms and the administrative document’s terms will supersede and replace the conflicting terms of this Form of Terms.

3. Performance Period. The period during which the performance goal measures apply (“Performance Period”) will be a three-year period that begins on January 1 of the year the Performance Share Award is granted to a Participant and ends on December 31 of the three-year period.

4. Number of Target Performance Shares and Deemed Dividends. A target number of Performance Shares are awarded to a Participant and allocated among the goals established by the Committee as set forth in Exhibit 1. No actual shares of Common Stock are issued to, or otherwise set aside for, the Participant at the time of grant.

The deemed dividends associated with the Performance Shares during the Performance Period shall be credited and treated as reinvested in additional Performance Shares. Reinvested dividends will not be received until the Performance Share Award is paid out and will depend on Company achievement of the performance goals. If no Performance Shares are earned and paid out, no dividends will be paid out.

5. Establishing Performance Goal Measures. The performance goal measures will be established by the Committee.

6. Determining Payment of Performance Share Award. After the end of the Performance Period, a Participant shall receive between 0% and 200% of the Performance Share Award subject to the first two performance goals set forth in Exhibit 1 and between 0% and 150% of the Performance Share Award subject to the final performance goal set forth in Exhibit 1, all as adjusted to reflect deemed dividend reinvestment, depending on Company performance measured against the performance goals approved by the Committee set forth on Exhibit 1. Each goal result will be determined and a payment percentage determined relative to the target amount of Performance Shares granted to the Participant. Prior to payment, the Committee shall certify that the requirements necessary to receive a payment under each performance goal have been met. Payment for performance between points is interpolated on a straight-line basis.

7. Vesting and Payment of Award. The Performance Share Award does not vest until the last day of the Performance Period (“Vesting Date”). A Participant must be an Employee on the Vesting Date to receive payment, except as follows:

Employment Termination Event	Impact on Performance Shares	Vesting and Timing of Payment
Retirement	Full payment of earned Award	No change to vesting and payment schedule
Disability	Earned Award is prorated based on months of actual employment during Performance Period	No change to vesting and payment schedule
Death	Earned Award is prorated based on months of actual employment during Performance Period	No change to vesting and payment schedule
Other voluntary or involuntary separation	Forfeit unvested Award	N/A
Cause	Forfeit unpaid Award, even if vested	N/A

See the LTI Program Document for additional information on the impact of certain employment events on the vesting of Performance Share Awards.

Performance Share Awards will be paid in unrestricted shares of Common Stock as soon as practicalfollowing the end of the Performance Period, but in no event later than March 15 immediately following the end of the Performance Period.

The Performance Share Award payment is subject to applicable withholding taxes. For purposes of tax calculations, the value of the Common Stock earned by a Participant will be determined based on the Fair Market Value on the payment date. The actual number of shares a Participant may receive will be reduced by the number of shares reflecting the amount of withholding taxes.

8. Deferral of Payment. Participants in the Southern Company Deferred Compensation Plan may not defer receipt of Performance Share Award payments.

9. Transferability and Share Ownership. Performance Shares are not transferable or assignable in any manner except by will or the laws of descent and distribution. A Participant is not considered to own any shares of Common Stock based on the Performance Share Award until the Common Stock is issued to a Participant.

10. No Right to Employment. Neither a Performance Share Award nor this Form of Terms creates any right to employment or continuation of current employment or the right to any future Awards under the Plan. No provision of this Form of Terms shall be construed to affect in any manner the existing rights of the Company or its affiliates to suspend, terminate, alter or modify, whether or not for cause, the Participant’s employment relationship with the Company or its affiliates.

11. Impact on Other Plans. Neither the Performance Share Award nor the final payment of the Performance Share Award in Common Stock is considered “Compensation” for purposes of the Southern Company Employee Savings Plan or “Earnings” as defined in The Southern Company Pension Plan. Payments to Participants shall not be considered wages, salary, or compensation under any other Company-sponsored employee benefit or compensation plan or program, unless the explicit terms of such plan or program provide otherwise.

Exhibit 1 – Performance Goals

Performance Measures. The number of shares of Common Stock that can be earned by a Participant under this Performance Share Award is based on the achievement of three separate performance goals established by the Committee, as well as achievement of the Credit Quality Threshold Goal described below.

a. Company Relative Total Shareholder Return (TSR) measures Company stock price performance plus dividends relative to a peer group approved by the Committee. Relative TSR performance accounts for 40% of a Participant’s long-term incentive grant value.

b. Return on Equity (ROE) measures the Southern Company ROE during the Performance Period. ROE performance accounts for 25% of a Participant’s long-term incentive grant value.

c. Carbon Reduction Goal measures Southern Company’s progress towards its 2030 greenhouse gas reduction goal during the Performance Period and accounts for 10% of the Participant’s long-term incentive grant value. The Participant’s Carbon Reduction Goal is measured in terms of megawatt changes over the Performance Period with a payout modifier for the Committee’s assessment of progress towards advancing the energy portfolio of the future (up to 30%).

Credit Quality Threshold Goals. The ROE goal described above is subject to credit quality threshold goals established by the Committee at the time of the grant. If, at the end of the performance period, the credit ratings for the Company, Alabama Power Company and Georgia Power Company are below specified levels approved by the Committee, there will be no payment associated with the ROE goal.

SOUTHERN COMPANY

OMNIBUS INCENTIVE COMPENSATION PLAN

FORM OF TERMS

RESTRICTED STOCK UNIT WITH PERFORMANCE MEASURE AWARD

A Restricted Stock Unit with performance measure (“RSU”) Award is subject to the following terms and conditions:

1. Award. A specific number of RSUs is granted by the Compensation and Management Succession Committee (“Committee”) of The Southern Company (“Company”) Board of Directors to a Participant. The RSU Award provides the Participant an opportunity to earn shares of Common Stock based on Company performance over a one-year Performance Period (as defined below) subject to the attainment of a performance measure set by the Committee. RSU Awards are granted pursuant to and are governed by the Southern Company Omnibus Incentive Compensation Plan, as amended from time to time (“Plan”).

2. Terms. Terms used in this Form of Terms that are defined in the Plan will have the meanings ascribed to them in the Plan. The Long-Term Incentive Program Document (the “LTI Program Document”), an administrative document adopted by the Committee which is set forth at https:/mysource.southernco.com, contains additional provisions that apply to RSU Awards. Additionally, RSU Awards are subject to the terms and conditions set forth in the Plan and any other administrative documents adopted by the Committee from time to time. If there is any inconsistency between the terms herein and the terms of the Plan or any administrative document adopted by the Committee, the Plan’s terms and the administrative document’s terms will supersede and replace the conflicting terms of this Form of Terms.

3. Number of RSUs and Deemed Dividends. The Committee shall determine the specified number of RSUs awarded to a Participant. The deemed dividends associated with the RSUs shall be credited and treated as reinvested in additional RSUs until each amount vests and is paid.

4. Performance Period. The period during which the performance measure will apply is the calendar year of the date of grant (“Grant Date”) of the RSU Award (“Performance Period”).

5. Establishing Performance Measure. The performance measure will be established by the Committee.

6. Satisfaction of Performance Measure. The Committee shall determine whether the performance measure was attained, and if so, shall certify such attainment (the “Certification Date”). If the performance measure is not attained, the RSUs shall be forfeited as of the Certification Date.

7. Vesting and Payment of Award. If the performance measure is attained, as certified by the Committee, the RSU Award will vest as follows:

Amount	Vesting Date
1/3 of RSU Award	Certification Date
1/3 of RSU Award	2-Year Anniversary of Grant Date
1/3 of RSU Award	3-Year Anniversary of Grant Date

Participant must be an Employee on the applicable Vesting Date to receive payment, except as follows:

Employment Termination Event	Impact on RSU Award	Vesting and Timing of Payment
Retirement (1)	Full payment of earned Award not yet paid out	No change to vesting and payment schedule
Disability	Full payment of remaining Award not yet paid out	Accelerated vesting; payable in full within 30 days
Death	Full payment of remaining Award not yet paid out	Accelerated vesting; payable in full within 30 days
Other voluntary or involuntary separation	Forfeit unvested RSU Award	N/A
Cause	Forfeit unpaid RSU Award, even if vested	N/A

⁽¹⁾ For avoidance of doubt, no RSU Award will be payable to a Participant that Retires unless the performance measure is attained.

See the LTI Program Document for additional information on the impact of certain employment events on the vesting and payment of RSU Awards.

RSU Awards will be paid in unrestricted shares of Common Stock as soon as practicalfollowing the Vesting Date, but in no event later than 30 days following the Vesting Date.

The RSU Award payment is subject to applicable withholding taxes. For purposes of tax calculations, the value of the Common Stock earned by a Participant will be determined based on the Fair Market Value on the payment date. The actual number of shares a Participant may receive will be reduced by the number of shares reflecting the amount of withholding taxes.

8. Deferral of Payout. Participants in the Southern Company Deferred Compensation Plan may not defer receipt of RSU Award payments.

9. Transferability and Share Ownership. RSUs are not transferable or assignable in any manner except by will or the laws of descent and distribution. A Participant is not considered to own any shares of Common Stock based on the RSU Award until after the Vesting Date and the Common Stock is issued to a Participant.

10. No Right to Employment. Neither a RSU Award nor this Form of Terms creates any right to employment or continuation of current employment or the right to any future Awards under the Plan. No provision of this Form of Terms shall be construed to affect in any manner the existing rights of the Company or its affiliates to suspend, terminate, alter or modify, whether or not for cause, the Participant’s employment relationship with the Company or its affiliates.

11. Impact on Other Plans. Neither the RSU Award nor the payment of the RSU Award in Common Stock is considered “Compensation” for purposes of the Southern Company Employee Savings Plan or “Earnings” as defined in The Southern Company Pension Plan. Payments to Participants shall not be considered wages, salary, or compensation under any other Company-sponsored employee benefit or compensation plan or program, unless the explicit terms of such plan or program provide otherwise.

Exhibit 1 – Performance Goal

Performance Measure. The Participant has the opportunity to earn shares of Common Stock based on the attainment of the following Company performance measure that has been established by the Committee:

2019 Cash from Operations is greater than $2.425 billion (2018 Dividends Paid)

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 30, 2019

/s/Thomas A. Fanning

Thomas A. Fanning

Chairman, President and

Chief Executive Officer

EX-31.A2

Exhibit 31(a)2

THE SOUTHERN COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Andrew W. Evans, 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 30, 2019

/s/Andrew W. Evans

Andrew W. Evans

Executive Vice President and Chief Financial Officer

EX-31.B1

Exhibit 31(b)1

ALABAMA POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Mark A. Crosswhite, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  April 30, 2019

/s/Mark A. Crosswhite

Mark A. Crosswhite

Chairman, President and Chief Executive Officer

EX-31.B2

Exhibit 31(b)2

ALABAMA POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Philip C. Raymond, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  April 30, 2019

/s/Philip C. Raymond

Philip C. Raymond

Executive Vice President, Chief Financial Officer

and Treasurer

EX-31.C1

Exhibit 31(c)1

GEORGIA POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, W. Paul Bowers, 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 30, 2019

/s/W. Paul Bowers

W. Paul Bowers

Chairman, President and Chief Executive Officer

EX-31.C2

Exhibit 31(c)2

GEORGIA POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, David P. Poroch, 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 30, 2019

/s/David P. Poroch

David P. Poroch

Executive Vice President, Chief Financial Officer, Treasurer, & Comptroller

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 30, 2019

/s/Anthony L. Wilson

Anthony L. Wilson

Chairman, President and

 Chief Executive Officer

EX-31.D2

Exhibit 31(d)2

MISSISSIPPI POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Moses H. Feagin, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  April 30, 2019

/s/Moses H. Feagin

Moses H. Feagin

Vice President, Treasurer and

Chief Financial Officer

EX-31.E1

Exhibit 31(e)1

SOUTHERN POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Mark S. Lantrip, 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 30, 2019

/s/Mark S. Lantrip

Mark S. Lantrip

Chairman, President and Chief Executive Officer

EX-31.E2

Exhibit 31(e)2

SOUTHERN POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, William C. Grantham, 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 30, 2019

/s/William C. Grantham

William C. Grantham

Senior Vice President, Treasurer and Chief

Financial Officer

EX-31.F1

Exhibit 31(f)1

SOUTHERN COMPANY GAS

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Kimberly S. Greene, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  April 30, 2019

/s/Kimberly S. Greene

Kimberly S. Greene

Chairman, President, and Chief Executive Officer

EX-31.F2

Exhibit 31(f)2

SOUTHERN COMPANY GAS

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Daniel S. Tucker, 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 30, 2019

/s/Daniel S. Tucker

Daniel S. Tucker

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, 2019, 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, 2019, 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, 2019, fairly presents, in all material respects, the financial condition and results of operations of The Southern Company.

/s/Thomas A. Fanning

Thomas A. Fanning

Chairman, President and

Chief Executive Officer

/s/Andrew W. Evans

Andrew W. Evans

Executive Vice President and

Chief Financial Officer

April 30, 2019

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, 2019, 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, 2019, 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, 2019, fairly presents, in all material respects, the financial condition and results of operations of Alabama Power Company.

/s/Mark A. Crosswhite

Mark A. Crosswhite

Chairman, President and Chief Executive Officer

/s/Philip C. Raymond

Philip C. Raymond

Executive Vice President,

Chief Financial Officer and Treasurer

April 30, 2019

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, 2019, 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, 2019, 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, 2019, fairly presents, in all material respects, the financial condition and results of operations of Georgia Power Company.

/s/W. Paul Bowers

W. Paul Bowers

Chairman, President and Chief Executive Officer

/s/David P. Poroch

David P. Poroch

Executive Vice President, Chief Financial Officer, Treasurer, & Comptroller

April 30, 2019

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, 2019, 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, 2019, 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, 2019, fairly presents, in all material respects, the financial condition and results of operations of Mississippi Power Company.

/s/Anthony L. Wilson

Anthony L. Wilson

Chairman, President and Chief Executive Officer

/s/Moses H. Feagin

Moses H. Feagin

Vice President, Treasurer and

Chief Financial Officer

April 30, 2019

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, 2019, 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, 2019, 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, 2019, fairly presents, in all material respects, the financial condition and results of operations of Southern Power Company.

/s/Mark S. Lantrip

Mark S. Lantrip

 Chairman, President

and Chief Executive Officer

/s/William C. Grantham

William C. Grantham

Senior Vice President, Treasurer and

Chief Financial Officer

April 30, 2019

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, 2019, 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, 2019, 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, 2019, fairly presents, in all material respects, the financial condition and results of operations of Southern Company Gas.

/s/Kimberly S. Greene

Kimberly S. Greene

Chairman, President, and Chief Executive Officer

/s/Daniel S. Tucker

Daniel S. Tucker

Executive Vice President, Chief Financial

Officer, and Treasurer

April 30, 2019

XML

Document and Entity Information	3 Months Ended
	Mar. 31, 2019 shares
Document Information [Line Items]
Entity Registrant Name	SOUTHERN CO
Entity Central Index Key	0000092122
Document Type	10-Q
Document Period End Date	Mar. 31, 2019
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding	1,040,295,732
ALABAMA POWER CO
Document Information [Line Items]
Entity Registrant Name	ALABAMA POWER CO
Entity Central Index Key	0000003153
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding	30,537,500
GEORGIA POWER CO
Document Information [Line Items]
Entity Registrant Name	GEORGIA POWER CO
Entity Central Index Key	0000041091
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding	9,261,500
MISSISSIPPI POWER CO
Document Information [Line Items]
Entity Registrant Name	MISSISSIPPI POWER CO
Entity Central Index Key	0000066904
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding	1,121,000
SOUTHERN POWER CO
Document Information [Line Items]
Entity Registrant Name	SOUTHERN POWER CO
Entity Central Index Key	0001160661
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding	1,000
SOUTHERN Co GAS
Document Information [Line Items]
Entity Registrant Name	SOUTHERN Co GAS
Entity Central Index Key	0001004155
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding	100

XML

Condensed Consolidated Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Revenues:
Total operating revenues	$ 5,412	$ 6,372
Operating Expenses:
Other operations and maintenance	1,312	1,451
Depreciation and amortization	751	769
Taxes other than income taxes	329	355
Estimated loss on plants under construction	2	44
Gain on dispositions, net	(2,497)	0
Total operating expenses	1,721	4,996
Operating Income (Loss)	3,691	1,376
Other Income and (Expense):
Allowance for equity funds used during construction	32	30
Earnings from equity method investments	48	41
Interest expense, net of amounts capitalized	(430)	(458)
Other income (expense), net	78	60
Total other income and (expense)	(272)	(327)
Earnings (Loss) Before Income Taxes	3,419	1,049
Income taxes	1,360	113
Consolidated net income (loss)	2,059	936
Dividends on preferred stock of subsidiaries	4	4
Net loss attributable to noncontrolling interests	(29)	(6)
Net Income (Loss)	$ 2,084	$ 938
Earnings per share -
Basic (in dollars per share)	$ 2.01	$ 0.93
Diluted (in dollars per share)	$ 1.99	$ 0.92
Average number of shares of common stock outstanding (in millions)
Basic (in shares)	1,038	1,011
Diluted (in shares)	1,045	1,016
Retail electric revenues
Operating Revenues:
Total operating revenues	$ 3,084	$ 3,568
Wholesale electric revenues
Operating Revenues:
Total operating revenues	499	623
Other electric revenues
Operating Revenues:
Total operating revenues	168	161
Natural gas
Operating Revenues:
Total operating revenues	1,474	1,607
Operating Expenses:
Total cost of natural gas	686	720
Other
Operating Revenues:
Total operating revenues	187	413
Operating Expenses:
Total cost of natural gas	118	289
Fuel
Operating Expenses:
Total cost of natural gas	850	1,101
Purchased power
Operating Expenses:
Total cost of natural gas	170	267
ALABAMA POWER CO
Operating Revenues:
Total operating revenues	1,408	1,473
Operating Expenses:
Other operations and maintenance	409	387
Depreciation and amortization	199	189
Taxes other than income taxes	103	98
Total operating expenses	1,070	1,101
Operating Income (Loss)	338	372
Other Income and (Expense):
Allowance for equity funds used during construction	14	13
Interest expense, net of amounts capitalized	(83)	(79)
Other income (expense), net	14	5
Total other income and (expense)	(55)	(61)
Earnings (Loss) Before Income Taxes	283	311
Income taxes	62	82
Consolidated net income (loss)	221	229
Dividends on preferred stock of subsidiaries	4	4
Net Income (Loss)	217	225
ALABAMA POWER CO | Retail electric revenues
Operating Revenues:
Total operating revenues	1,213	1,285
ALABAMA POWER CO | Wholesale electric revenues
Operating Revenues:
Total operating revenues	61	74
ALABAMA POWER CO | Other
Operating Revenues:
Total operating revenues	74	63
ALABAMA POWER CO | Fuel
Operating Expenses:
Total cost of natural gas	301	326
ALABAMA POWER CO | Purchased power
Operating Expenses:
Total cost of natural gas	37	64
ALABAMA POWER CO | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	60	51
ALABAMA POWER CO | Purchased power, affiliates
Operating Expenses:
Total cost of natural gas	21	37
GEORGIA POWER CO
Operating Revenues:
Total operating revenues	1,833	1,961
Operating Expenses:
Other operations and maintenance	446	408
Depreciation and amortization	240	228
Taxes other than income taxes	106	108
Total operating expenses	1,385	1,448
Operating Income (Loss)	448	513
Other Income and (Expense):
Interest expense, net of amounts capitalized	(96)	(106)
Other income (expense), net	40	38
Total other income and (expense)	(56)	(68)
Earnings (Loss) Before Income Taxes	392	445
Income taxes	81	93
Consolidated net income (loss)	311	352
Net Income (Loss)	311	352
GEORGIA POWER CO | Retail electric revenues
Operating Revenues:
Total operating revenues	1,668	1,798
GEORGIA POWER CO | Wholesale electric revenues
Operating Revenues:
Total operating revenues	29	44
GEORGIA POWER CO | Other
Operating Revenues:
Total operating revenues	133	109
GEORGIA POWER CO | Fuel
Operating Expenses:
Total cost of natural gas	299	412
GEORGIA POWER CO | Purchased power
Operating Expenses:
Total cost of natural gas	118	121
GEORGIA POWER CO | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	3	10
GEORGIA POWER CO | Purchased power, affiliates
Operating Expenses:
Total cost of natural gas	176	171
MISSISSIPPI POWER CO
Operating Revenues:
Total operating revenues	287	302
Operating Expenses:
Other operations and maintenance	59	75
Depreciation and amortization	48	41
Taxes other than income taxes	26	28
Estimated loss on plants under construction	2	44
Total operating expenses	231	295
Operating Income (Loss)	56	7
Other Income and (Expense):
Interest expense, net of amounts capitalized	(17)	(19)
Other income (expense), net	5	1
Total other income and (expense)	(12)	(18)
Earnings (Loss) Before Income Taxes	44	(11)
Income taxes	7	(4)
Consolidated net income (loss)	37	(7)
Net Income (Loss)	37	(7)
MISSISSIPPI POWER CO | Retail electric revenues
Operating Revenues:
Total operating revenues	203	194
MISSISSIPPI POWER CO | Wholesale electric revenues
Operating Revenues:
Total operating revenues	57	68
MISSISSIPPI POWER CO | Other
Operating Revenues:
Total operating revenues	5	6
MISSISSIPPI POWER CO | Fuel
Operating Expenses:
Total cost of natural gas	93	98
MISSISSIPPI POWER CO | Purchased power
Operating Expenses:
Total cost of natural gas	3	9
MISSISSIPPI POWER CO | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	22	34
SOUTHERN POWER CO
Operating Revenues:
Total operating revenues	443	509
Operating Expenses:
Other operations and maintenance	84	93
Depreciation and amortization	119	114
Taxes other than income taxes	11	12
Total operating expenses	383	449
Operating Income (Loss)	60	60
Other Income and (Expense):
Interest expense, net of amounts capitalized	(44)	(47)
Other income (expense), net	2	3
Total other income and (expense)	(42)	(44)
Earnings (Loss) Before Income Taxes	18	16
Income taxes	(9)	(99)
Consolidated net income (loss)	27	115
Net loss attributable to noncontrolling interests	(29)	(6)
Net Income (Loss)	56	121
SOUTHERN POWER CO | Wholesale electric revenues
Operating Revenues:
Total operating revenues	352	424
SOUTHERN POWER CO | Other
Operating Revenues:
Total operating revenues	4	2
SOUTHERN POWER CO | Fuel
Operating Expenses:
Total cost of natural gas	145	169
SOUTHERN POWER CO | Purchased power
Operating Expenses:
Total cost of natural gas	24	61
SOUTHERN POWER CO | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	87	83
SOUTHERN Co GAS
Operating Revenues:
Total operating revenues	1,474	1,639
Operating Expenses:
Other operations and maintenance	235	276
Depreciation and amortization	118	129
Taxes other than income taxes	82	77
Goodwill impairment	0	42
Total operating expenses	1,121	1,251
Operating Income (Loss)	353	388
Other Income and (Expense):
Earnings from equity method investments	48	42
Interest expense, net of amounts capitalized	(59)	(59)
Other income (expense), net	5	12
Total other income and (expense)	(6)	(5)
Earnings (Loss) Before Income Taxes	347	383
Income taxes	77	104
Consolidated net income (loss)	270	279
Net Income (Loss)	270	279
SOUTHERN Co GAS | Natural gas
Operating Revenues:
Total operating revenues	1,476	1,631
Operating Expenses:
Total cost of natural gas	686	720
SOUTHERN Co GAS | Other
Operating Revenues:
Total operating revenues	0	32
Operating Expenses:
Total cost of natural gas	0	7
SOUTHERN Co GAS | Alternative revenue programs
Operating Revenues:
Total operating revenues	$ (2)	$ (24)

XML

Condensed Consolidated Statements of Income (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Alternative revenue programs
Total operating revenues	$ (2)	$ (24)
SOUTHERN Co GAS
Excise taxes collected	$ 55	$ 51

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Net income (loss)	$ 2,059	$ 936
Qualifying hedges:
Changes in fair value, net of tax	(28)	47
Reclassification adjustment for amounts included in net income, net of tax	28	(19)
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	0	2
Total other comprehensive income (loss)	0	30
Comprehensive Income (Loss)	2,059	966
Less:
Dividends on preferred stock of subsidiaries	4	4
Comprehensive loss attributable to noncontrolling interests	(29)	(6)
Comprehensive Income (Loss) Attributable to Parent	2,084	968
ALABAMA POWER CO
Net income (loss)	221	229
Qualifying hedges:
Reclassification adjustment for amounts included in net income, net of tax	1	1
Pension and other postretirement benefit plans:
Total other comprehensive income (loss)	1	1
Comprehensive Income (Loss)	222	230
Less:
Dividends on preferred stock of subsidiaries	4	4
GEORGIA POWER CO
Net income (loss)	311	352
Qualifying hedges:
Reclassification adjustment for amounts included in net income, net of tax	1	1
Pension and other postretirement benefit plans:
Total other comprehensive income (loss)	1	1
Comprehensive Income (Loss)	312	353
MISSISSIPPI POWER CO
Net income (loss)	37	(7)
Qualifying hedges:
Changes in fair value, net of tax	0	(1)
Pension and other postretirement benefit plans:
Total other comprehensive income (loss)	0	(1)
Comprehensive Income (Loss)	37	(8)
SOUTHERN POWER CO
Net income (loss)	27	115
Qualifying hedges:
Changes in fair value, net of tax	(29)	48
Reclassification adjustment for amounts included in net income, net of tax	25	(24)
Pension and other postretirement benefit plans:
Total other comprehensive income (loss)	(4)	24
Comprehensive Income (Loss)	23	139
Less:
Comprehensive loss attributable to noncontrolling interests	(29)	(6)
Comprehensive Income (Loss) Attributable to Parent	52	145
SOUTHERN Co GAS
Net income (loss)	270	279
Qualifying hedges:
Changes in fair value, net of tax	0	1
Reclassification adjustment for amounts included in net income, net of tax	0	2
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	(1)	(1)
Total other comprehensive income (loss)	(1)	2
Comprehensive Income (Loss)	$ 269	$ 281

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Qualifying hedges:
Changes in fair value, tax	$ (9)	$ 16
Reclassification adjustment for amounts included in net income, tax	9	(6)
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, tax	0	0
ALABAMA POWER CO
Qualifying hedges:
Reclassification adjustment for amounts included in net income, tax	0	1
GEORGIA POWER CO
Qualifying hedges:
Reclassification adjustment for amounts included in net income, tax	0	0
MISSISSIPPI POWER CO
Qualifying hedges:
Changes in fair value, tax	0	(1)
SOUTHERN POWER CO
Qualifying hedges:
Changes in fair value, tax	(10)	16
Reclassification adjustment for amounts included in net income, tax	8	(8)
SOUTHERN Co GAS
Qualifying hedges:
Changes in fair value, tax	0	0
Reclassification adjustment for amounts included in net income, tax	0	1
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, tax	$ 0	$ 0

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Activities:
Net income (loss)	$ 2,059	$ 936
Adjustments to reconcile net income (loss) to net cash provided from (used for) operating activities —
Depreciation and amortization, total	851	873
Deferred income taxes	191	34
Allowance for equity funds used during construction	(32)	(30)
Pension, postretirement, and other employee benefits	(53)	(27)
Settlement of asset retirement obligations	(62)	(41)
Stock based compensation expense	64	69
Estimated loss on Kemper IGCC	6	37
Mark-to-market adjustments	46	(60)
Gain on dispositions, net	(2,503)	1
Other, net	19	73
Changes in certain current assets and liabilities —
-Receivables	378	197
-Prepayments	(129)	(82)
-Natural gas for sale	363	413
-Other current assets	17	7
-Accounts payable	(783)	(425)
-Accrued taxes	928	(79)
-Accrued compensation	(489)	(471)
-Other current liabilities	(127)	84
Net cash used for operating activities	744	1,509
Investing Activities:
Business acquisitions, net of cash acquired	(2)	(46)
Property additions	(1,678)	(1,781)
Nuclear decommissioning trust fund purchases	(197)	(306)
Nuclear decommissioning trust fund sales	192	301
Cost of removal, net of salvage	(89)	(79)
Proceeds from asset dispositions	4,427	135
Change in construction payables, net	(146)	(112)
Investment in unconsolidated subsidiaries	(10)	(30)
Payments pursuant to LTSAs	(28)	(73)
Other investing activities	(15)	(4)
Net cash provided from (used for) investing activities	2,454	(1,995)
Financing Activities:
Increase (decrease) in notes payable, net	86	782
Proceeds —
Long-term debt	1,220	600
Common stock	224	113
Short-term borrowings	0	1,200
Redemptions and repurchases —
Long-term debt	(2,429)	(1,283)
Short-term borrowings	(1,750)	(150)
Distributions to noncontrolling interests	(36)	(13)
Capital contributions from noncontrolling interests	3	8
Payment of common stock dividends	(623)	(586)
Other financing activities	(48)	(42)
Net cash provided from (used for) financing activities	(3,353)	629
Net Change in Cash, Cash Equivalents, and Restricted Cash	(155)	143
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,519	2,147
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,364	2,290
Cash paid (received) during the period for —
Interest, net of amounts capitalized	462	499
Income taxes, net	0	(1)
Noncash transactions — Accrued property additions at end of period	899	894
ALABAMA POWER CO
Operating Activities:
Net income (loss)	221	229
Adjustments to reconcile net income (loss) to net cash provided from (used for) operating activities —
Depreciation and amortization, total	244	228
Deferred income taxes	0	32
Allowance for equity funds used during construction	(14)	(13)
Other, net	(24)	(21)
Changes in certain current assets and liabilities —
-Receivables	105	(1)
-Prepayments	(78)	(82)
-Materials and supplies	(4)	(27)
-Other current assets	19	19
-Accounts payable	(286)	(216)
-Accrued taxes	80	57
-Accrued compensation	(122)	(108)
-Other current liabilities	(9)	45
Net cash used for operating activities	146	155
Investing Activities:
Property additions	(390)	(490)
Nuclear decommissioning trust fund purchases	(68)	(50)
Nuclear decommissioning trust fund sales	68	51
Cost of removal, net of salvage	(16)	(19)
Change in construction payables, net	(95)	(50)
Other investing activities	(10)	(6)
Net cash provided from (used for) investing activities	(511)	(564)
Financing Activities:
Increase (decrease) in notes payable, net	0	245
Proceeds —
Capital contributions from parent company	1,232	484
Redemptions and repurchases —
Senior notes	(200)	0
Payment of common stock dividends	(211)	(202)
Other financing activities	(10)	(9)
Net cash provided from (used for) financing activities	811	518
Net Change in Cash, Cash Equivalents, and Restricted Cash	446	109
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	313	544
Cash, Cash Equivalents, and Restricted Cash at End of Period	759	653
Cash paid (received) during the period for —
Interest, net of amounts capitalized	89	84
Income taxes, net	0	9
Noncash transactions — Accrued property additions at end of period	176	195
GEORGIA POWER CO
Operating Activities:
Net income (loss)	311	352
Adjustments to reconcile net income (loss) to net cash provided from (used for) operating activities —
Depreciation and amortization, total	287	280
Deferred income taxes	127	(38)
Pension, postretirement, and other employee benefits	(35)	(19)
Settlement of asset retirement obligations	(34)	(23)
Other, net	(18)	28
Changes in certain current assets and liabilities —
-Receivables	91	135
-Fossil fuel stock	(41)	24
-Prepaid income taxes	(73)	84
-Other current assets	33	9
-Accounts payable	(166)	(180)
-Accrued taxes	(245)	(191)
-Accrued compensation	(67)	(85)
-Other current liabilities	42	(3)
Net cash used for operating activities	212	373
Investing Activities:
Property additions	(875)	(681)
Nuclear decommissioning trust fund purchases	(129)	(255)
Nuclear decommissioning trust fund sales	124	250
Cost of removal, net of salvage	(58)	(26)
Proceeds from asset dispositions	7	134
Change in construction payables, net of joint owner portion	(38)	(47)
Payments pursuant to LTSAs	(2)	(43)
Other investing activities	(9)	0
Net cash provided from (used for) investing activities	(980)	(668)
Financing Activities:
Increase (decrease) in notes payable, net	(19)	0
Proceeds —
FFB loan	835	0
Pollution control revenue bonds	343	0
Capital contributions from parent company	27	1,474
Redemptions and repurchases —
Pollution control revenue bonds	(108)	(278)
Short-term borrowings	0	(150)
Other long-term debt	0	(100)
Payment of common stock dividends	(394)	(339)
Other financing activities	(19)	(6)
Net cash provided from (used for) financing activities	665	601
Net Change in Cash, Cash Equivalents, and Restricted Cash	(103)	306
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	112	852
Cash, Cash Equivalents, and Restricted Cash at End of Period	9	1,158
Cash paid (received) during the period for —
Interest, net of amounts capitalized	92	115
Noncash transactions — Accrued property additions at end of period	607	525
MISSISSIPPI POWER CO
Operating Activities:
Net income (loss)	37	(7)
Adjustments to reconcile net income (loss) to net cash provided from (used for) operating activities —
Depreciation and amortization, total	50	44
Deferred income taxes	(8)	155
Estimated loss on Kemper IGCC	6	37
Other, net	(10)	3
Changes in certain current assets and liabilities —
-Receivables	11	(129)
-Other current assets	7	(12)
-Accounts payable	(38)	(21)
-Accrued taxes	(62)	(110)
-Accrued compensation	(22)	(22)
-Other current liabilities	6	0
Net cash used for operating activities	(23)	(62)
Investing Activities:
Property additions	(45)	(33)
Change in construction payables, net	(8)	(2)
Other investing activities	(10)	(17)
Net cash provided from (used for) investing activities	(63)	(52)
Financing Activities:
Increase (decrease) in notes payable, net	0	(4)
Proceeds —
Senior notes	0	600
Short-term borrowings	0	300
Pollution control revenue bonds	43	0
Redemptions and repurchases —
Other long-term debt	0	(900)
Return of capital	(38)	0
Other financing activities	0	(5)
Net cash provided from (used for) financing activities	5	(9)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(81)	(123)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	293	248
Cash, Cash Equivalents, and Restricted Cash at End of Period	212	125
Cash paid (received) during the period for —
Interest, net of amounts capitalized	13	21
Income taxes, net	0	19
Noncash transactions — Accrued property additions at end of period	27	30
SOUTHERN POWER CO
Operating Activities:
Net income (loss)	27	115
Adjustments to reconcile net income (loss) to net cash provided from (used for) operating activities —
Depreciation and amortization, total	125	122
Deferred income taxes	17	(50)
Amortization of investment tax credits	(14)	(14)
Other, net	(7)	2
Changes in certain current assets and liabilities —
-Receivables	10	48
-Prepaid income taxes	(9)	(32)
-Other current assets	3	5
-Accounts payable	(32)	(43)
-Accrued compensation	(15)	(13)
-Other current liabilities	5	9
Net cash used for operating activities	110	149
Investing Activities:
Business acquisitions, net of cash acquired	(2)	(46)
Property additions	(66)	(121)
Change in construction payables, net	(7)	25
Payments pursuant to LTSAs	(15)	(18)
Other investing activities	11	7
Net cash provided from (used for) investing activities	(79)	(153)
Financing Activities:
Increase (decrease) in notes payable, net	5	29
Redemptions and repurchases —
Distributions to noncontrolling interests	(36)	(13)
Capital contributions from noncontrolling interests	3	8
Payment of common stock dividends	(51)	(78)
Net cash provided from (used for) financing activities	(79)	(54)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(48)	(58)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	181	140
Cash, Cash Equivalents, and Restricted Cash at End of Period	133	82
Cash paid (received) during the period for —
Interest, net of amounts capitalized	28	29
Income taxes, net	1	(39)
Noncash transactions — Accrued property additions at end of period	19	57
SOUTHERN Co GAS
Operating Activities:
Net income (loss)	270	279
Adjustments to reconcile net income (loss) to net cash provided from (used for) operating activities —
Depreciation and amortization, total	118	129
Deferred income taxes	42	47
Mark-to-market adjustments	45	(59)
Goodwill impairment	0	42
Other, net	(20)	(2)
Changes in certain current assets and liabilities —
-Receivables	238	175
-Natural gas for sale	363	413
-Other current assets	59	35
-Accounts payable	(353)	(119)
-Accrued taxes	21	28
-Accrued compensation	(50)	(38)
-Other current liabilities	(50)	48
Net cash used for operating activities	683	978
Investing Activities:
Property additions	(256)	(268)
Cost of removal, net of salvage	(12)	(14)
Change in construction payables, net	1	(46)
Investment in unconsolidated subsidiaries	(10)	(29)
Other investing activities	(13)	(4)
Net cash provided from (used for) investing activities	(290)	(361)
Financing Activities:
Increase (decrease) in notes payable, net	(289)	(483)
Redemptions and repurchases —
Payment of common stock dividends	(118)	(118)
Other financing activities	5	6
Net cash provided from (used for) financing activities	(402)	(595)
Net Change in Cash, Cash Equivalents, and Restricted Cash	(9)	22
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	70	78
Cash, Cash Equivalents, and Restricted Cash at End of Period	61	100
Cash paid (received) during the period for —
Interest, net of amounts capitalized	55	52
Income taxes, net	(1)	0
Noncash transactions — Accrued property additions at end of period	$ 98	$ 89

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Interest capitalized	$ 18	$ 17
ALABAMA POWER CO
Interest capitalized	5	5
GEORGIA POWER CO
Interest capitalized	8	6
MISSISSIPPI POWER CO
Interest capitalized	0	0
SOUTHERN POWER CO
Interest capitalized	4	5
SOUTHERN Co GAS
Interest capitalized	$ 2	$ 1

XML

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 1,361	$ 1,396
Receivables —
Customer accounts receivable	1,715	1,726
Energy marketing receivables	529	801
Unbilled revenues	555	654
Under recovered fuel clause revenues	73	115
Other accounts and notes receivable	863	813
Accumulated provision for uncollectible accounts	(46)	(50)
Materials and supplies	1,477	1,465
Fossil fuel for generation	427	405
Natural gas for sale	189	524
Prepaid expenses	786	432
Assets from risk management activities, net of collateral	111	222
Other regulatory assets	482	525
Assets held for sale	55	393
Other current assets	132	162
Total current assets	8,709	9,583
Property, Plant, and Equipment:
In service	102,673	103,706
Less: Accumulated depreciation	30,834	31,038
Plant in service, net of depreciation	71,839	72,668
Other utility plant, net	1,315	0
Nuclear fuel, at amortized cost	885	875
Construction work in progress	7,598	7,254
Total property, plant, and equipment	81,637	80,797
Other Property and Investments:
Goodwill	5,284	5,315
Equity investments in unconsolidated subsidiaries	1,598	1,580
Other intangible assets, net of amortization	585	613
Nuclear decommissioning trusts, at fair value	1,875	1,721
Leveraged leases	806	798
Miscellaneous property and investments	363	269
Total other property and investments	10,511	10,296
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,881
Deferred charges related to income taxes	794	794
Unamortized loss on reacquired debt	318	323
Other regulatory assets, deferred	8,191	8,308
Assets held for sale, deferred	763	5,350
Other deferred charges and assets	1,292	1,463
Total deferred charges and other assets	13,239	16,238
Total Assets	114,096	116,914
Current Liabilities:
Securities due within one year	2,315	3,198
Notes payable	1,251	2,915
Energy marketing trade payables	532	856
Accounts payable —
Accounts payable	2,037	2,580
Customer deposits	483	522
Accrued taxes —
Accrued income taxes	340	21
Other accrued taxes	331	635
Accrued interest	412	472
Accrued compensation	473	1,030
Asset retirement obligations	417	404
Other regulatory liabilities	310	376
Liabilities held for sale	38	425
Operating lease obligations	226
Other current liabilities	754	852
Total current liabilities	9,919	14,286
Long-term Debt	40,457	40,736
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	7,937	6,558
Deferred credits related to income taxes	6,417	6,460
Accumulated deferred ITCs	2,353	2,372
Employee benefit obligations	2,084	2,147
Operating lease obligations, deferred	1,720
Asset retirement obligations, deferred	9,011	8,990
Accrued environmental remediation	261	268
Other cost of removal obligations	2,304	2,297
Other regulatory liabilities, deferred	211	169
Liabilities held for sale, deferred	39	2,836
Other deferred credits and liabilities	405	465
Total deferred credits and other liabilities	32,742	32,562
Total Liabilities	83,118	87,584
Redeemable Preferred Stock of Subsidiaries	291	291
Stockholders' Equity:
Total stockholders' equity	30,687	29,039
Total Liabilities and Stockholders' Equity	114,096	116,914
ALABAMA POWER CO
Current Assets:
Cash and cash equivalents	759	313
Receivables —
Customer accounts receivable	382	403
Unbilled revenues	126	150
Affiliated	45	94
Other accounts and notes receivable	58	51
Accumulated provision for uncollectible accounts	(10)	(10)
Materials and supplies	558	546
Fossil fuel for generation	120	141
Prepaid expenses	113	66
Other regulatory assets	125	137
Other current assets	21	18
Total current assets	2,297	1,909
Property, Plant, and Equipment:
In service	28,810	30,402
Less: Accumulated depreciation	9,447	9,988
Plant in service, net of depreciation	19,363	20,414
Other utility plant, net	1,315	0
Nuclear fuel, at amortized cost	320	324
Construction work in progress	1,023	1,113
Total property, plant, and equipment	22,021	21,851
Other Property and Investments:
Equity investments in unconsolidated subsidiaries	64	65
Nuclear decommissioning trusts, at fair value	933	847
Miscellaneous property and investments	129	127
Total other property and investments	1,126	1,039
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	160
Deferred charges related to income taxes	239	240
Deferred under recovered regulatory clause revenues	21	116
Other regulatory assets, deferred	1,350	1,386
Other deferred charges and assets	193	189
Total deferred charges and other assets	1,963	1,931
Total Assets	27,407	26,730
Current Liabilities:
Securities due within one year	1	201
Accounts payable —
Affiliated	262	364
Other	346	614
Customer deposits	97	96
Accrued taxes —
Other accrued taxes	97	44
Accrued interest	77	89
Accrued compensation	102	227
Asset retirement obligations	163	163
Operating lease obligations	47
Other current liabilities	97	161
Total current liabilities	1,242	1,959
Long-term Debt	7,924	7,923
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	2,971	2,962
Deferred credits related to income taxes	2,015	2,027
Accumulated deferred ITCs	105	106
Employee benefit obligations	302	314
Operating lease obligations, deferred	147
Asset retirement obligations, deferred	3,064	3,047
Other cost of removal obligations	489	497
Other regulatory liabilities, deferred	107	69
Other deferred credits and liabilities	30	58
Total deferred credits and other liabilities	9,230	9,080
Total Liabilities	18,396	18,962
Redeemable Preferred Stock	291	291
Stockholders' Equity:
Total stockholders' equity	8,720	7,477
Total Liabilities and Stockholders' Equity	27,407	26,730
GEORGIA POWER CO
Current Assets:
Cash and cash equivalents	9	4
Restricted cash and cash equivalents	0	108
Receivables —
Customer accounts receivable	550	591
Unbilled revenues	179	208
Under recovered fuel clause revenues	73	115
Joint owner accounts receivable	170	170
Affiliated	21	39
Other accounts and notes receivable	241	80
Accumulated provision for uncollectible accounts	(2)	(2)
Materials and supplies	504	519
Fossil fuel for generation	272	231
Prepaid expenses	193	142
Other regulatory assets	210	199
Other current assets	48	70
Total current assets	2,468	2,474
Property, Plant, and Equipment:
In service	38,015	37,675
Less: Accumulated depreciation	12,210	12,096
Plant in service, net of depreciation	25,805	25,579
Nuclear fuel, at amortized cost	565	550
Construction work in progress	5,298	4,833
Total property, plant, and equipment	31,668	30,962
Other Property and Investments:
Equity investments in unconsolidated subsidiaries	50	51
Nuclear decommissioning trusts, at fair value	942	873
Miscellaneous property and investments	73	72
Total other property and investments	1,065	996
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,519
Deferred charges related to income taxes	518	517
Other regulatory assets, deferred	4,921	4,902
Other deferred charges and assets	379	514
Total deferred charges and other assets	7,337	5,933
Total Assets	42,538	40,365
Current Liabilities:
Securities due within one year	973	617
Notes payable	275	294
Accounts payable —
Affiliated	448	575
Other	827	890
Customer deposits	278	276
Accrued taxes —
Other accrued taxes	132	377
Accrued interest	103	105
Accrued compensation	112	221
Asset retirement obligations	221	202
Other regulatory liabilities	197	169
Operating lease obligations	139
Other current liabilities	305	183
Total current liabilities	3,871	3,909
Long-term Debt	10,108	9,364
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,192	3,062
Deferred credits related to income taxes	3,079	3,080
Accumulated deferred ITCs	259	262
Employee benefit obligations	567	599
Operating lease obligations, deferred	1,404
Asset retirement obligations, deferred	5,634	5,627
Other deferred credits and liabilities	155	139
Total deferred credits and other liabilities	14,290	12,769
Total Liabilities	28,269	26,042
Stockholders' Equity:
Total stockholders' equity	14,269	14,323
Total Liabilities and Stockholders' Equity	42,538	40,365
MISSISSIPPI POWER CO
Current Assets:
Cash and cash equivalents	212	293
Receivables —
Customer accounts receivable	29	34
Unbilled revenues	37	41
Affiliated	16	21
Other accounts and notes receivable	36	31
Materials and supplies	52	53
Fossil fuel for generation	23	20
Other regulatory assets	102	116
Other current assets	6	19
Total current assets	513	628
Property, Plant, and Equipment:
In service	4,821	4,900
Less: Accumulated depreciation	1,467	1,429
Plant in service, net of depreciation	3,354	3,471
Construction work in progress	110	103
Total property, plant, and equipment	3,464	3,574
Other Property and Investments:
Total other property and investments	123	24
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	8
Deferred charges related to income taxes	33	33
Other regulatory assets, deferred	487	474
Accumulated deferred income taxes	148	150
Other deferred charges and assets	17	3
Total deferred charges and other assets	685	660
Total Assets	4,785	4,886
Current Liabilities:
Securities due within one year	339	40
Accounts payable —
Affiliated	52	60
Other	50	90
Accrued taxes —
Other accrued taxes	33	95
Accrued interest	20	15
Accrued compensation	16	38
Accrued plant closure costs	26	29
Asset retirement obligations	28	34
Operating lease obligations	3
Other current liabilities	55	40
Over recovered regulatory clause liabilities	14	14
Total current liabilities	633	455
Long-term Debt	1,280	1,539
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	373	378
Deferred credits related to income taxes	367	382
Employee benefit obligations	111	115
Operating lease obligations, deferred	5
Asset retirement obligations, deferred	127	126
Other cost of removal obligations	186	185
Other regulatory liabilities, deferred	80	81
Other deferred credits and liabilities	18	16
Total deferred credits and other liabilities	1,262	1,283
Total Liabilities	3,175	3,277
Stockholders' Equity:
Total stockholders' equity	1,610	1,609
Total Liabilities and Stockholders' Equity	4,785	4,886
SOUTHERN POWER CO
Current Assets:
Cash and cash equivalents	133	181
Receivables —
Customer accounts receivable	120	111
Affiliated	33	55
Other accounts and notes receivable	116	116
Materials and supplies	218	220
Prepaid income taxes	1,190	25
Other current assets	37	37
Total current assets	1,847	745
Property, Plant, and Equipment:
In service	13,284	13,271
Less: Accumulated depreciation	2,288	2,171
Plant in service, net of depreciation	10,996	11,100
Construction work in progress	409	430
Total property, plant, and equipment	11,405	11,530
Other Property and Investments:
Intangible assets, net of amortization	340	345
Miscellaneous property and investments	2	0
Total other property and investments	342	345
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	372
Prepaid LTSAs	102	98
Accumulated deferred income taxes	17	1,186
Income taxes receivable, non-current	33	30
Assets held for sale, deferred	644	576
Other deferred charges and assets	342	373
Total deferred charges and other assets	1,510	2,263
Total Assets	15,104	14,883
Current Liabilities:
Securities due within one year	599	599
Notes payable	105	100
Accounts payable —
Affiliated	69	92
Other	66	77
Accrued taxes —
Accrued income taxes	11	6
Accrued interest	44	36
Liabilities held for sale	9	15
Operating lease obligations	22
Other current liabilities	111	106
Total current liabilities	1,014	1,031
Long-term Debt	4,396	4,418
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	107	105
Accumulated deferred ITCs	1,817	1,832
Operating lease obligations, deferred	371
Other deferred credits and liabilities	181	213
Total deferred credits and other liabilities	2,476	2,150
Total Liabilities	7,886	7,599
Stockholders' Equity:
Total stockholders' equity	7,218	7,284
Total Liabilities and Stockholders' Equity	15,104	14,883
SOUTHERN Co GAS
Current Assets:
Cash and cash equivalents	57	64
Receivables —
Customer accounts receivable	472	370
Energy marketing receivables	529	801
Unbilled revenues	179	213
Affiliated	9	11
Other accounts and notes receivable	108	142
Accumulated provision for uncollectible accounts	(27)	(30)
Natural gas for sale	189	524
Prepaid expenses	99	118
Assets from risk management activities, net of collateral	108	219
Other regulatory assets	46	73
Other current assets	42	50
Total current assets	1,811	2,555
Property, Plant, and Equipment:
In service	15,417	15,177
Less: Accumulated depreciation	4,466	4,400
Plant in service, net of depreciation	10,951	10,777
Construction work in progress	577	580
Total property, plant, and equipment	11,528	11,357
Other Property and Investments:
Goodwill	5,015	5,015
Equity investments in unconsolidated subsidiaries	1,557	1,538
Other intangible assets, net of amortization	93	101
Miscellaneous property and investments	20	20
Total other property and investments	6,685	6,674
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	86
Other regulatory assets, deferred	657	669
Other deferred charges and assets	185	193
Total deferred charges and other assets	928	862
Total Assets	20,952	21,448
Current Liabilities:
Securities due within one year	354	357
Notes payable	361	650
Energy marketing trade payables	532	856
Accounts payable —
Affiliated	31	45
Other	391	402
Customer deposits	91	133
Accrued taxes —
Accrued income taxes	89	66
Other accrued taxes	72	75
Accrued interest	64	55
Accrued compensation	49	100
Liabilities from risk management activities, net of collateral	26	76
Other regulatory liabilities	86	79
Operating lease obligations	13
Other current liabilities	160	130
Total current liabilities	2,306	3,024
Long-term Debt	5,574	5,583
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,064	1,016
Deferred credits related to income taxes	926	940
Employee benefit obligations	351	357
Operating lease obligations, deferred	71
Accrued environmental remediation	261	268
Other cost of removal obligations	1,598	1,585
Other deferred credits and liabilities	63	105
Total deferred credits and other liabilities	4,334	4,271
Total Liabilities	12,214	12,878
Stockholders' Equity:
Total stockholders' equity	8,738	8,570
Total Liabilities and Stockholders' Equity	$ 20,952	$ 21,448

XML

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Other intangible assets, amortization	$ 251	$ 235
SOUTHERN POWER CO
Other intangible assets, amortization	67	61
SOUTHERN Co GAS
Other intangible assets, amortization	$ 153	$ 145

XML

Consolidated Statements of Stockholders' Equity (Unaudited) - USD ($) shares in Thousands, $ in Millions	Total	Common Stock	Treasury	Paid-In Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests	ALABAMA POWER CO	ALABAMA POWER CO Common Stock	ALABAMA POWER CO Paid-In Capital	ALABAMA POWER CO Retained Earnings	ALABAMA POWER CO Accumulated Other Comprehensive Income (Loss)	GEORGIA POWER CO	GEORGIA POWER CO Common Stock	GEORGIA POWER CO Paid-In Capital	GEORGIA POWER CO Retained Earnings	GEORGIA POWER CO Accumulated Other Comprehensive Income (Loss)	MISSISSIPPI POWER CO	MISSISSIPPI POWER CO Common Stock	MISSISSIPPI POWER CO Paid-In Capital	MISSISSIPPI POWER CO Retained Earnings	MISSISSIPPI POWER CO Accumulated Other Comprehensive Income (Loss)	SOUTHERN POWER CO	SOUTHERN POWER CO Paid-In Capital	SOUTHERN POWER CO Retained Earnings	SOUTHERN POWER CO Accumulated Other Comprehensive Income (Loss)	SOUTHERN POWER CO Total Common Stockholders' Equity	SOUTHERN POWER CO Noncontrolling Interests	SOUTHERN Co GAS	SOUTHERN Co GAS Paid-In Capital	SOUTHERN Co GAS Retained Earnings	SOUTHERN Co GAS Accumulated Other Comprehensive Income (Loss)
Beginning balance (in shares) at Dec. 31, 2017		1,008,532	929						31,000					9,000					1,000
Beginning balance at Dec. 31, 2017	$ 25,528	$ 5,037	$ (36)	$ 10,470	$ 8,885	$ (189)	$ 1,361	$ 6,829	$ 1,222	$ 2,986	$ 2,647	$ (26)	$ 11,931	$ 398	$ 7,328	$ 4,215	$ (10)	$ 1,358	$ 38	$ 4,529	$ (3,205)	$ (4)	$ 6,498	$ 3,662	$ 1,478	$ (2)	$ 5,138	$ 1,360	$ 9,022	$ 9,214	$ (212)	$ 20
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	938				938			225			225		352			352		(7)			(7)		121		121		121		279		279
Other comprehensive income (loss)	30					30		1				1	1				1	(1)				(1)	24			24	24		2			2
Stock issued (in shares)		4,055
Stock issued	113	$ 16		97
Stock-based compensation	36			36
Cash dividends on common stock	(586)				(586)			(202)			(202)		(339)			(339)							(78)		(78)		(78)		(118)		(118)
Contributions from noncontrolling interests	9						9																9					9
Distributions to noncontrolling interests	(13)						(13)																(13)					(13)
Net income (loss) attributable to noncontrolling interests	(6)						(6)																(6)					(6)
Other (in shares)			(33)
Other	(24)	$ 1	$ (2)		20	(41)	(2)	(6)				(6)	(1)		1		(2)	(1)			(1)		2		(2)	5	3	(1)	0		(4)	4
Return of capital																		0
Capital contributions from parent company								488		488			1,476		1,476			2		2			1	1			1		14	14
Ending balance (in shares) at Mar. 31, 2018		1,012,587	962						31,000					9,000					1,000
Ending balance at Mar. 31, 2018	26,025	$ 5,054	$ (38)	10,603	9,257	(200)	1,349	7,335	$ 1,222	3,474	2,670	(31)	13,420	$ 398	8,805	4,228	(11)	1,351	$ 38	4,531	(3,213)	(5)	6,558	3,663	1,519	27	5,209	1,349	9,199	9,228	(55)	26
Beginning balance (in shares) at Dec. 31, 2018		1,034,741	953						31,000					9,000					1,000
Beginning balance at Dec. 31, 2018	29,039	$ 5,164	$ (38)	11,094	8,706	(203)	4,316	7,477	$ 1,222	3,508	2,775	(28)	14,323	$ 398	10,322	3,612	(9)	1,609	$ 38	4,546	(2,971)	(4)	7,284	1,600	1,352	16	2,968	4,316	8,570	8,856	(312)	26
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	2,084				2,084			217			217		311			311		37			37		56		56		56		270		270
Other comprehensive income (loss)								1				1	1				1						(4)			(4)	(4)		(1)			(1)
Stock issued (in shares)		6,547
Stock issued	224	$ 28		196
Stock-based compensation	24			24
Cash dividends on common stock	(622)				(622)			(211)			(211)		(394)			(394)							(51)		(51)		(51)		(118)		(118)
Contributions from noncontrolling interests	3						3																3					3
Distributions to noncontrolling interests	(41)						(41)																(41)					(41)
Net income (loss) attributable to noncontrolling interests	(29)						(29)																(29)					(29)
Other (in shares)			(39)
Other	5		$ (2)	7	(1)		1						(1)		(1)		0						(1)	(1)	(1)		(2)	1
Return of capital																		(38)		(38)
Capital contributions from parent company								1,236		1,236			29		29			2		2			1	1			1		17	17
Ending balance (in shares) at Mar. 31, 2019		1,041,288	992						31,000					9,000					1,000
Ending balance at Mar. 31, 2019	$ 30,687	$ 5,192	$ (40)	$ 11,321	$ 10,167	$ (203)	$ 4,250	$ 8,720	$ 1,222	$ 4,744	$ 2,781	$ (27)	$ 14,269	$ 398	$ 10,350	$ 3,529	$ (8)	$ 1,610	$ 38	$ 4,510	$ (2,934)	$ (4)	$ 7,218	$ 1,600	$ 1,356	$ 12	$ 2,968	$ 4,250	$ 8,738	$ 8,873	$ (160)	$ 25

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Consolidated Statements of Stockholders' Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement of Stockholders' Equity [Abstract]
Cash dividends (in dollars per share)	$ 0.60	$ 0.58

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Introduction

3 Months Ended

Mar. 31, 2019

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 as of December 31, 2018 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, 2019 and 2018. 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, 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 results of operations, financial position, or cash flows of any registrant.

Recently Adopted Accounting Standards

In 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (ASU 2016-02). ASU 2016-02 requires lessees to recognize on the balance sheet a lease liability and a right-of-use asset for all leases. ASU 2016-02 also changes the recognition, measurement, and presentation of expense associated with leases and provides clarification regarding the identification of certain components of contracts that would represent a lease. The accounting required by lessors is relatively unchanged and there is no change to the accounting for existing leveraged leases. The registrants adopted the new standard effective January 1, 2019. See Note (L) for additional information and related disclosures.

Goodwill and Other Intangible Assets

Goodwill at March 31, 2019 and December 31, 2018 was as follows:

	At March 31, 2019		At December 31, 2018
	(in millions)
Southern Company	$	5,284	$	5,315
Southern Company Gas:
Gas distribution operations	$	4,034	$	4,034
Gas marketing services	981		981
Southern Company Gas total	$	5,015	$	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, 2019							At December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net
	(in millions)							(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	211	$	(100	)	$	111	$	223	$	(94	)	$	129
Trade names	70		(22		)	48		70		(21		)	49
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
PPA fair value adjustments	405		(67		)	338		405		(61		)	344
Other	11		(6		)	5		11		(5		)	6
Total other intangible assets subject to amortization	$	761	$	(251	)	$	510	$	773	$	(235	)	$	538
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—			75		75		—			75
Total other intangible assets	$	836	$	(251	)	$	585	$	848	$	(235	)	$	613
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	405	$	(67	)	$	338	$	405	$	(61	)	$	344
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(89	)	$	67	$	156	$	(84	)	$	72
Trade names	26		(8		)	18		26		(7		)	19
Wholesale gas services
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
Total other intangible assets subject to amortization	$	246	$	(153	)	$	93	$	246	$	(145	)	$	101

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2019
	(in millions)
Southern Company	$	17
Southern Power(a)	$	6
Southern Company Gas
Gas marketing services(b)	$	6
Wholesale gas services(a)	2
Southern Company Gas total	$	8

(a) Recorded as a reduction to operating revenues.

(b) Included in depreciation and amortization.

Restricted Cash

At December 31, 2018, Georgia Power had restricted cash related to the redemption of pollution control revenue bonds, which were redeemed in January 2019. See Note (F) under "Financing Activities" for additional information. At both March 31, 2019 and December 31, 2018, Southern Company Gas had restricted cash held as collateral for worker's compensation, life insurance, and long-term disability insurance.

The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amounts shown in the condensed statements of cash flows for the registrants that had restricted cash at March 31, 2019 and/or December 31, 2018:

	Southern Company			Southern Company Gas
	(in millions)
At March 31, 2019
Cash and cash equivalents	$	1,361		$	57
Restricted cash:
Other accounts and notes receivable	4			4
Total cash, cash equivalents, and restricted cash	$	1,364	(*)	$	61

(*) Total does not add due to rounding.

	Southern Company		Georgia Power		Southern Company Gas
	(in millions)
At December 31, 2018
Cash and cash equivalents	$	1,396	$	4	$	64
Cash and cash equivalents held for sale	9		—		—
Restricted cash:
Restricted cash	—		108		—
Other accounts and notes receivable	114		—		6
Total cash, cash equivalents, and restricted cash	$	1,519	$	112	$	70

Natural Gas for Sale

Southern Company Gas, with the exception of Nicor Gas, carries natural gas inventory 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. Southern Company Gas had no material adjustment in any period presented.

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. Nicor Gas' inventory decrement at March 31, 2019 is expected to be restored prior to year end.

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Regulatory Matters

3 Months Ended

Mar. 31, 2019

Commitments and Contingencies Disclosure [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 of Alabama Power's, Georgia Power's, and Mississippi Power's regulatory clauses at March 31, 2019 and December 31, 2018 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2019		December 31, 2018
		(in millions)
Alabama Power
Rate CNP Compliance	Deferred under recovered regulatory clause revenues	$	—	$	42
	Customer accounts receivable	25		—
Rate CNP PPA	Deferred under recovered regulatory clause revenues	21		25
Retail Energy Cost Recovery(*)	Deferred under recovered regulatory clause revenues	—		109
	Other regulatory liabilities, deferred	2		—
Natural Disaster Reserve	Other regulatory liabilities, deferred	22		20
Georgia Power
Fuel Cost Recovery	Receivables – under recovered fuel clause revenues	$	73	$	115
Mississippi Power
Fuel Cost Recovery	Over recovered retail fuel costs	$	10	$	8

(*) In accordance with an accounting order issued on February 5, 2019 by the Alabama PSC, Alabama Power utilized $75 million of the 2018 Rate RSE refund liability to reduce the Rate ECR under recovered balance. See Note 2 to the financial statements under "Alabama Power – Rate ECR" in Item 8 of the Form 10-K for additional information.

Alabama Power

Environmental Accounting Order

In connection with management's decision to retire Plant Gorgas, in February 2019, Alabama Power reclassified approximately $1.3 billion for Plant Gorgas Unit 10 from plant in service, net of depreciation to other utility plant, net and continued to depreciate the asset according to the original depreciation rates. On April 15, 2019, Alabama Power retired Plant Gorgas Units 8, 9, and 10 and reclassified approximately $740 million of the remaining net investment costs of the units to a regulatory asset to be recovered over the units' remaining useful lives as established prior to the decision to retire. Additionally, approximately $700 million of net capitalized asset retirement costs will be reclassified to a regulatory asset and recovered in accordance with accounting guidance provided by the Alabama PSC. See Note 2 to the financial statements under "Alabama Power – Environmental Accounting Order" and Note 6 in Item 8 of the Form 10-K for additional information.

Georgia Power

Nuclear Construction

See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" in Item 8 of the Form 10-K for additional information regarding Georgia Power's construction of Plant Vogtle Units 3 and 4, the joint ownership agreements and related funding agreement, VCM reports, and the NCCR tariff.

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4. Georgia Power holds a 45.7% ownership interest in Plant Vogtle Units 3 and 4. 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 March 2017, the EPC Contractor filed for bankruptcy protection under Chapter 11 of the U.S. Bankruptcy Code. In connection with the EPC Contractor's bankruptcy filing, 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, a cost reimbursable plus fee arrangement, whereby Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, which is 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.

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4 by the expected in-service dates of November 2021 and November 2022, respectively, is as follows:

	(in billions)
Base project capital cost forecast(a)(b)	$	8.0
Construction contingency estimate	0.4
Total project capital cost forecast(a)(b)	8.4
Net investment as of March 31, 2019(b)	(4.9		)
Remaining estimate to complete(a)	$	3.5

(a) Excludes financing costs expected to be capitalized through AFUDC of approximately $325 million.

(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 $3.1 billion, of which $1.9 billion had been incurred through March 31, 2019.

In April 2019, Southern Nuclear completed a cost and schedule validation process to verify and update quantities of commodities remaining to install, labor hours to install remaining quantities and related productivity, testing and system turnover requirements, and forecasted staffing needs and related costs. This process confirmed the total estimated project capital cost forecast for Plant Vogtle Units 3 and 4. The expected in-service dates of November 2021 for Unit 3 and November 2022 for Unit 4, as previously approved by the Georgia PSC, remain unchanged.

As construction continues, challenges with management of contractors, subcontractors, and vendors; supervision of craft labor and related craft labor productivity, ability to attract and retain craft labor, and/or related cost escalation; procurement, fabrication, delivery, assembly, and/or installation and the initial testing and start-up, including any required engineering changes, of plant systems, structures, or components (some of which are based on new technology that only recently began initial operation in the global nuclear industry at this scale), any of which may require additional labor and/or materials; or other issues could arise and change the projected schedule and estimated cost. Monthly construction production targets established as part of a strategy to maintain and build margin to the approved in-service dates will continue to increase significantly throughout 2019. To meet these increasing monthly targets, existing craft construction productivity must improve and additional craft laborers must be retained and deployed.

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 assure 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. As a result of such compliance processes, certain license amendment requests have been filed and approved or are pending before the NRC. Various design and other licensing-based compliance matters, including the timely resolution of ITAAC and the related approvals by the NRC, may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues 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 regulatory-approved project schedule is currently estimated to result in additional base capital costs of approximately $50 million per month, based on Georgia Power's ownership interests, and AFUDC of approximately $12 million per month. While Georgia Power is not precluded from seeking recovery of any future capital cost forecast increase, 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.

As a result of the increase in the total project capital cost forecast and Georgia Power's decision not to seek rate recovery of the increase in the base capital costs in conjunction with the nineteenth VCM report, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 were required to vote to continue construction. In September 2018, the Vogtle Owners unanimously voted to continue construction of Plant Vogtle Units 3 and 4.

Amendments to the Vogtle Joint Ownership Agreements

In connection with the vote to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG'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 and MEAG SPVJ to provide funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. On January 14, 2019, Georgia Power, MEAG, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. On February 18, 2019, Georgia Power, the other Vogtle Owners, and MEAG'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.

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, 2019, Georgia Power had recovered approximately $1.9 billion of financing costs. Financing costs related to capital costs above $4.418 billion will be recovered through AFUDC; however, Georgia Power will not record 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 2018, the Georgia PSC approved Georgia Power's request to increase the NCCR tariff by $88 million annually, effective January 1, 2019.

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 amounts 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 prudence decisions on cost recovery will be made at a later date, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 ARP) 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 upon Unit 3 reaching commercial operation, retail base rates would be adjusted to include carrying costs on those capital costs deemed prudent in the Vogtle Cost Settlement Agreement. 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 $100 million in 2018 and are estimated to have negative earnings impacts of approximately $75 million in 2019 and an aggregate of approximately $635 million from 2020 to 2022.

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 February 2018, Georgia Interfaith Power & Light, Inc. (GIPL) and Partnership for Southern Equity, Inc. (PSE) filed a petition appealing the Georgia PSC's January 11, 2018 order with the Fulton County Superior Court. In March 2018, Georgia Watch filed a similar appeal to the Fulton County Superior Court for judicial review of the Georgia PSC's decision and denial of Georgia Watch's motion for reconsideration. In December 2018, the Fulton County Superior Court granted Georgia Power's motion to dismiss the two appeals. On January 9, 2019, GIPL, PSE, and Georgia Watch filed an appeal of this decision with the Georgia Court of Appeals. Georgia Power believes the appeal has no merit; however, an adverse outcome in the appeal combined with subsequent adverse action by the Georgia PSC could have a material impact on Southern Company's and Georgia Power's results of operations, financial condition, and liquidity.

In August 2018, Georgia Power filed its nineteenth VCM report with the Georgia PSC, which requested approval of $578 million of construction capital costs incurred from January 1, 2018 through June 30, 2018. On February 19, 2019, the Georgia PSC approved the nineteenth VCM, but deferred approval of $51.6 million of expenditures related to Georgia Power's portion of an administrative claim filed in the Westinghouse bankruptcy proceedings. Through the nineteenth VCM, the Georgia PSC has approved total construction capital costs incurred through June 30, 2018 of $5.4 billion (before $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related Customer Refunds). In addition, the staff of the Georgia PSC requested, and Georgia Power agreed, to report the results of the cost and schedule validation process to the Georgia PSC (which is expected to occur by May 1, 2019) and to file its twentieth VCM report concurrently with the twenty-first VCM report by August 31, 2019.

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

DOE Financing

At March 31, 2019, Georgia Power had borrowed $3.46 billion related to Plant Vogtle Units 3 and 4 costs as provided through the Amended and Restated Loan Guarantee Agreement and related multi-advance credit facilities among Georgia Power, the DOE, and the FFB, which provide for borrowings of up to approximately $5.130 billion, subject to the satisfaction of certain conditions. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K and Note (F) under "DOE Loan Guarantee Borrowings" for additional information, including applicable covenants, events of default, mandatory prepayment events, and conditions to borrowing.

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

Mississippi Power

Municipal and Rural Association Tariff

On March 28, 2019, Mississippi Power filed a request with the FERC for a decrease in wholesale base revenues under the MRA tariff as agreed upon in a settlement agreement reached with its wholesale customers resolving all matters related to the Kemper County energy facility similar to the retail rate settlement agreement approved by the Mississippi PSC in February 2018 and reflecting the impacts of the Tax Reform Legislation. The MRA settlement agreement provides that base rates will decrease $3.7 million annually, effective January 1, 2019. Mississippi Power expects the matter to be resolved in the second quarter 2019. The ultimate outcome of this matter cannot be determined at this time.

Kemper County Energy Facility

As the mining permit holder, Liberty Fuels Company, LLC has a legal obligation to perform mine reclamation, and Mississippi Power has a contractual obligation to fund all reclamation activities. As a result of the abandonment of the Kemper IGCC, final mine reclamation began in 2018 and is expected to be substantially completed in 2020, with monitoring expected to continue through 2027. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

During the first quarter 2019, Mississippi Power recorded pre-tax charges to income of $2 million ($1 million after tax), primarily resulting from the abandonment and related closure activities and ongoing period costs, net of sales proceeds, for the mine and gasifier-related assets at the Kemper County energy facility. Additional closure costs for the mine and gasifier-related assets, currently estimated at up to $10 million pre-tax (excluding salvage, net of dismantlement costs), may be incurred through the first half of 2020. In addition, period costs, including, but not limited to, costs for compliance and safety, ARO accretion, and property taxes for the mine and gasifier-related assets, are estimated at $11 million for the remainder of 2019 and $2 million to $6 million annually in 2020 through 2023.

In addition, Mississippi Power constructed the CO₂ pipeline for the planned transport of captured CO₂ for use in enhanced oil recovery and is currently evaluating its options regarding the final disposition of the CO₂ pipeline, including removal of the pipeline. This evaluation is expected to be complete later in 2019. If Mississippi Power ultimately decides to remove the CO₂ pipeline, the cost of removal would have a material impact on Mississippi Power's financial statements and could have a material impact on Southern Company's financial statements.

In December 2018, Mississippi Power filed with the DOE its request for property closeout certification under the contract related to the$387 million of grants received. Mississippi Power and the DOE are currently in discussions regarding the requested closeout and property disposition, which may require payment to the DOE for a portion of certain property that is to be retained by Mississippi Power. In connection with the DOE closeout discussions, on April 29, 2019, the Civil Division of the Department of Justice informed Southern Company and Mississippi Power of an investigation related to the Kemper County energy facility. The ultimate outcome of these matters cannot be determined at this time; however, they could have a material impact on Mississippi Power's and Southern Company's financial statements.

Southern Company Gas

Rate Proceedings

Nicor Gas

In November 2018, Nicor Gas filed a general base rate case with the Illinois Commission requesting a$230 millionincrease in annual base rate revenues. The requested increase is based on a projected test year for the12-month period ending September 30, 2020, a ROE of10.6%, and an increase in the equity ratio from52% to 54% to address the negative cash flow and credit metric impacts of the Tax Reform Legislation.

On April 16, 2019, Nicor Gas entered into a stipulation agreement to resolve all related issues with the Staff of the Illinois Commission, including a ROE of9.86% and an equity ratio of 54%. Also on April 16, 2019, Nicor Gas filed its rebuttal testimony with the Illinois Commission incorporating the stipulation agreement and addressing the remaining items outstanding with the other two intervenors. As a result of the stipulation agreement and rebuttal testimony, the revised requested annual revenue increase is $180 million.

The Illinois Commission is expected to rule on the requested increase within the statutory time limit of 11 months from the filing of the rate case, after which rate adjustments will be effective. The ultimate outcome of this matter cannot be determined at this time.

Virginia Natural Gas

In December 2018, the Virginia Commission approved Virginia Natural Gas' annual information form filing, which reduced annual base rates by $14 millioneffective January 1, 2019 due to lower tax expense as a result of the Tax Reform Legislation. This approval also required Virginia Natural Gas to issue customer refunds, via bill credits, for $14 millionrelated to 2018 tax benefits deferred as a regulatory liability, current, on the balance sheet at December 31, 2018. These customer refunds were completed in the first quarter 2019.

Regulatory Infrastructure Programs

Southern Company Gas is engaged in various infrastructure programs that update or expand its gas distribution systems to improve reliability and help ensure the safety of its utility infrastructure, and recovers in rates its investment and a return associated with these infrastructure programs. In addition to capital expenditures recovered through base rates by each of the natural gas distribution utilities, Nicor Gas and Virginia Natural Gas have separate rate riders that provide for timely recovery of capital expenditures for specific infrastructure replacement programs.

Virginia Natural Gas

On April 8, 2019, Virginia Natural Gas filed an application with the Virginia Commission to amend and extend its Steps to Advance Virginia's Energy program. The proposal would allow Virginia Natural Gas to continue replacing aging pipeline infrastructure and increase its authorized investment under the currently-approved plan. Virginia Natural Gas seeks to amend its currently-approved plan by increasing the authorized investment in 2019 from$35 million to $40 millionand to extend the plan for an additionalfive years until 2024, with proposed annual investments of $50 million in 2020,$60 millionin 2021, and$70 millionin each year from 2022 through 2024, for a maximum total investment over thesix-year term (2019 through 2024) of$370 million. The proposed investment schedule would also allow for variances of up to$6 million in 2019,$8 millionin 2020,$9 millionin 2021, and$10 millionin each year from 2022 through 2024, with a total potential net variance of up to $10 million allowed for the program. The Virginia Commission is expected to rule on the request in the third quarter 2019. The ultimate outcome of this matter cannot be determined at this time.

Affiliate Asset Management Agreements

On March 15, 2019, the Virginia Commission approved an extension of Virginia Natural Gas' asset management agreement with Sequent to March 31, 2021.

FERC Matters

See Note 2 to the financial statements under "FERC Matters – Open Access Transmission Tariff" in Item 8 of the Form 10-K for additional information.

On March 25, 2019, the Alabama Municipal Electric Authority and Cooperative Energy and SCS and the traditional electric operating companiesfiled a formal settlement agreement with the FERC agreeing to a rate reduction based on a 10.6% ROE, with a retroactive effective date of May 10, 2018, and a five-year moratorium on these parties seeking changes to the OATT formula rate. The ultimate outcome of this matter cannot be determined at this time; however, if approved by the FERC as filed, the OATT settlement would not have a material impact on the financial statements of any of the traditional electric operating companies or Southern Company.

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Contingencies

3 Months Ended

Mar. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

CONTINGENCIES

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

Each registrant is subject to certain claims and legal actions arising in the ordinary course of business. In addition, the business activities of Southern Company's subsidiaries are subject to extensive governmental regulation related to public health and the environment, such as laws and regulations governing air, water, land, and protection of natural resources. Litigation over environmental issues and claims of various types, including property damage, personal injury, common law nuisance, and citizen enforcement of environmental laws and regulations, has occurred throughout the U.S. This litigation has included claims for damages alleged to have been caused by CO₂ and other emissions, CCR, and alleged exposure to hazardous materials, and/or requests for injunctive relief in connection with such matters.

The ultimate outcome of such pending or potential litigation against each registrant and any subsidiaries cannot be predicted 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.

Southern Company

In January 2017, a putative securities class action complaint was filed against Southern Company, certain of its officers, and certain former Mississippi Power officers in the U.S. District Court for the Northern District of Georgia by Monroe County Employees' Retirement System on behalf of all persons who purchased shares of Southern Company's common stock between April 25, 2012 and October 29, 2013. The complaint alleges that Southern Company, certain of its officers, and certain former Mississippi Power officers made materially false and misleading statements regarding the Kemper County energy facility in violation of certain provisions under the Securities Exchange Act of 1934, as amended. The complaint seeks, among other things, compensatory damages and litigation costs and attorneys' fees. In 2017, the plaintiffs filed an amended complaint that provided additional detail about their claims, increased the purported class period by one day, and added certain other former Mississippi Power officers as defendants. Also in 2017, the defendants filed a motion to dismiss the plaintiffs' amended complaint with prejudice, to which the plaintiffs filed an opposition. In March 2018, the court issued an order granting, in part, the defendants' motion to dismiss. The court dismissed certain claims against certain officers of Southern Company and Mississippi Power and dismissed the allegations related to a number of the statements that plaintiffs challenged as being false or misleading. In April 2018, the defendants filed a motion for reconsideration of the court's order, seeking dismissal of the remaining claims in the lawsuit. In August 2018, the court denied the motion for reconsideration and denied a motion to certify the issue for interlocutory appeal.

In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of Georgia. The complaints allege that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints allege that the defendants were unjustly enriched and caused the waste of corporate assets and also allege that the individual defendants violated their fiduciary duties. Each plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. Each plaintiff also seeks certain changes to Southern Company's corporate governance and internal processes. In April 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action.

In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that names as defendants Southern Company, certain of its directors, certain of its officers, and certain former Mississippi Power officers. The complaint alleges that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleges that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. The plaintiff seeks to recover, on behalf of Southern Company, unspecified actual damages and disgorgement of profits and, on its behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiff also seeks certain unspecified changes to Southern Company's corporate governance and internal processes. In May 2018, the court entered an order staying this lawsuit until 30 days after the resolution of any dispositive motions or any settlement, whichever is earlier, in the putative securities class action.

Southern Company believes these legal challenges have no merit; however, an adverse outcome in any of these proceedings could have an impact on Southern Company's results of operations, financial condition, and liquidity. The ultimate outcome of these matters cannot be determined at this time.

Georgia Power

In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state tort law claims. In 2016, the Georgia Court of Appeals reversed the trial court's previous dismissal of the case and remanded the case to the trial court. Georgia Power filed a petition for writ of certiorari with the Georgia Supreme Court, which was granted in 2017. In June 2018, the Georgia Supreme Court affirmed the judgment of the Georgia Court of Appeals and remanded the case to the trial court for further proceedings. Following a motion by Georgia Power, on February 13, 2019, the Superior Court of Fulton County ordered the parties to submit petitions to the Georgia PSC for a declaratory ruling to address certain terms the court previously held were ambiguous as used in the Georgia PSC's orders. The order entered by the Superior Court of Fulton County also conditionally certified the proposed class. In March 2019, Georgia Power and the plaintiffs filed petitions with the Georgia PSC seeking confirmation of the proper application of the municipal franchise fee schedule pursuant to the Georgia PSC's orders. Georgia Power and the plaintiffs also have filed notices of appeal with the Georgia Court of Appeals regarding the Superior Court of Fulton County's February 2019 order. Georgia Power believes the plaintiffs' claims have no merit. The amount of any possible losses cannot be calculated at this time because, among other factors, it is unknown whether conditional class certification will be upheld and the ultimate composition of any class and whether any losses would be subject to recovery from any municipalities. The ultimate outcome of this matter cannot be determined at this time.

Mississippi Power

In May 2018, Southern Company and Mississippi Power received a notice of dispute and arbitration demand filed by Martin Product Sales, LLC (Martin) based on two agreements, both related to Kemper IGCC byproducts for which Mississippi Power provided termination notices in 2017. Martin alleges breach of contract, breach of good faith and fair dealing, fraud and misrepresentation, and civil conspiracy and makes a claim for damages in the amount of approximately $143 million, as well as additional unspecified damages, attorney's fees, costs, and interest. In the first quarter 2019, Mississippi Power and Southern Company filed motions to dismiss. Southern Company and Mississippi Power believe this legal challenge has no merit; however, an adverse outcome in this proceeding could have a material impact on Southern Company's and Mississippi Power's results of operations, financial condition, and liquidity. The ultimate outcome of this matter cannot be determined at this time.

In November 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three current members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi. 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. They also allege that Mississippi Power underpaid customers 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. In response to Mississippi Power and the Mississippi PSC each filing a motion to dismiss, the plaintiffs filed an amended complaint on March 14, 2019. The amended complaint included four additional plaintiffs and additional claims for gross negligence, reckless conduct, and intentional wrongdoing. Mississippi Power and the Mississippi PSC have each filed a motion to dismiss the amended complaint. Mississippi Power believes this legal challenge has no merit; however, an adverse outcome in this proceeding could have a material impact on Mississippi Power's results of operations, financial condition, and liquidity. The ultimate outcome of this matter cannot be determined at this time.

Southern Power

Southern Power indirectly owns a 51% membership interest in RE Roserock LLC (Roserock), the owner of the Roserock facility in Pecos County, Texas. Prior to the facility being placed in service in 2016, certain solar panels were damaged during installation by the construction contractor, McCarthy Building Companies, Inc. (McCarthy), and certain solar panels were damaged by a hail event that also occurred during construction. In connection therewith, Southern Power withheld payment of approximately $26 million to the construction contractor, which placed a lien on the Roserock facility for the same amount. In 2017, Roserock filed a lawsuit in the state district court in Pecos County, Texas against XL Insurance America, Inc. and North American Elite Insurance Company seeking recovery from an insurance policy for damages resulting from the hail event and McCarthy's installation practices. In June 2018, the court granted Roserock's motion for partial summary judgment, finding that the insurers were in breach of contract and in violation of the Texas Insurance Code for failing to pay any monies owed for the hail claim. Separate lawsuits were filed between Roserock and McCarthy, as well as other parties, and that litigation was consolidated in the U.S. District Court for the Western District of Texas. On April 18, 2019, Roserock and the parties to the state and federal lawsuits executed a settlement agreement and mutual release that resolves both lawsuits. Under the agreement, the lawsuits will be dismissed and McCarthy will release its lien following payments of all amounts (which are expected to occur in May 2019). Roserock will pay $26 million to McCarthy that was withheld and included in the original construction costs and will receive funds that will cover all related legal costs and the replacement costs of certain solar panels. In addition, during the first quarter 2019, Roserock received a partial payment of approximately $5 million in insurance proceeds toward the hail event. Any additional funds received in excess of the initial replacement costs are expected to be recognized as a gain when received by Roserock in the second quarter 2019, but are not expected to have a material impact on Southern Power's net income.

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 compliance 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 $18 million and $23 million as of March 31, 2019 and December 31, 2018, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected.

Southern Company Gas' environmental remediation liability was $289 million and $294 million as of March 31, 2019 and December 31, 2018, respectively, based on the estimated cost of environmental investigation and remediation associated with known current and former manufactured gas plant operating sites. These environmental remediation expenditures are recoverable from customers through rate mechanisms approved by the applicable state regulatory agencies of the natural gas distribution utilities, with the exception of one site representing $2 million of the total accrued remediation costs.

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 Southern Company, Georgia Power, or Southern Company Gas.

Other Matters

Mississippi Power

In conjunction with Southern Company's sale of Gulf Power, Mississippi Power and Gulf Power have committed to seek a restructuring of their 50% undivided ownership interests in Plant Daniel such that each of them would, after the restructuring, own 100% of a generating unit. On January 15, 2019, Gulf Power provided notice to Mississippi Power that Gulf Power will retire its share of the generating capacity of Plant Daniel on January 15, 2024. Mississippi Power has the option to purchase Gulf Power's ownership interest for $1 on January 15, 2024, provided that Mississippi Power exercises the option no later than 120 days prior to that date. Mississippi Power is assessing the potential operational and economic effects of Gulf Power's notice. The ultimate outcome of these matters remains subject to completion of Mississippi Power's evaluations and applicable regulatory approvals, including by the FERC and the Mississippi PSC, and cannot be determined at this time. See Note (K) under "Southern Company" for information regarding the sale of Gulf Power.

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Revenue from Contracts with Customers

3 Months Ended

Mar. 31, 2019

Revenue from Contract with Customer [Abstract]

REVENUE FROM CONTRACTS WITH CUSTOMERS

REVENUE FROM CONTRACTS WITH CUSTOMERS

The registrants generate revenues from a variety of sources, some of which are excluded from the scope of ASC 606, Revenue from Contracts with Customers (ASC 606), such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 to the financial statements under "Recently Adopted Accounting Standards – Revenue" in Item 8 of the Form 10-K for additional information on the adoption of ASC 606 for revenue from contracts with customers and Note 1 to the financial statements under "Revenues" and "Other Taxes" in Item 8 of the Form 10-K for additional information on the revenue policies of the registrants. For additional information on revenues accounted for under other accounting guidance, see Notes (J) and (L) for energy-related derivative contracts and lessor revenues, respectively, Note 1 to the financial statements under "Revenues – Southern Company Gas" in Item 8 of the Form 10-K for alternative revenue programs at the natural gas distribution utilities, and Note 2 to the financial statements in Item 8 of the Form 10-K for cost recovery mechanisms.

The following tables disaggregate revenue sources for the three months ended March 31, 2019 and 2018:

	For the Three Months Ended March 31, 2019			For the Three Months Ended March 31, 2018
	(in millions)
Southern Company
Operating revenues
Retail electric revenues(a)
Residential	$	1,288		$	1,539
Commercial	1,093			1,243
Industrial	677			756
Other	26			30
Natural gas distribution revenues	1,163			1,224
Alternative revenue programs(b)	(2		)	(24		)
Total retail electric and gas distribution revenues	$	4,245		$	4,768
Wholesale energy revenues(c)(d)	367			472
Wholesale capacity revenues(d)	132			151
Other natural gas revenues(e)(f)	313			407
Other revenues(g)	355			574
Total operating revenues	$	5,412		$	6,372

(a) Retail electric revenues include $8 million and $18 million of revenues accounted for as leases for the three months ended March 31, 2019 and 2018, respectively, and a (net reduction) or net increase of $(103) million and $117 million for the three months ended March 31, 2019 and 2018, respectively, from certain cost recovery mechanisms that are not accounted for as revenue under ASC 606.

(b) Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period.

(c) Wholesale energy revenues include $53 million and $93 million for the three months ended March 31, 2019 and 2018, respectively, of revenues accounted for as derivatives, primarily related to physical energy sales in the wholesale electricity market.

(d) Wholesale energy and wholesale capacity revenues include $66 million and $25 million, respectively, for the three months ended March 31, 2019 and $69 million and $30 million, respectively, for the three months ended March 31, 2018 related to PPAs accounted for as leases.

(e) Other natural gas revenues related to Southern Company Gas' energy and risk management activities are presented net of the related costs of those activities and include gross third-party revenues of $1.9 billion for each of the three months ended March 31, 2019 and 2018, of which $1.2 billion and $1.1 billion, respectively, relates to contracts that are accounted for as derivatives. See Note (M) under "Southern Company Gas" for additional information on the components of wholesale gas services operating revenues.

(f) Other natural gas revenues for the three months ended March 31, 2019 include $9 million of revenues accounted for as leases.

(g) Other revenues include $96 million and $90 million for the three months ended March 31, 2019 and 2018, respectively, of revenues not accounted for under ASC 606, including $31 million and $33 million in 2019 and 2018, respectively, accounted for as leases.

	Alabama Power		Georgia Power		Mississippi Power
	(in millions)
For the Three Months Ended March 31, 2019
Operating revenues
Retail revenues(a)(b)
Residential	$	540	$	688	$	60
Commercial	354		674		65
Industrial	313		289		74
Other	6		17		4
Total retail electric revenues	$	1,213	$	1,668	$	203
Wholesale energy revenues(c)	94		18		78
Wholesale capacity revenues	27		14		1
Other revenues(b)(d)	74		133		5
Total operating revenues	$	1,408	$	1,833	$	287
For the Three Months Ended March 31, 2018
Operating revenues
Retail revenues(a)(b)
Residential	$	570	$	744	$	60
Commercial	371		717		62
Industrial	338		316		70
Other	6		21		2
Total retail electric revenues	$	1,285	$	1,798	$	194
Wholesale energy revenues(c)	101		40		98
Wholesale capacity revenues	24		14		4
Other revenues(b)(d)	63		109		6
Total operating revenues	$	1,473	$	1,961	$	302

(a) Retail revenues at Alabama Power, Georgia Power, and Mississippi Power include a net increase or (net reduction) of $(57) million, $(47) million, and $1 million, respectively, for the three months ended March 31, 2019 and $47 million, $10 million, and $76 million, respectively, for the three months ended March 31, 2018 related to certain cost recovery mechanisms that are not accounted for as revenue under ASC 606.

(b) Retail revenues and other revenues at Georgia Power include $8 million and $11 million, respectively, for the three months ended March 31, 2019 and $18 million and $33 million, respectively, for the three months ended March 31, 2018 of revenues accounted for as leases.

(c) Wholesale energy revenues at Alabama Power, Georgia Power, and Mississippi Power include $3 million, $4 million, and $1 million, respectively, for the three months ended March 31, 2019 and $5 million, $7 million, and $1 million, respectively, for the three months ended March 31, 2018 accounted for as derivatives primarily related to physical energy sales in the wholesale electricity market.

(d) Other revenues at Alabama Power and Georgia Power include $28 million and $31 million, respectively, for the three months ended March 31, 2019 and $25 million and $26 million, respectively, for the three months ended March 31, 2018 of revenues not accounted for under ASC 606.

	For the Three Months Ended March 31, 2019		For the Three Months Ended March 31, 2018
	(in millions)
Southern Power
PPA capacity revenues(a)	$	127	$	138
PPA energy revenues(a)	227		254
Non-PPA revenues(b)	85		115
Other revenues	4		2
Total operating revenues	$	443	$	509

(a) PPA capacity revenues and PPA energy revenues include $41 million and $72 million, respectively, for the three months ended March 31, 2019 and $47 million and $76 million, respectively, for the three months ended March 31, 2018 related to PPAs accounted for as leases.

(b) Non-PPA revenues include $45 million and $79 million for the three months ended March 31, 2019 and 2018, respectively, of revenues from short-term sales related to physical energy sales from uncovered capacity in the wholesale electricity market.

	For the Three Months Ended March 31, 2019			For the Three Months Ended March 31, 2018
	(in millions)
Southern Company Gas
Operating revenues
Natural gas distribution revenues
Residential	$	601		$	660
Commercial	170			192
Transportation	256			277
Industrial	17			17
Other	119			78
Alternative revenue programs(a)	(2		)	(24		)
Total natural gas distribution revenues	$	1,161		$	1,200
Gas pipeline investments(b)	8			8
Wholesale gas services(c)	66			146
Gas marketing services(d)	229			271
Other revenues	10			14
Total operating revenues	$	1,474		$	1,639

(a) Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period.

(b) Revenues from gas pipeline investments include $8 million for the three months ended March 31, 2019 accounted for as leases.

(c) Wholesale gas services revenues are presented net of the related costs associated with its energy trading and risk management activities. Operating revenues, as presented, include gross third-party revenues of $1.9 billion for each of the three months ended March 31, 2019 and 2018, of which $1.2 billion and $1.1 billion, respectively, relates to contracts accounted for as derivatives. See Note (M) under "Southern Company Gas" for additional information on the components of wholesale gas services operating revenues.

(d) Gas marketing services includes $6 million and $4 million for the three months ended March 31, 2019 and 2018, respectively, of revenues not accounted for under ASC 606.

Contract Balances

The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers as of March 31, 2019 and December 31, 2018:

	Receivables				Contract Assets				Contract Liabilities
	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018
	(in millions)
Southern Company(*)	$	2,522	$	2,630	$	84	$	102	$	62	$	32
Alabama Power	514		520		1		—		10		12
Georgia Power	668		721		41		58		25		7
Mississippi Power	85		100		—		—		—		—
Southern Power	99		118		—		—		4		11
Southern Company Gas	948		952		—		—		1		2

(*) Includes amounts related to held for sale investments.

As of March 31, 2019 and December 31, 2018, Georgia Power had contract assets primarily related to unregulated service agreements where payment is contingent on project completion and fixed retail customer bill programs where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over the one-year contract term. Alabama Power had contract liabilities for outstanding performance obligations primarily related to extended service agreements. Contract liabilities for Georgia Power and Southern Power relate to cash collections recognized in advance of revenue for certain unregulated service agreements and certain levelized PPAs, respectively. Southern Company's unregulated distributed generation business had $34 million and $39 million of contract assets and $25 million and $11 million of contract liabilities at March 31, 2019 and December 31, 2018, respectively, remaining for outstanding performance obligations.

The following table reflects revenue from contracts with customers recognized in the three-month period ended March 31, 2019 included in the contract liability at December 31, 2018:

	Three Months Ended March 31, 2019
	(in millions)
Southern Company	$	17
Southern Power	10

Revenues recognized in the three-month period ended March 31, 2019, which were included in contract liabilities at December 31, 2018, were immaterial for Alabama Power, Georgia Power, and Southern Company Gas.

Remaining Performance Obligations

The traditional electric operating companies and Southern Power have long-term contracts with customers in which revenues are recognized when the performance obligations are satisfied during the contract term. These contracts primarily relate to PPAs whereby the traditional electric operating companies and Southern Power provide electricity and generation capacity to a customer. The revenue recognized for the delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Registrants with revenues from contracts with customers related to these performance obligations remaining at March 31, 2019 expect the revenues to be recognized as follows:

	2019 (remaining)		2020		2021		2022		2023		Thereafter
	(in millions)
Southern Company(*)	$	451	$	349	$	315	$	310	$	301	$	2,219
Alabama Power	16		22		27		23		22		140
Georgia Power	30		38		40		30		31		82
Mississippi Power	2		3		1		—		—		—
Southern Power	248		295		270		276		269		2,143

(*) Includes amounts related to held for sale investments.

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Consolidated Entities and Equity Method Investments

3 Months Ended

Mar. 31, 2019

Regulated Operations [Abstract]

CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS

CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS

Southern Power

Variable Interest Entities

See Note 7 to the financial statements in Item 8 of the Form 10-K for additional information on Southern Power's VIEs.

Southern Power has certain wholly-owned 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. Southern Power previously consolidated SP Solar and SP Wind. Southern Power continues to consolidate them following the 2018 sales of noncontrolling interests in each entity, as the primary beneficiary of each VIE, since it controls the most significant activities of each entity, including operating and maintaining their assets. Transfers and sales of the assets in the VIEs are subject to limited 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.

SP Solar

At March 31, 2019, SP Solar had total assets of $6.5 billion, total liabilities of $373 million, and noncontrolling interests of $1.2 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves.

SP Wind

At March 31, 2019, SP Wind had total assets of $2.6 billion, total liabilities of $141 million, and noncontrolling interests of $46 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 Company Gas

See Note 7 to the financial statements in Item 8 of the Form 10-K for additional information on Southern Company Gas' equity method investments.

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments as of March 31, 2019 and December 31, 2018 and related income from those investments for the three-month periods ended March 31, 2019 and 2018 were as follows:

Investment Balance	March 31, 2019		December 31, 2018
	(in millions)
SNG	$	1,262	$	1,261
Atlantic Coast Pipeline	96		83
PennEast Pipeline	75		71
Other	124		123
Total	$	1,557	$	1,538

Earnings from Equity Method Investments	Three Months Ended March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
SNG	$	42	$	39
Atlantic Coast Pipeline	3		1
PennEast Pipeline	2		1
Other	1		1
Total	$	48	$	42

SNG

Selected financial information of SNG for the three months ended March 31, 2019 and 2018 is as follows:

Income Statement Information	Three Months Ended March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
Revenues	$	166	$	160
Operating income	106		99
Net income	84		78

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Financing

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

FINANCING

FINANCING

Bank Credit Arrangements

Bank credit arrangements provide liquidity support to the registrants' commercial paper borrowings and the traditional electric operating companies' revenue bonds. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support as of March 31, 2019 was approximately $1.4 billion (comprised of approximately $854 million at Alabama Power, $550 million at Georgia Power, and $40 million at Mississippi Power). In addition, at March 31, 2019, the traditional electric operating companies had approximately $432 million (comprised of approximately $87 million at Alabama Power and $345 million at Georgia Power) of revenue bonds outstanding that were required to be remarketed within the next 12 months. Subsequent to March 31, 2019, Georgia Power purchased and held approximately $115 million of outstanding pollution control revenue bonds required to be remarketed. See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K and "Financing Activities" herein for additional information.

The following table outlines the committed credit arrangements by company as of March 31, 2019:

	Expires
Company	2019		2020		2022		Total		Unused(d)
	(in millions)
Southern Company(a)	$	—	$	—	$	2,000	$	2,000	$	1,999
Alabama Power	33		500		800		1,333		1,333
Georgia Power	—		—		1,750		1,750		1,736
Mississippi Power	100		—		—		100		100
Southern Power(b)	—		—		750		750		741
Southern Company Gas(c)	—		—		1,900		1,900		1,895
Other	30		—		—		30		30
Southern Company Consolidated	$	163	$	500	$	7,200	$	7,863	$	7,834

(a) Represents the Southern Company parent entity.

(b) Does not include Southern Power Company's $120 million continuing letter of credit facility for standby letters of credit expiring in 2021, of which $24 million was unused at March 31, 2019. Southern Power's subsidiaries are not parties to its bank credit arrangement.

(c) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $1.4 billion of this arrangement. Southern Company Gas' committed credit arrangement also includes $500 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to this multi-year credit arrangement, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

(d) Amounts used are for letters of credit.

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.

DOE Loan Guarantee 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 regarding Georgia Power's 2014 loan guarantee agreement.

Pursuant to the loan guarantee program established under Title XVII of the Energy Policy Act of 2005 (Title XVII Loan Guarantee Program), Georgia Power and the DOE entered into a loan guarantee agreement in 2014 and the Amended and Restated Loan Guarantee Agreement in March 2019. Under the Amended and Restated Loan Guarantee Agreement, the DOE has agreed to guarantee the obligations of Georgia Power under note purchase agreements among the DOE, Georgia Power, and the FFB and related promissory notes which provide for two multi-advance term loan facilities (FFB Credit Facilities). Under the FFB Credit Facilities, Georgia Power may make term loan borrowings through the FFB in an amount up to approximately $5.130 billion, provided that total aggregate borrowings under the FFB Credit Facilities may not exceed 70% of (i) Eligible Project Costs minus (ii) approximately $1.492 billion (reflecting the amounts received by Georgia Power under the Guarantee Settlement Agreement less the Customer Refunds).

In March 2019, Georgia Power made borrowings under the FFB Credit Facilities in an aggregate principal amount of $835 million at an interest rate of 3.213% through the final maturity date of February 20, 2044. At March 31, 2019, Georgia Power had a total of $3.46 billion of borrowings outstanding under the FFB Credit Facilities.

All borrowings under the FFB Credit Facilities are full recourse to Georgia Power, and Georgia Power is obligated to reimburse the DOE for any payments the DOE is required to make to the FFB under its guarantee. Georgia Power's reimbursement obligations to the DOE are full recourse and secured by a first priority lien on (i) Georgia Power's 45.7% undivided ownership interest in Plant Vogtle Units 3 and 4 (primarily the units under construction, the related real property, and any nuclear fuel loaded in the reactor core) and (ii) Georgia Power's rights and obligations under the principal contracts relating to Plant Vogtle Units 3 and 4. There are no restrictions on Georgia Power's ability to grant liens on other property.

In addition to the conditions described above, future advances are subject to satisfaction of customary conditions, as well as certification of compliance with the requirements of the Title XVII Loan Guarantee Program, including accuracy of project-related representations and warranties, delivery of updated project-related information, and evidence of compliance with the prevailing wage requirements of the Davis-Bacon Act of 1931, as amended, and certification from the DOE's consulting engineer that proceeds of the advances are used to reimburse Eligible Project Costs.

Upon satisfaction of all conditions described above, advances may be requested on a quarterly basis through 2023. The final maturity date for each advance under the FFB Credit Facilities is February 20, 2044. Interest is payable quarterly and principal payments will begin on February 20, 2020. Borrowings under the FFB Credit Facilities will bear interest at the applicable U.S. Treasury rate plus a spread equal to 0.375%.

Under the Amended and Restated Loan Guarantee Agreement, Georgia Power is subject to customary borrower affirmative and negative covenants and events of default. In addition, Georgia Power is subject to project-related reporting requirements and other project-specific covenants and events of default.

In the event certain mandatory prepayment events occur, the FFB's commitment to make further advances under the FFB Credit Facilities will terminate and Georgia Power will be required to prepay the outstanding principal amount of all borrowings under the FFB Credit Facilities over a period of five years (with level principal amortization). Among other things, these mandatory prepayment events include (i) the termination of the Vogtle Services Agreement or rejection of the Vogtle Services Agreement in any Westinghouse bankruptcy if Georgia Power does not maintain access to intellectual property rights under the related intellectual property licenses; (ii) termination of the Bechtel Agreement, unless the Vogtle Owners enter into a replacement agreement; (iii) cancellation of Plant Vogtle Units 3 and 4 by the Georgia PSC or by Georgia Power; (iv) failure of the holders of 90% of the ownership interests in Plant Vogtle Units 3 and 4 to vote to continue construction following certain schedule extensions; (v) cost disallowances by the Georgia PSC that could have a material adverse effect on completion of Plant Vogtle Units 3 and 4 or Georgia Power's ability to repay the outstanding borrowings under the FFB Credit Facilities; or (vi) loss of or failure to receive necessary regulatory approvals. Under certain circumstances, insurance proceeds and any proceeds from an event of taking must be applied to immediately prepay outstanding borrowings under the FFB Credit Facilities. In addition, if Georgia Power discontinues construction of Plant Vogtle Units 3 and 4, Georgia Power would be obligated to immediately repay a portion of the outstanding borrowings under the FFB Credit Facilities to the extent such outstanding borrowings exceed 70% of Eligible Project Costs, net of the proceeds received by Georgia Power under the Guarantee Settlement Agreement less the Customer Refunds. Georgia Power also may voluntarily prepay outstanding borrowings under the FFB Credit Facilities. Under the FFB Credit Facilities, any prepayment (whether mandatory or optional) will be made with a make-whole premium or discount, as applicable.

In connection with any cancellation of Plant Vogtle Units 3 and 4, the DOE may elect to continue construction of Plant Vogtle Units 3 and 4. In such an event, the DOE will have the right to assume Georgia Power's rights and obligations under the principal agreements relating to Plant Vogtle Units 3 and 4 and to acquire all or a portion of Georgia Power's ownership interest in Plant Vogtle Units 3 and 4.

Financing Activities

The following table outlines the long-term debt financing activities for Southern Company and its subsidiaries for the first three months of 2019:

Company	Senior Note Maturities, Redemptions, and Repurchases		Revenue Bond Issuances and Reofferings of Purchased Bonds		Revenue Bond Maturities, Redemptions, and Repurchases		Other Long-Term Debt Issuances		Other Long-Term Debt Redemptions and Maturities(a)
	(in millions)
Southern Company(b)	$	2,100	$	—	$	—	$	—	$	—
Alabama Power	200		—		—		—		—
Georgia Power	—		343		108		835		2
Mississippi Power	—		43		—		—		—
Other	—		—		—		—		19
Southern Company Consolidated	$	2,300	$	386	$	108	$	835	$	21

(a) Includes reductions in finance lease obligations resulting from cash payments under finance leases.

(b) Represents the Southern Company parent entity.

Except as otherwise described herein, Southern Company and its subsidiaries 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 subsidiaries also used the proceeds for their construction programs.

Southern Company

In January 2019, Southern Company repaid a $250 million short-term uncommitted bank credit arrangement and a $1.5 billion short-term floating rate bank loan.

Also in January 2019, through cash tender offers, Southern Company repurchased and retired approximately $522 million of the $1.0 billion aggregate principal amount outstanding of its 1.85% Senior Notes due July 1, 2019 (1.85% Notes), approximately $180 million of the $350 million aggregate principal amount outstanding of its Series 2014B 2.15% Senior Notes due September 1, 2019 (Series 2014B Notes), and approximately $504 million of the $750 million aggregate principal amount outstanding of its Series 2018A Floating Rate Notes due February 14, 2020 (Series 2018A Notes), for an aggregate purchase price, excluding accrued and unpaid interest, of approximately $1.2 billion. In addition, following the completion of the cash tender offers, in February 2019, Southern Company completed the redemption of all of the Series 2018A Notes, 1.85% Notes, and Series 2014B Notes remaining outstanding.

Georgia Power

In January 2019, Georgia Power redeemed approximately $13 million, $20 million, and $75 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 1992, Eighth Series 1994, and Second Series 1995, respectively.

In March 2019, Georgia Power reoffered to the public the following pollution control revenue bonds that previously had been purchased and held by Georgia Power:

• $173 million aggregate principal amount of Development Authority of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Bowen Project), First Series 2009;

• approximately $105 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 2013; and

• $65 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 2008.

Subsequent to March 31, 2019, Georgia Power purchased and held the following pollution control revenue bonds, which may be reoffered to the public at a later date:

• $55 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1994;

• $30 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1995;

• $20 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Ninth Series 1994; and

• $10 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 1994.

Mississippi Power

In March 2019, Mississippi Power reoffered to the public $43 million of Mississippi Business Finance Corporation Pollution Control Revenue Refunding Bonds, Series 2002, that previously had been purchased and held by Mississippi Power.

Earnings per Share

For Southern Company, the only difference in computing basic and diluted earnings per share is attributable to awards outstanding under stock-based compensation plans. See Note 12 to the financial statements in Item 8 of the Form 10-K for information on stock-based compensation plans. The effect of stock-based compensation plans was determined using the treasury stock method. Shares used to compute diluted earnings per share were as follows:

	Three Months Ended March 31, 2019	Three Months Ended March 31, 2018
	(in millions)
As reported shares	1,038	1,011
Effect of stock-based compensation	7	5
Diluted shares	1,045	1,016

There were no stock-based compensation awards that were not included in the diluted earnings per share calculation because they were anti-dilutive for the three months ended March 31, 2019 and an immaterial amount of such awards was not included for the three months ended March 31, 2018.

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Income Taxes

3 Months Ended

Mar. 31, 2019

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.

Effective Tax Rate

Details of significant changes in the effective tax rate for the applicable registrants are provided herein.

Southern Company

Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity and flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs, primarily at Southern Power.

Southern Company's effective tax rate was 39.8% for the three months ended March 31, 2019 compared to 10.8% for the corresponding period in 2018. The effective tax rate increase was primarily due to the tax impact from the sale of Gulf Power. See Note (K) for additional information.

Alabama Power

Alabama Power's effective tax rate was 21.9% for the three months ended March 31, 2019 compared to 26.3% for the corresponding period in 2018. The effective tax rate decrease was primarily due to the application in 2018 of the accounting order approved by the Alabama PSC in May 2018 related to the Tax Reform Legislation. See Note 2 to the financial statements under "Alabama Power – Tax Reform Accounting Order" in Item 8 of the Form 10-K for additional information.

Mississippi Power

Mississippi Power's effective tax rate was 15.5% for the three months ended March 31, 2019 compared to a benefit rate of (34.7)% for the corresponding period in 2018. The effective tax rate increase was primarily due to lower estimated losses on the Kemper IGCC in 2019, partially offset by an increase in the flowback of excess deferred income taxes as a result of a settlement agreement reached with wholesale customers under the MRA tariff. See Note (B) under "Mississippi Power" for additional information.

Southern Power

Southern Power's effective tax benefit rate was (49.8)% for the three months ended March 31, 2019 compared to (647.0)% for the corresponding period in 2018. The effective tax benefit rate decrease was primarily due to changes in state apportionment rates following the reorganization of Southern Power's legal entities that own and operate certain solar facilities and a reduction of tax benefits from wind PTCs primarily as a result of the sale of a noncontrolling tax equity interest in SP Wind.

Southern Company Gas

Southern Company Gas' effective tax rate was 22.3% for the three months ended March 31, 2019 compared to 27.2% for the corresponding period in 2018. This decrease was primarily related to tax impacts of the goodwill impairment charge recorded in the first quarter 2018 and an increase in the flowback of excess deferred income taxes in 2019 primarily at Atlanta Gas Light as previously authorized by the Georgia PSC. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

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Retirement Benefits

3 Months Ended

Mar. 31, 2019

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, 2019. 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.

Components of the net periodic benefit costs for the three months ended March 31, 2019 and 2018 are presented in the following tables.

Three Months Ended March 31, 2019	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Power			Southern Company Gas
	(in millions)
Pension Plans
Service cost	$	73		$	17		$	19		$	3		$	2		$	6
Interest cost	123			28			39			6			1			9
Expected return on plan assets	(221		)	(51		)	(73		)	(10		)	(2		)	(15		)
Amortization:
Prior service costs	—			—			—			—			—			(1		)
Regulatory asset	—			—			—			—			—			3
Net (gain)/loss	30			9			11			1			—			1
Net periodic pension cost (income)	$	5		$	3		$	(4	)	$	—		$	1		$	3
Postretirement Benefits
Service cost	$	5		$	1		$	1		$	—		$	—		$	1
Interest cost	17			4			7			1			—			2
Expected return on plan assets	(16		)	(6		)	(6		)	—			—			(2		)
Amortization:
Prior service costs	1			1			—			—			—			—
Regulatory asset	—			—			—			—			—			2
Net (gain)/loss	(1		)	—			—			—			—			(1		)
Net periodic postretirement benefit cost	$	6		$	—		$	2		$	1		$	—		$	2

Three Months Ended March 31, 2018	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Power			Southern Company Gas
	(in millions)
Pension Plans
Service cost	$	90		$	19		$	22		$	4		$	2		$	8
Interest cost	116			25			35			5			1			10
Expected return on plan assets	(236		)	(51		)	(74		)	(10		)	(3		)	(18		)
Amortization:
Prior service costs	1			—			—			—			—			(1		)
Regulatory asset	—			—			—			—			—			3
Net (gain)/loss	53			14			17			3			1			3
Net periodic pension cost (income)	$	24		$	7		$	—		$	2		$	1		$	5
Postretirement Benefits
Service cost	$	6		$	1		$	2		$	—		$	—		$	1
Interest cost	19			4			7			1			—			2
Expected return on plan assets	(17		)	(6		)	(6		)	—			—			(2		)
Amortization:
Prior service costs	2			1			—			—			—			—
Regulatory asset	—			—			—			—			—			1
Net (gain)/loss	3			—			2			—			—			—
Net periodic postretirement benefit cost	$	13		$	—		$	5		$	1		$	—		$	2

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Fair Value Measurements

3 Months Ended

Mar. 31, 2019

Fair Value Disclosures [Abstract]

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS

As of March 31, 2019, 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:
As of March 31, 2019:	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)(b)	$	322	$	128	$	4	$	—	$	454
Foreign currency derivatives	—		38		—		—		38
Investments in trusts:(c)(d)
Domestic equity	682		120		—		—		802
Foreign equity	60		195		—		—		255
U.S. Treasury and government agency securities	—		283		—		—		283
Municipal bonds	—		73		—		—		73
Pooled funds – fixed income	—		14		—		—		14
Corporate bonds	24		298		—		—		322
Mortgage and asset backed securities	—		72		—		—		72
Private equity	—		—		—		48		48
Cash and cash equivalents	1		—		—		—		1
Other	28		4		—		—		32
Cash equivalents	907		3		—		—		910
Other investments	9		14		—		—		23
Total	$	2,033	$	1,242	$	4	$	48	$	3,327
Liabilities:
Energy-related derivatives(a)(b)	$	466	$	106	$	23	$	—	$	595
Interest rate derivatives	—		35		—		—		35
Foreign currency derivatives	—		24		—		—		24
Contingent consideration	—		—		21		—		21
Total	$	466	$	165	$	44	$	—	$	675

	Fair Value Measurements Using:
As of March 31, 2019:	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	$	—	$	6	$	—	$	—	$	6
Nuclear decommissioning trusts:(c)
Domestic equity	446		108		—		—		554
Foreign equity	60		57		—		—		117
U.S. Treasury and government agency securities	—		18		—		—		18
Municipal bonds	—		1		—		—		1
Corporate bonds	24		139		—		—		163
Mortgage and asset backed securities	—		24		—		—		24
Private equity	—		—		—		48		48
Other	5		—		—		—		5
Cash equivalents	569		3		—		—		572
Other investments	—		14		—		—		14
Total	$	1,104	$	370	$	—	$	48	$	1,522
Liabilities:
Energy-related derivatives	$	—	$	7	$	—	$	—	$	7
Georgia Power
Assets:
Energy-related derivatives	$	—	$	9	$	—	$	—	$	9
Nuclear decommissioning trusts:(c)(d)
Domestic equity	236		1		—		—		237
Foreign equity	—		134		—		—		134
U.S. Treasury and government agency securities	—		265		—		—		265
Municipal bonds	—		72		—		—		72
Corporate bonds	—		160		—		—		160
Mortgage and asset backed securities	—		47		—		—		47
Other	23		4		—		—		27
Total	$	259	$	692	$	—	$	—	$	951
Liabilities:
Energy-related derivatives	$	—	$	16	$	—	$	—	$	16
Interest rate derivatives	—		2		—		—		2
Total	$	—	$	18	$	—	$	—	$	18

	Fair Value Measurements Using:
As of March 31, 2019:	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	$	—	$	3	$	—	$	—	$	3
Cash equivalents	202		—		—		—		202
Total	$	202	$	3	$	—	$	—	$	205
Liabilities:
Energy-related derivatives	$	—	$	6	$	—	$	—	$	6
Southern Power
Assets:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1
Foreign currency derivatives	—		38		—		—		38
Cash equivalents	10		—		—		—		10
Total	$	10	$	39	$	—	$	—	$	49
Liabilities:
Energy-related derivatives	$	—	$	3	$	—	$	—	$	3
Foreign currency derivatives	—		24		—		—		24
Contingent consideration	—		—		21		—		21
Total	$	—	$	27	$	21	$	—	$	48
Southern Company Gas
Assets:
Energy-related derivatives(a)(b)	$	322	$	108	$	4	$	—	$	434
Non-qualified deferred compensation trusts:
Domestic equity	—		11		—		—		11
Foreign equity	—		4		—		—		4
Pooled funds – fixed income	—		14		—		—		14
Cash equivalents	1		—		—		—		1
Cash equivalents	13		—		—		—		13
Total	$	336	$	137	$	4	$	—	$	477
Liabilities:
Energy-related derivatives(a)(b)	$	466	$	73	$	23	$	—	$	562

(a) Energy-related derivatives exclude $11 million associated with premiums and certain weather derivatives accounted for based on intrinsic value rather than fair value.

(b) Energy-related derivatives exclude cash collateral of $190 million.

(c) 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.

(d) Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. As of March 31, 2019, approximately $72 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 for the three months ended March 31, 2019 and decreased for the three months ended March 31, 2018 by the amounts shown in the table below. 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 March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
Southern Company	$	152	$	(11	)
Alabama Power	87		(5		)
Georgia Power	65		(6		)

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 Southern Power 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 obligation is 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.

As of March 31, 2019, the fair value measurements of private equity investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $48 million and unfunded commitments related to the private equity investments totaled $49 million. Private equity funds include funds-of-funds that invest in high-quality private equity funds across several market sectors, funds that invest in real estate assets, and a fund that acquires companies to create resale value. Private equity funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated.

As of March 31, 2019, 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 millions)
Long-term debt, including securities due within one year:
Carrying amount	$	42,535	$	7,921	$	10,910	$	1,619	$	4,995	$	5,928
Fair value	43,910		8,424		11,249		1,619		5,131		6,176

(*) The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the Merger. Southern Company Gas amortizes the fair value adjustments over the lives of the respective bonds.

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 Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas.

Commodity Contracts with Level 3 Valuation Inputs

As of March 31, 2019, the fair value of Southern Company Gas' Level 3 physical natural gas forward contracts was $19 million. Since commodity contracts classified as Level 3 typically include a combination of observable and unobservable components, the changes in fair value may include amounts due in part to observable market factors, or changes to assumptions on the unobservable components. The following table includes transfers to Level 3, which represent the fair value of Southern Company Gas' commodity derivative contracts that include a significant unobservable component for the first time during the period.

	Three Months Ended March 31, 2019
	(in millions)
Beginning balance	$	—
Transfers to Level 3	(30		)
Changes in fair value	11
Ending balance	$	(19	)

Changes in fair value of Level 3 instruments represent changes in gains and losses for the periods that are reported on Southern Company Gas' statements of income in natural gas revenues.

The valuation of certain commodity contracts requires the use of certain unobservable inputs. All forward pricing used in the valuation of such contracts is directly based on third-party market data, such as broker quotes and exchange settlements, when that data is available. If third-party market data is not available, then industry standard methodologies are used to develop inputs that maximize the use of relevant observable inputs and minimize the use of unobservable inputs. Observable inputs, including some forward prices used for determining fair value, reflect the best available market information. Unobservable inputs are updated using industry standard techniques such as extrapolation, combining observable forward inputs supplemented by historical market and other relevant data. Level 3 physical natural gas forward contracts include unobservable forward price inputs (ranging from $0.07 to $1.15 per mmBtu). Forward price increases (decreases) as of March 31, 2019 would have resulted in higher (lower) values on a net basis.

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Derivatives

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVES

DERIVATIVES

Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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. Southern Company Gas' wholesale gas operations use various contracts in its commercial activities that generally meet the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with 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 traditional electric operating companies, Southern Power, and Southern Company Gas 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 of operating margins 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 the respective fuel cost recovery clauses.

• 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, 2019, 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(*)	538	2022	2029
Alabama Power	72	2022	—
Georgia Power	153	2022	—
Mississippi Power	61	2022	—
Southern Power	9	2020	—
Southern Company Gas(*)	243	2021	2029

(*) Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 3.8 billion mmBtu and short natural gas positions of 3.6 billion mmBtu as of March 31, 2019, 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 40 million mmBtu for Southern Company, which includes 6 million mmBtu for Alabama Power, 12 million mmBtu for Georgia Power, 5 million mmBtu for Mississippi Power, and 13 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 next 12-month period ending March 31, 2020 are immaterial for all registrants.

Interest Rate Derivatives

Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. The derivatives employed as hedging instruments are structured to minimize ineffectiveness. 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, 2019, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2019
	(in millions)					(in millions)
Fair Value Hedges of Existing Debt
Southern Company(*)	$	300	2.75%	3-month LIBOR+0.92%	June 2020	$	(3	)
Southern Company(*)	1,500		2.35%	1-month LIBOR+0.87%	July 2021	(30		)
Georgia Power	200		4.25%	3-month LIBOR+2.46%	December 2019	(2		)
Southern Company Consolidated	$	2,000				$	(35	)

(*) Represents the Southern Company parent entity.

The estimated pre-tax gains (losses) related to interest rate derivatives expected to be reclassified from accumulated OCI to interest expense for the next 12-month period ending March 31, 2020 are $(19) million for Southern Company and immaterial for all other registrants. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2046 for the Southern Company parent entity, 2035 for Alabama Power, 2037 for 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. The derivatives employed as hedging instruments are structured to minimize ineffectiveness.

At March 31, 2019, 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, 2019
	(in millions)			(in millions)				(in millions)
Cash Flow Hedges of Existing Debt
Southern Power	$	677	2.95%	€	600	1.00%	June 2022	$	2
Southern Power	564		3.78%	500		1.85%	June 2026	11
Total	$	1,241		€	1,100			$	13

The estimated pre-tax gains (losses) related to Southern Power's foreign currency derivatives expected to be reclassified from accumulated OCI to earnings for the next 12-month period ending March 31, 2020 are $(24) million.

Derivative Financial Statement Presentation and Amounts

Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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 sheet 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:

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	12		$	10		$	8		$	23
Other deferred charges and assets/Other deferred credits and liabilities	11			21			9			26
Assets held for sale, current/Liabilities held for sale, current	—			—			—			6
Total derivatives designated as hedging instruments for regulatory purposes	$	23		$	31		$	17		$	55
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	1		$	3		$	3		$	7
Other deferred charges and assets/Other deferred credits and liabilities	—			1			1			2
Interest rate derivatives:
Other current assets/Other current liabilities	—			20			—			19
Other deferred charges and assets/Other deferred credits and liabilities	—			15			—			30
Foreign currency derivatives:
Other current assets/Other current liabilities	—			24			—			23
Other deferred charges and assets/Other deferred credits and liabilities	38			—			75			—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	39		$	63		$	79		$	81
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	259		$	291		$	561		$	575
Other deferred charges and assets/Other deferred credits and liabilities	171			269			180			325
Total derivatives not designated as hedging instruments	$	430		$	560		$	741		$	900
Gross amounts recognized	$	492		$	654		$	837		$	1,036
Gross amounts offset(a)	$	(333	)	$	(523	)	$	(524	)	$	(801	)
Net amounts recognized in the Balance Sheets(b)	$	159		$	131		$	313		$	235

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	3		$	2		$	3		$	4
Other deferred charges and assets/Other deferred credits and liabilities	3			5			3			6
Total derivatives designated as hedging instruments for regulatory purposes	$	6		$	7		$	6		$	10
Gross amounts recognized	$	6		$	7		$	6		$	10
Gross amounts offset	$	(5	)	$	(5	)	$	(4	)	$	(4	)
Net amounts recognized in the Balance Sheets	$	1		$	2		$	2		$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	4		$	5		$	2		$	8
Other deferred charges and assets/Other deferred credits and liabilities	5			11			4			13
Total derivatives designated as hedging instruments for regulatory purposes	$	9		$	16		$	6		$	21
Derivatives designated as hedging instruments in cash flow and fair value hedges
Interest rate derivatives:
Other current assets/Other current liabilities	$	—		$	2		$	—		$	2
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	—		$	2		$	—		$	2
Gross amounts recognized	$	9		$	18		$	6		$	23
Gross amounts offset	$	(8	)	$	(8	)	$	(6	)	$	(6	)
Net amounts recognized in the Balance Sheets	$	1		$	10		$	—		$	17

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	2		$	2		$	1		$	3
Other deferred charges and assets/Other deferred credits and liabilities	1			4			2			6
Total derivatives designated as hedging instruments for regulatory purposes	$	3		$	6		$	3		$	9
Gross amounts recognized	$	3		$	6		$	3		$	9
Gross amounts offset	$	(3	)	$	(3	)	$	(2	)	$	(2	)
Net amounts recognized in the Balance Sheets	$	—		$	3		$	1		$	7
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	1		$	2		$	3		$	6
Other deferred charges and assets/Other deferred credits and liabilities	—			1			1			2
Foreign currency derivatives:
Other current assets/Other current liabilities	—			24			—			23
Other deferred charges and assets/Other deferred credits and liabilities	38			—			75			—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	39		$	27		$	79		$	31
Gross amounts recognized	$	39		$	27		$	79		$	31
Gross amounts offset	$	(1	)	$	(1	)	$	(3	)	$	(3	)
Net amounts recognized in the Balance Sheets	$	38		$	26		$	76		$	28
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	$	3		$	1		$	2		$	8
Other deferred charges and assets/Other deferred credits and liabilities	1			—			—			1
Total derivatives designated as hedging instruments for regulatory purposes	$	4		$	1		$	2		$	9
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-current	$	—		$	1		$	—		$	1
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	—		$	1		$	—		$	1

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	$	259		$	291		$	559		$	574
Other deferred charges and assets/Other deferred credits and liabilities	171			269			180			325
Total derivatives not designated as hedging instruments	$	430		$	560		$	739		$	899
Gross amounts of recognized	$	434		$	562		$	741		$	909
Gross amounts offset(a)	$	(316	)	$	(506	)	$	(508	)	$	(785	)
Net amounts recognized in the Balance Sheets(b)	$	118		$	56		$	233		$	124

(a) Gross amounts offset include cash collateral held on deposit in broker margin accounts of $190 million and $277 million as of March 31, 2019 and December 31, 2018, respectively.

(b) Net amounts of derivative instruments outstanding exclude premium and intrinsic value associated with weather derivatives of $11 million and $8 million as of March 31, 2019 and December 31, 2018, respectively.

At March 31, 2019 and December 31, 2018, 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 at March 31, 2019
Derivative Category and Balance Sheet Location	Southern Company(*)			Alabama Power			Georgia Power			Mississippi Power			Southern Company Gas(*)
	(in millions)
Energy-related derivatives:
Other regulatory assets, current	$	(5	)	$	(1	)	$	(2	)	$	(1	)	$	(1	)
Other regulatory assets, deferred	(11		)	(2		)	(6		)	(3		)	—
Other regulatory liabilities, current	7			1			1			1			4
Total energy-related derivative gains (losses)	$	(9	)	$	(2	)	$	(7	)	$	(3	)	$	3

(*) Fair value gains and losses recorded in regulatory assets and liabilities include cash collateral held on deposit in broker margin accounts of $2 million at March 31, 2019.

Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet at December 31, 2018
Derivative Category and Balance Sheet Location	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Company Gas
	(in millions)
Energy-related derivatives:
Other regulatory assets, current	$	(19	)	$	(3	)	$	(6	)	$	(2	)	$	(8	)
Other regulatory assets, deferred	(16		)	(3		)	(9		)	(4		)	—
Assets held for sale, current	(6		)	—			—			—			—
Other regulatory liabilities, current	1			—			—			—			1
Total energy-related derivative gains (losses)	$	(40	)	$	(6	)	$	(15	)	$	(6	)	$	(7	)

For the three months ended March 31, 2019 and 2018, the pre-tax effects of cash flow hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Southern Company
Energy-related derivatives	$	—		$	12
Interest rate derivatives	—			(2		)
Foreign currency derivatives	(39		)	53
Total	$	(39	)	$	63
Southern Power
Energy-related derivatives	$	—		$	11
Foreign currency derivatives	(39		)	53
Total	$	(39	)	$	64

For the three months ended March 31, 2019 and 2018, the pre-tax effects of energy-related derivatives and interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other registrants.

For the three months ended March 31, 2019 and 2018, 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,
	2019			2018
	(in millions)
Southern Company
Total depreciation and amortization	$	751		$	769
Gain (loss) on energy-related cash flow hedges(a)	(3		)	1
Total interest expense, net of amounts capitalized	(430		)	(458		)
Gain (loss) on interest rate cash flow hedges(a)	(5		)	(5		)
Gain (loss) on foreign currency cash flow hedges(a)	(6		)	(5		)
Gain (loss) on interest rate fair value hedges(b)	14			(24		)
Total other income (expense), net	78			60
Gain (loss) on foreign currency cash flow hedges(a)(c)	(24		)	36
Southern Power
Total depreciation and amortization	$	119		$	114
Gain (loss) on energy-related cash flow hedges(a)	(3		)	1
Total interest expense, net of amounts capitalized	(44		)	(47		)
Gain (loss) on foreign currency cash flow hedges(a)	(6		)	(5		)
Total other income (expense), net	2			3
Gain (loss) on foreign currency cash flow hedges(a)(c)	(24		)	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.

For the three months ended March 31, 2019 and 2018, 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 and Southern Company Gas.

As of March 31, 2019 and December 31, 2018, 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	As of March 31, 2019			As of December 31, 2018			As of March 31, 2019		As of December 31, 2018
	(in millions)						(in millions)
Southern Company
Securities due within one year	$	(499	)	$	(498	)	$	1	$	2
Long-term debt	(2,065		)	(2,052		)	28		41
Georgia Power
Securities due within one year	$	(499	)	$	(498	)	$	1	$	2
Long-term debt	—			—			—		—

For the three months ended March 31, 2019 and 2018, 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	2019		2018
		(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	33	$	(15	)
	Cost of natural gas	8		2
Total derivatives in non-designated hedging relationships		$	41	$	(13	)

(*) Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for the three months ended March 31, 2019 and 2018.

For the three months ended March 31, 2019 and 2018, the pre-tax effects of energy-related derivatives and interest rate derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies and Southern Power.

Contingent Features

Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas do not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. At March 31, 2019, the registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For the registrants with interest rate derivatives at March 31, 2019, 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, was immaterial. At March 31, 2019, the fair value of 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 for all registrants. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Following the sale of Gulf Power to NextEra Energy, Gulf Power is continuing to participate in the Southern Company power pool for a defined transition period that, subject to certain potential adjustments, is scheduled to end on January 1, 2024.

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

Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Alabama Power and Southern Power may be required to post collateral. At March 31, 2019, cash collateral posted in these accounts was immaterial. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At March 31, 2019, cash collateral held on deposit in broker margin accounts was $190 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. Prior to entering into a physical transaction, Southern Company Gas assigns physical wholesale counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch Ratings Inc. ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.

In addition, Southern Company Gas conducts credit evaluations and obtains appropriate internal approvals for the counterparty's line of credit before any transaction with the counterparty is executed. In most cases, the counterparty must have an investment grade rating, which includes a minimum long-term debt rating of Baa3 from Moody's and BBB- from S&P. Generally, Southern Company Gas requires credit enhancements by way of a guaranty, cash deposit, or letter of credit for transaction counterparties that do not have investment grade ratings.

Southern Company Gas also utilizes master netting agreements whenever possible to mitigate exposure to counterparty credit risk. When Southern Company Gas is engaged in more than one outstanding derivative transaction with the same counterparty and it also has a legally enforceable netting agreement with that counterparty, the "net" mark-to-market exposure represents the netting of the positive and negative exposures with that counterparty and a reasonable measure of Southern Company Gas' credit risk. Southern Company Gas also uses other netting agreements with certain counterparties with whom it conducts significant transactions. Master netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty. Southern Company Gas also nets across product lines and against cash collateral provided the master netting and cash collateral agreements include such provisions. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.

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

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Acquisitions and Dispositions

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

ACQUISITIONS AND DISPOSITIONS

ACQUISITIONS AND DISPOSITIONS

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

Southern Company

On January 1, 2019, Southern Company completed the sale of all of the capital stock of Gulf Power to 700 Universe, LLC, a wholly-owned subsidiary of NextEra Energy, for an aggregate cash purchase price of approximately $5.8 billion (less $1.3 billion of indebtedness assumed), subject to customary working capital adjustments. The preliminary gain associated with the sale of Gulf Power totaled $2.5 billion pre-tax ($1.3 billion after tax). The assets and liabilities of Gulf Power were classified as assets held for sale and liabilities held for sale on Southern Company's balance sheet as of December 31, 2018.

Southern Power

Construction Projects in Progress

During the three months ended March 31, 2019, Southern Power continued construction of the projects set forth in the table below. Total aggregate construction costs, excluding the acquisition costs, are expected to be between $575 million and $640 million for the Plant Mankato expansion and the Wildhorse Mountain and Reading facilities. At March 31, 2019, total costs of construction incurred for these projects were $347 million and are included in CWIP, except for the Plant Mankato expansion, which is included in assets held for sale in the financial statements. The ultimate outcome of these matters cannot be determined at this time.

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	Expected COD	PPA Contract Period
Mankato expansion(a)	Natural Gas	385	Mankato, MN	May 2019	20 years
Wildhorse Mountain(b)	Wind	100	Pushmataha County, OK	Fourth quarter 2019	20 years
Reading(c)	Wind	200	Osage and Lyon Counties, KS	Second quarter 2020	12 years

(a) In November 2018, Southern Power entered into an agreement to sell all of its equity interests in Plant Mankato, including this expansion currently under construction. This transaction is subject to FERC and state commission approvals and is expected to close mid-2019. The ultimate outcome of this matter cannot be determined at this time. See "Sales of Natural Gas and Biomass Plants" below.

(b) In May 2018, Southern Power purchased 100% of the Wildhorse Mountain facility. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

(c) In August 2018, Southern Power purchased 100% of the membership interests of the Reading facility from the joint development arrangement with Renewable Energy Systems Americas, Inc. described below. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

Development Projects

Southern Power continues to evaluate and refine the deployment of the wind turbine equipment purchased in 2016 and 2017 to potential joint development and construction projects as well as the amount of MW capacity to be constructed. During the three months ended March 31, 2019, approximately $53 million of equipment was marketed for sale and, subsequent to March 31, 2019, was sold. At March 31, 2019, the equipment was classified as held for sale on Southern Company's and Southern Power's balance sheets. See "Assets Held for Sale" herein for additional information.

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

Sales of Natural Gas and Biomass Plants

In November 2018, Southern Power entered into an agreement with Northern States Power to sell all of its equity interests in Plant Mankato (including the 385-MW expansion currently under construction) for an aggregate purchase price of approximately $650 million. The completion of the disposition is subject to the expansion unit reaching commercial operation as well as various other customary conditions to closing, including working capital and timing adjustments.This transaction is subject to FERC and state commission approvals. The assets and liabilities of Plant Mankato are classified as assets held for sale and liabilities held for sale on Southern Company's and Southern Power's balance sheets as of March 31, 2019 and December 31, 2018. See "Assets Held for Sale" herein for additional information.

On April 17, 2019, Southern Power entered into an agreement to sell all of its equity interests in the Nacogdoches biomass-fueled facility to Austin Energy for an aggregate purchase price of $460 million, subject to customary closing conditions and working capital adjustments.

Each of these sales is expected to close in mid-2019; however, the ultimate outcome of these matters cannot be determined at this time.

Assets Subject to Lien

Under the terms of the PPA and the expansion PPA for Plant Mankato, approximately $538 million of assets, primarily related to property, plant, and equipment, are subject to lien at March 31, 2019.

Assets Held for Sale

As discussed above, Southern Company and Southern Power each have assets and liabilities held for sale on their balance sheets at March 31, 2019 and December 31, 2018. Assets and liabilities held for sale have been classified separately on each company's balance sheet at the lower of carrying value or fair value less costs to sell at the time the criteria for held-for-sale classification were met. For assets and liabilities held for sale recorded at fair value on a nonrecurring basis, the fair value of assets held for sale is based primarily on unobservable inputs (Level 3), which includes the agreed upon sales prices in executed sales agreements.

Upon classification as held for sale in November 2018 for Plant Mankato, Southern Power ceased recognizing depreciation and amortization on the long-lived assets to be sold.

The following table provides Southern Company's and Southern Power's major classes of assets and liabilities classified as held for sale at March 31, 2019 and December 31, 2018:

	Southern Company		Southern Power
	(in millions)
At March 31, 2019
Assets Held for Sale:
Current assets	$	55	$	11
Total property, plant, and equipment	637		604
Goodwill and other intangible assets	82		40
Other non-current assets	44		—
Total Assets Held for Sale	$	818	$	655
Liabilities Held for Sale:
Current liabilities	$	38	$	9
Other non-current liabilities	39		—
Total Liabilities Held for Sale	$	77	$	9
At December 31, 2018
Assets Held for Sale:
Current assets	$	393	$	8
Total property, plant, and equipment	4,583		536
Goodwill and other intangible assets	40		40
Other non-current assets	727		—
Total Assets Held for Sale	$	5,743	$	584
Liabilities Held for Sale:
Current liabilities	$	425	$	15
Long-term debt	1,286		—
Accumulated deferred income taxes	618		—
Other non-current liabilities	932		—
Total Liabilities Held for Sale	$	3,261	$	15

Southern Company and Southern Power each concluded that the sale of their assets, both individually and combined, did not represent a strategic shift in operations that has, or is expected to have, a major effect on its operations and financial results; therefore, none of the assets related to the sales have been classified as discontinued operations for any of the periods presented.

Gulf Power and Southern Power's equity interests in Plant Oleander and Plant Stanton Unit A (together, the Florida Plants) represented individually significant components of Southern Company and Southern Power, respectively; therefore, pre-tax profit for these components for the three months ended March 31, 2018 is presented below:

	For the Three Months Ended March 31, 2018
	(in millions)
Earnings before income taxes:
Gulf Power	$	55
Southern Power's Florida Plants	$	8

XML

Leases

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

LEASES

LEASES

On January 1, 2019, the registrants adopted the provisions of FASB ASC Topic 842 (as amended), Leases (ASC 842), which require lessees to recognize leases with a term of greater than 12 months on the balance sheet as lease obligations, representing the discounted future fixed payments due, along with right-of-use (ROU) assets that will be amortized over the term of each lease.

The registrants elected the transition methodology provided by ASC 842, whereby the applicable requirements are applied on a prospective basis as of the adoption date of January 1, 2019, without restating prior periods. The registrants also elected the package of practical expedients provided by ASC 842 that allows prior determinations of whether existing contracts are, or contain, leases and the classification of existing leases to continue without reassessment. Additionally, the registrants applied the use-of-hindsight practical expedient in determining lease terms as of the date of adoption and elected the practical expedient that allows existing land easements not previously accounted for as leases not to be reassessed.

Lessee

As lessee, the registrants lease certain electric generating units (including renewable energy facilities), real estate/land, communication towers, railcars, and other equipment and vehicles. The major categories of lease obligations are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Electric generating units	$	1,094	$	159	$	1,606	$	—	$	—	$	—
Real estate/land	803		3		63		2		393		83
Communication towers	131		1		3		—		—		—
Railcars	55		25		26		3		—		—
Other	153		10		16		3		—		1
Total	$	2,236	$	198	$	1,714	$	8	$	393	$	84

Real estate/land leases primarily consist of commercial real estate leases at Southern Company, Georgia Power, and Southern Company Gas and various land leases primarily associated with renewable energy facilities at Southern Power. The commercial real estate leases have remaining terms of up to 25 years while the land leases have remaining terms of up to 48 years, including renewal periods.

Communication towers are leased for the installation of equipment to provide cellular phone service to customers and to support the automated meter infrastructure programs at the traditional electric operating companies. Communication tower leases have terms of up to 10 years with options to renew for periods up to 20 years.

While renewal options exist in many of the leases, other than for land leases associated with renewable energy facilities, the expected term used in calculating the lease obligation generally reflects only the noncancelable period of the lease as it is not considered reasonably certain that the lease will be extended. The expected term of land leases associated with renewable energy facilities includes renewal periods reasonably certain of exercise resulting in an expected lease term at least equal to the expected life of the renewable energy facilities.

Contracts that Contain a Lease

While not specifically structured as a lease, some of the PPAs at Alabama Power and Georgia Power are deemed to represent a lease of the underlying electric generating units when the terms of the PPA convey the right to control the use of the underlying assets. Amounts recorded for leases of electric generating units are generally based on the amount of scheduled capacity payments due over the remaining term of the affiliate PPA, which varies between four and 18 years. Georgia Power has several PPAs with Southern Power that Georgia Power accounts for as leases with a lease obligation of approximately $670 million at March 31, 2019. The amount paid for energy under these affiliate PPAs reflects a price that would be paid in an arm's-length transaction as those amounts have been reviewed and approved by the Georgia PSC.

Short-term Leases

Leases with an initial term of 12 months or less are not recorded on the balance sheet; the registrants generally recognize lease expense for these leases on a straight-line basis over the lease term.

Residual Value Guarantees

Residual value guarantees exist primarily in railcar leases at Alabama Power and Georgia Power and the amounts probable of being paid under those guarantees are included in the lease payments. All such amounts are immaterial as of March 31, 2019.

Lease and Nonlease Components

For all asset categories, with the exception of electric generating units, gas pipelines, and real estate leases, the registrants combine lease payments and any nonlease components, such as asset maintenance, for purposes of calculating the lease obligation and the right-of-use asset.

Balance sheet amounts recorded for operating and finance leases are as follows:

	As of March 31, 2019
	Southern  Company(*)		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Operating Leases
Operating lease ROU assets, net	$	1,926	$	160	$	1,519	$	8	$	372	$	86
Operating lease obligations - current	$	239	$	47	$	139	$	3	$	22	$	13
Operating lease obligations - non current	1,752		147		1,404		5		371		71
Total operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance Leases
Finance lease ROU assets, net	$	242	$	4	$	145	$	—	$	—	$	—
Finance lease obligations - current	$	38	$	1	$	10	$	—	$	—	$	—
Finance lease obligations - noncurrent	207		3		161		—		—		—
Total finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

(*) Includes operating lease ROU assets, net and operating lease obligations classified as held for sale.

Lease costs for the three months ended March 31, 2019, which includes both amounts recognized as operations and maintenance expense and amounts capitalized as part of the cost of another asset, are as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease cost
Operating lease cost	$	69	$	7	$	49	$	1	$	7	$	4
Finance lease cost:
Amortization of ROU assets	7		—		4		—		—		—
Interest on lease obligations	3		—		4		—		—		—
Total finance lease cost	10		—		8		—		—		—
Short-term lease costs	14		5		3		—		—		—
Variable lease cost	19		—		16		—		1		—
Sublease income	—		—		—		—		—		—
Total lease cost	$	112	$	12	$	76	$	1	$	8	$	4

Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities subject to PPAs.

Other information with respect to cash and noncash activities related to leases, as well as weighted-average lease terms and discount rates, is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Other information
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$	74	$	13	$	32	$	1	$	7	$	4
Operating cash flows from finance leases	6		—		13		—		—		—
Financing cash flows from finance leases	8		—		2		—		—		—
ROU assets obtained in exchange for new operating lease obligations	15		2		4		—		—		—
ROU assets obtained in exchange for new finance lease obligations	29		—		28		—		—		—

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
Weighted-average remaining lease term in years:
Operating leases	13.5		3.8		10.1		6.8		33.7		9.0
Finance leases	18.5		14.8		11.3		—		—		—
Weighted-average discount rate:
Operating leases	4.49	%	3.33	%	4.42	%	4.03	%	5.68	%	3.70	%
Finance leases	5.00	%	3.75	%	10.68	%	—	%	—	%	—	%

Maturities of lease liabilities are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Maturity Analysis
Operating leases:
2019 (remaining)	$	253	$	46	$	182	$	2	$	17	$	12
2020	291		53		202		2		22		16
2021	274		52		197		1		23		16
2022	263		52		195		1		23		12
2023	198		3		196		1		24		10
Thereafter	1,637		1		984		2		848		36
Total	2,916		207		1,956		9		957		102
Less: Present value discount	925		13		413		1		564		18
Operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance leases:
2019 (remaining)	$	24	$	1	$	22	$	—	$	—	$	—
2020	32		1		28		—		—		—
2021	26		1		25		—		—		—
2022	22		1		25		—		—		—
2023	18		1		25		—		—		—
Thereafter	273		—		165		—		—		—
Total	395		5		290		—		—		—
Less: Present value discount	150		1		119		—		—		—
Finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

Payments made under PPAs at Georgia Power for energy generated from certain renewable energy facilities accounted for as operating and finance leases are considered variable lease costs and are therefore not reflected in the above maturity analysis. As of March 31, 2019, Southern Company and Southern Power have additional operating leases, primarily for land, that have not yet commenced. These operating leases are expected to commence during the remainder of 2019 through 2021, with lease terms of up to 30 years, and have estimated total obligations of $77 million.

For additional information on each registrant's operating lease obligations at December 31, 2018, see Note 9 to the financial statements in Item 8 of the Form 10-K.

Lessor

With the exception of Southern Company Gas, the registrants are each considered lessors in various arrangements that have been determined to contain a lease due to the customer's ability to control the use of the underlying asset owned by the applicable registrant. For the traditional electric operating companies, these arrangements consist of outdoor lighting contracts accounted for as operating leases with initial terms of up to five years, after which the contracts renew on a month-to-month basis at the customer's option. For Mississippi Power, these arrangements also include tolling arrangements related to electric generating units accounted for as sales-type leases with terms of up to 20 years. For Southern Power, these arrangements consist of PPAs related to electric generating units, including renewable energy facilities, accounted for as operating leases with terms of up to 28 years. For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as operating leases with terms of up to 15 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with remaining terms of up to 24 years.

Lease income for the three months ended March 31, 2019 is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease income - interest income on sales-type leases	$	2	$	—	$	2	$	—	$	—
Lease income - operating leases	71		19		—		41		9
Variable lease income	66		—		—		72		—
Total lease income	$	139	$	19	$	2	$	113	$	9

No profit or loss was recognized by Mississippi Power upon commencement of a sales-type lease during the first quarter 2019.

Lease income for Southern Power is included in wholesale revenues. 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. Scheduled payments to be received under outdoor lighting contracts, tolling arrangements, and PPAs accounted for as leases are presented in the following maturity analyses.

The undiscounted cash flows to be received under tolling arrangements accounted for as sales-type leases are as follows:

	As of March 31, 2019
	Southern Company		Mississippi Power
	(in millions)
2019 (remaining)	$	11	$	11
2020	14		14
2021	14		14
2022	13		13
2023	12		12
Thereafter	135		135
Total undiscounted cash flows	$	199	$	199
Lease receivable	108		108
Difference between undiscounted cash flows and discounted cash flows	$	91	$	91

The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases (adjusted for intercompany eliminations) are as follows:

	As of March 31, 2019
	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
2019 (remaining)	$	163	$	20	$	123	$	26
2020	188		26		128		34
2021	183		18		131		34
2022	174		8		134		34
2023	171		2		137		34
Thereafter	1,809		—		1,017		498
Total	$	2,688	$	74	$	1,670	$	660

Southern Power receives payments for renewable energy under PPAs accounted for as operating leases that are considered contingent rents and are therefore not reflected in the table above. Southern Power allocates revenue to the nonlease components of PPAs based on the stand-alone selling price of capacity and energy. The undiscounted cash flows to be received under outdoor lighting contracts accounted for as operating leases at Alabama Power and Mississippi Power are immaterial.

LEASES

LEASES

On January 1, 2019, the registrants adopted the provisions of FASB ASC Topic 842 (as amended), Leases (ASC 842), which require lessees to recognize leases with a term of greater than 12 months on the balance sheet as lease obligations, representing the discounted future fixed payments due, along with right-of-use (ROU) assets that will be amortized over the term of each lease.

The registrants elected the transition methodology provided by ASC 842, whereby the applicable requirements are applied on a prospective basis as of the adoption date of January 1, 2019, without restating prior periods. The registrants also elected the package of practical expedients provided by ASC 842 that allows prior determinations of whether existing contracts are, or contain, leases and the classification of existing leases to continue without reassessment. Additionally, the registrants applied the use-of-hindsight practical expedient in determining lease terms as of the date of adoption and elected the practical expedient that allows existing land easements not previously accounted for as leases not to be reassessed.

Lessee

As lessee, the registrants lease certain electric generating units (including renewable energy facilities), real estate/land, communication towers, railcars, and other equipment and vehicles. The major categories of lease obligations are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Electric generating units	$	1,094	$	159	$	1,606	$	—	$	—	$	—
Real estate/land	803		3		63		2		393		83
Communication towers	131		1		3		—		—		—
Railcars	55		25		26		3		—		—
Other	153		10		16		3		—		1
Total	$	2,236	$	198	$	1,714	$	8	$	393	$	84

Real estate/land leases primarily consist of commercial real estate leases at Southern Company, Georgia Power, and Southern Company Gas and various land leases primarily associated with renewable energy facilities at Southern Power. The commercial real estate leases have remaining terms of up to 25 years while the land leases have remaining terms of up to 48 years, including renewal periods.

Communication towers are leased for the installation of equipment to provide cellular phone service to customers and to support the automated meter infrastructure programs at the traditional electric operating companies. Communication tower leases have terms of up to 10 years with options to renew for periods up to 20 years.

While renewal options exist in many of the leases, other than for land leases associated with renewable energy facilities, the expected term used in calculating the lease obligation generally reflects only the noncancelable period of the lease as it is not considered reasonably certain that the lease will be extended. The expected term of land leases associated with renewable energy facilities includes renewal periods reasonably certain of exercise resulting in an expected lease term at least equal to the expected life of the renewable energy facilities.

Contracts that Contain a Lease

While not specifically structured as a lease, some of the PPAs at Alabama Power and Georgia Power are deemed to represent a lease of the underlying electric generating units when the terms of the PPA convey the right to control the use of the underlying assets. Amounts recorded for leases of electric generating units are generally based on the amount of scheduled capacity payments due over the remaining term of the affiliate PPA, which varies between four and 18 years. Georgia Power has several PPAs with Southern Power that Georgia Power accounts for as leases with a lease obligation of approximately $670 million at March 31, 2019. The amount paid for energy under these affiliate PPAs reflects a price that would be paid in an arm's-length transaction as those amounts have been reviewed and approved by the Georgia PSC.

Short-term Leases

Leases with an initial term of 12 months or less are not recorded on the balance sheet; the registrants generally recognize lease expense for these leases on a straight-line basis over the lease term.

Residual Value Guarantees

Residual value guarantees exist primarily in railcar leases at Alabama Power and Georgia Power and the amounts probable of being paid under those guarantees are included in the lease payments. All such amounts are immaterial as of March 31, 2019.

Lease and Nonlease Components

For all asset categories, with the exception of electric generating units, gas pipelines, and real estate leases, the registrants combine lease payments and any nonlease components, such as asset maintenance, for purposes of calculating the lease obligation and the right-of-use asset.

Balance sheet amounts recorded for operating and finance leases are as follows:

	As of March 31, 2019
	Southern  Company(*)		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Operating Leases
Operating lease ROU assets, net	$	1,926	$	160	$	1,519	$	8	$	372	$	86
Operating lease obligations - current	$	239	$	47	$	139	$	3	$	22	$	13
Operating lease obligations - non current	1,752		147		1,404		5		371		71
Total operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance Leases
Finance lease ROU assets, net	$	242	$	4	$	145	$	—	$	—	$	—
Finance lease obligations - current	$	38	$	1	$	10	$	—	$	—	$	—
Finance lease obligations - noncurrent	207		3		161		—		—		—
Total finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

(*) Includes operating lease ROU assets, net and operating lease obligations classified as held for sale.

Lease costs for the three months ended March 31, 2019, which includes both amounts recognized as operations and maintenance expense and amounts capitalized as part of the cost of another asset, are as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease cost
Operating lease cost	$	69	$	7	$	49	$	1	$	7	$	4
Finance lease cost:
Amortization of ROU assets	7		—		4		—		—		—
Interest on lease obligations	3		—		4		—		—		—
Total finance lease cost	10		—		8		—		—		—
Short-term lease costs	14		5		3		—		—		—
Variable lease cost	19		—		16		—		1		—
Sublease income	—		—		—		—		—		—
Total lease cost	$	112	$	12	$	76	$	1	$	8	$	4

Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities subject to PPAs.

Other information with respect to cash and noncash activities related to leases, as well as weighted-average lease terms and discount rates, is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Other information
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$	74	$	13	$	32	$	1	$	7	$	4
Operating cash flows from finance leases	6		—		13		—		—		—
Financing cash flows from finance leases	8		—		2		—		—		—
ROU assets obtained in exchange for new operating lease obligations	15		2		4		—		—		—
ROU assets obtained in exchange for new finance lease obligations	29		—		28		—		—		—

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
Weighted-average remaining lease term in years:
Operating leases	13.5		3.8		10.1		6.8		33.7		9.0
Finance leases	18.5		14.8		11.3		—		—		—
Weighted-average discount rate:
Operating leases	4.49	%	3.33	%	4.42	%	4.03	%	5.68	%	3.70	%
Finance leases	5.00	%	3.75	%	10.68	%	—	%	—	%	—	%

Maturities of lease liabilities are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Maturity Analysis
Operating leases:
2019 (remaining)	$	253	$	46	$	182	$	2	$	17	$	12
2020	291		53		202		2		22		16
2021	274		52		197		1		23		16
2022	263		52		195		1		23		12
2023	198		3		196		1		24		10
Thereafter	1,637		1		984		2		848		36
Total	2,916		207		1,956		9		957		102
Less: Present value discount	925		13		413		1		564		18
Operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance leases:
2019 (remaining)	$	24	$	1	$	22	$	—	$	—	$	—
2020	32		1		28		—		—		—
2021	26		1		25		—		—		—
2022	22		1		25		—		—		—
2023	18		1		25		—		—		—
Thereafter	273		—		165		—		—		—
Total	395		5		290		—		—		—
Less: Present value discount	150		1		119		—		—		—
Finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

Payments made under PPAs at Georgia Power for energy generated from certain renewable energy facilities accounted for as operating and finance leases are considered variable lease costs and are therefore not reflected in the above maturity analysis. As of March 31, 2019, Southern Company and Southern Power have additional operating leases, primarily for land, that have not yet commenced. These operating leases are expected to commence during the remainder of 2019 through 2021, with lease terms of up to 30 years, and have estimated total obligations of $77 million.

For additional information on each registrant's operating lease obligations at December 31, 2018, see Note 9 to the financial statements in Item 8 of the Form 10-K.

Lessor

With the exception of Southern Company Gas, the registrants are each considered lessors in various arrangements that have been determined to contain a lease due to the customer's ability to control the use of the underlying asset owned by the applicable registrant. For the traditional electric operating companies, these arrangements consist of outdoor lighting contracts accounted for as operating leases with initial terms of up to five years, after which the contracts renew on a month-to-month basis at the customer's option. For Mississippi Power, these arrangements also include tolling arrangements related to electric generating units accounted for as sales-type leases with terms of up to 20 years. For Southern Power, these arrangements consist of PPAs related to electric generating units, including renewable energy facilities, accounted for as operating leases with terms of up to 28 years. For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as operating leases with terms of up to 15 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with remaining terms of up to 24 years.

Lease income for the three months ended March 31, 2019 is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease income - interest income on sales-type leases	$	2	$	—	$	2	$	—	$	—
Lease income - operating leases	71		19		—		41		9
Variable lease income	66		—		—		72		—
Total lease income	$	139	$	19	$	2	$	113	$	9

No profit or loss was recognized by Mississippi Power upon commencement of a sales-type lease during the first quarter 2019.

Lease income for Southern Power is included in wholesale revenues. 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. Scheduled payments to be received under outdoor lighting contracts, tolling arrangements, and PPAs accounted for as leases are presented in the following maturity analyses.

The undiscounted cash flows to be received under tolling arrangements accounted for as sales-type leases are as follows:

	As of March 31, 2019
	Southern Company		Mississippi Power
	(in millions)
2019 (remaining)	$	11	$	11
2020	14		14
2021	14		14
2022	13		13
2023	12		12
Thereafter	135		135
Total undiscounted cash flows	$	199	$	199
Lease receivable	108		108
Difference between undiscounted cash flows and discounted cash flows	$	91	$	91

The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases (adjusted for intercompany eliminations) are as follows:

	As of March 31, 2019
	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
2019 (remaining)	$	163	$	20	$	123	$	26
2020	188		26		128		34
2021	183		18		131		34
2022	174		8		134		34
2023	171		2		137		34
Thereafter	1,809		—		1,017		498
Total	$	2,688	$	74	$	1,670	$	660

Southern Power receives payments for renewable energy under PPAs accounted for as operating leases that are considered contingent rents and are therefore not reflected in the table above. Southern Power allocates revenue to the nonlease components of PPAs based on the stand-alone selling price of capacity and energy. The undiscounted cash flows to be received under outdoor lighting contracts accounted for as operating leases at Alabama Power and Mississippi Power are immaterial.

LEASES

LEASES

On January 1, 2019, the registrants adopted the provisions of FASB ASC Topic 842 (as amended), Leases (ASC 842), which require lessees to recognize leases with a term of greater than 12 months on the balance sheet as lease obligations, representing the discounted future fixed payments due, along with right-of-use (ROU) assets that will be amortized over the term of each lease.

The registrants elected the transition methodology provided by ASC 842, whereby the applicable requirements are applied on a prospective basis as of the adoption date of January 1, 2019, without restating prior periods. The registrants also elected the package of practical expedients provided by ASC 842 that allows prior determinations of whether existing contracts are, or contain, leases and the classification of existing leases to continue without reassessment. Additionally, the registrants applied the use-of-hindsight practical expedient in determining lease terms as of the date of adoption and elected the practical expedient that allows existing land easements not previously accounted for as leases not to be reassessed.

Lessee

As lessee, the registrants lease certain electric generating units (including renewable energy facilities), real estate/land, communication towers, railcars, and other equipment and vehicles. The major categories of lease obligations are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Electric generating units	$	1,094	$	159	$	1,606	$	—	$	—	$	—
Real estate/land	803		3		63		2		393		83
Communication towers	131		1		3		—		—		—
Railcars	55		25		26		3		—		—
Other	153		10		16		3		—		1
Total	$	2,236	$	198	$	1,714	$	8	$	393	$	84

Real estate/land leases primarily consist of commercial real estate leases at Southern Company, Georgia Power, and Southern Company Gas and various land leases primarily associated with renewable energy facilities at Southern Power. The commercial real estate leases have remaining terms of up to 25 years while the land leases have remaining terms of up to 48 years, including renewal periods.

Communication towers are leased for the installation of equipment to provide cellular phone service to customers and to support the automated meter infrastructure programs at the traditional electric operating companies. Communication tower leases have terms of up to 10 years with options to renew for periods up to 20 years.

While renewal options exist in many of the leases, other than for land leases associated with renewable energy facilities, the expected term used in calculating the lease obligation generally reflects only the noncancelable period of the lease as it is not considered reasonably certain that the lease will be extended. The expected term of land leases associated with renewable energy facilities includes renewal periods reasonably certain of exercise resulting in an expected lease term at least equal to the expected life of the renewable energy facilities.

Contracts that Contain a Lease

While not specifically structured as a lease, some of the PPAs at Alabama Power and Georgia Power are deemed to represent a lease of the underlying electric generating units when the terms of the PPA convey the right to control the use of the underlying assets. Amounts recorded for leases of electric generating units are generally based on the amount of scheduled capacity payments due over the remaining term of the affiliate PPA, which varies between four and 18 years. Georgia Power has several PPAs with Southern Power that Georgia Power accounts for as leases with a lease obligation of approximately $670 million at March 31, 2019. The amount paid for energy under these affiliate PPAs reflects a price that would be paid in an arm's-length transaction as those amounts have been reviewed and approved by the Georgia PSC.

Short-term Leases

Leases with an initial term of 12 months or less are not recorded on the balance sheet; the registrants generally recognize lease expense for these leases on a straight-line basis over the lease term.

Residual Value Guarantees

Residual value guarantees exist primarily in railcar leases at Alabama Power and Georgia Power and the amounts probable of being paid under those guarantees are included in the lease payments. All such amounts are immaterial as of March 31, 2019.

Lease and Nonlease Components

For all asset categories, with the exception of electric generating units, gas pipelines, and real estate leases, the registrants combine lease payments and any nonlease components, such as asset maintenance, for purposes of calculating the lease obligation and the right-of-use asset.

Balance sheet amounts recorded for operating and finance leases are as follows:

	As of March 31, 2019
	Southern  Company(*)		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Operating Leases
Operating lease ROU assets, net	$	1,926	$	160	$	1,519	$	8	$	372	$	86
Operating lease obligations - current	$	239	$	47	$	139	$	3	$	22	$	13
Operating lease obligations - non current	1,752		147		1,404		5		371		71
Total operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance Leases
Finance lease ROU assets, net	$	242	$	4	$	145	$	—	$	—	$	—
Finance lease obligations - current	$	38	$	1	$	10	$	—	$	—	$	—
Finance lease obligations - noncurrent	207		3		161		—		—		—
Total finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

(*) Includes operating lease ROU assets, net and operating lease obligations classified as held for sale.

Lease costs for the three months ended March 31, 2019, which includes both amounts recognized as operations and maintenance expense and amounts capitalized as part of the cost of another asset, are as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease cost
Operating lease cost	$	69	$	7	$	49	$	1	$	7	$	4
Finance lease cost:
Amortization of ROU assets	7		—		4		—		—		—
Interest on lease obligations	3		—		4		—		—		—
Total finance lease cost	10		—		8		—		—		—
Short-term lease costs	14		5		3		—		—		—
Variable lease cost	19		—		16		—		1		—
Sublease income	—		—		—		—		—		—
Total lease cost	$	112	$	12	$	76	$	1	$	8	$	4

Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities subject to PPAs.

Other information with respect to cash and noncash activities related to leases, as well as weighted-average lease terms and discount rates, is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Other information
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$	74	$	13	$	32	$	1	$	7	$	4
Operating cash flows from finance leases	6		—		13		—		—		—
Financing cash flows from finance leases	8		—		2		—		—		—
ROU assets obtained in exchange for new operating lease obligations	15		2		4		—		—		—
ROU assets obtained in exchange for new finance lease obligations	29		—		28		—		—		—

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
Weighted-average remaining lease term in years:
Operating leases	13.5		3.8		10.1		6.8		33.7		9.0
Finance leases	18.5		14.8		11.3		—		—		—
Weighted-average discount rate:
Operating leases	4.49	%	3.33	%	4.42	%	4.03	%	5.68	%	3.70	%
Finance leases	5.00	%	3.75	%	10.68	%	—	%	—	%	—	%

Maturities of lease liabilities are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Maturity Analysis
Operating leases:
2019 (remaining)	$	253	$	46	$	182	$	2	$	17	$	12
2020	291		53		202		2		22		16
2021	274		52		197		1		23		16
2022	263		52		195		1		23		12
2023	198		3		196		1		24		10
Thereafter	1,637		1		984		2		848		36
Total	2,916		207		1,956		9		957		102
Less: Present value discount	925		13		413		1		564		18
Operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance leases:
2019 (remaining)	$	24	$	1	$	22	$	—	$	—	$	—
2020	32		1		28		—		—		—
2021	26		1		25		—		—		—
2022	22		1		25		—		—		—
2023	18		1		25		—		—		—
Thereafter	273		—		165		—		—		—
Total	395		5		290		—		—		—
Less: Present value discount	150		1		119		—		—		—
Finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

Payments made under PPAs at Georgia Power for energy generated from certain renewable energy facilities accounted for as operating and finance leases are considered variable lease costs and are therefore not reflected in the above maturity analysis. As of March 31, 2019, Southern Company and Southern Power have additional operating leases, primarily for land, that have not yet commenced. These operating leases are expected to commence during the remainder of 2019 through 2021, with lease terms of up to 30 years, and have estimated total obligations of $77 million.

For additional information on each registrant's operating lease obligations at December 31, 2018, see Note 9 to the financial statements in Item 8 of the Form 10-K.

Lessor

With the exception of Southern Company Gas, the registrants are each considered lessors in various arrangements that have been determined to contain a lease due to the customer's ability to control the use of the underlying asset owned by the applicable registrant. For the traditional electric operating companies, these arrangements consist of outdoor lighting contracts accounted for as operating leases with initial terms of up to five years, after which the contracts renew on a month-to-month basis at the customer's option. For Mississippi Power, these arrangements also include tolling arrangements related to electric generating units accounted for as sales-type leases with terms of up to 20 years. For Southern Power, these arrangements consist of PPAs related to electric generating units, including renewable energy facilities, accounted for as operating leases with terms of up to 28 years. For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as operating leases with terms of up to 15 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with remaining terms of up to 24 years.

Lease income for the three months ended March 31, 2019 is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease income - interest income on sales-type leases	$	2	$	—	$	2	$	—	$	—
Lease income - operating leases	71		19		—		41		9
Variable lease income	66		—		—		72		—
Total lease income	$	139	$	19	$	2	$	113	$	9

No profit or loss was recognized by Mississippi Power upon commencement of a sales-type lease during the first quarter 2019.

Lease income for Southern Power is included in wholesale revenues. 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. Scheduled payments to be received under outdoor lighting contracts, tolling arrangements, and PPAs accounted for as leases are presented in the following maturity analyses.

The undiscounted cash flows to be received under tolling arrangements accounted for as sales-type leases are as follows:

	As of March 31, 2019
	Southern Company		Mississippi Power
	(in millions)
2019 (remaining)	$	11	$	11
2020	14		14
2021	14		14
2022	13		13
2023	12		12
Thereafter	135		135
Total undiscounted cash flows	$	199	$	199
Lease receivable	108		108
Difference between undiscounted cash flows and discounted cash flows	$	91	$	91

The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases (adjusted for intercompany eliminations) are as follows:

	As of March 31, 2019
	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
2019 (remaining)	$	163	$	20	$	123	$	26
2020	188		26		128		34
2021	183		18		131		34
2022	174		8		134		34
2023	171		2		137		34
Thereafter	1,809		—		1,017		498
Total	$	2,688	$	74	$	1,670	$	660

Southern Power receives payments for renewable energy under PPAs accounted for as operating leases that are considered contingent rents and are therefore not reflected in the table above. Southern Power allocates revenue to the nonlease components of PPAs based on the stand-alone selling price of capacity and energy. The undiscounted cash flows to be received under outdoor lighting contracts accounted for as operating leases at Alabama Power and Mississippi Power are immaterial.

LEASES

LEASES

On January 1, 2019, the registrants adopted the provisions of FASB ASC Topic 842 (as amended), Leases (ASC 842), which require lessees to recognize leases with a term of greater than 12 months on the balance sheet as lease obligations, representing the discounted future fixed payments due, along with right-of-use (ROU) assets that will be amortized over the term of each lease.

The registrants elected the transition methodology provided by ASC 842, whereby the applicable requirements are applied on a prospective basis as of the adoption date of January 1, 2019, without restating prior periods. The registrants also elected the package of practical expedients provided by ASC 842 that allows prior determinations of whether existing contracts are, or contain, leases and the classification of existing leases to continue without reassessment. Additionally, the registrants applied the use-of-hindsight practical expedient in determining lease terms as of the date of adoption and elected the practical expedient that allows existing land easements not previously accounted for as leases not to be reassessed.

Lessee

As lessee, the registrants lease certain electric generating units (including renewable energy facilities), real estate/land, communication towers, railcars, and other equipment and vehicles. The major categories of lease obligations are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Electric generating units	$	1,094	$	159	$	1,606	$	—	$	—	$	—
Real estate/land	803		3		63		2		393		83
Communication towers	131		1		3		—		—		—
Railcars	55		25		26		3		—		—
Other	153		10		16		3		—		1
Total	$	2,236	$	198	$	1,714	$	8	$	393	$	84

Real estate/land leases primarily consist of commercial real estate leases at Southern Company, Georgia Power, and Southern Company Gas and various land leases primarily associated with renewable energy facilities at Southern Power. The commercial real estate leases have remaining terms of up to 25 years while the land leases have remaining terms of up to 48 years, including renewal periods.

Communication towers are leased for the installation of equipment to provide cellular phone service to customers and to support the automated meter infrastructure programs at the traditional electric operating companies. Communication tower leases have terms of up to 10 years with options to renew for periods up to 20 years.

While renewal options exist in many of the leases, other than for land leases associated with renewable energy facilities, the expected term used in calculating the lease obligation generally reflects only the noncancelable period of the lease as it is not considered reasonably certain that the lease will be extended. The expected term of land leases associated with renewable energy facilities includes renewal periods reasonably certain of exercise resulting in an expected lease term at least equal to the expected life of the renewable energy facilities.

Contracts that Contain a Lease

While not specifically structured as a lease, some of the PPAs at Alabama Power and Georgia Power are deemed to represent a lease of the underlying electric generating units when the terms of the PPA convey the right to control the use of the underlying assets. Amounts recorded for leases of electric generating units are generally based on the amount of scheduled capacity payments due over the remaining term of the affiliate PPA, which varies between four and 18 years. Georgia Power has several PPAs with Southern Power that Georgia Power accounts for as leases with a lease obligation of approximately $670 million at March 31, 2019. The amount paid for energy under these affiliate PPAs reflects a price that would be paid in an arm's-length transaction as those amounts have been reviewed and approved by the Georgia PSC.

Short-term Leases

Leases with an initial term of 12 months or less are not recorded on the balance sheet; the registrants generally recognize lease expense for these leases on a straight-line basis over the lease term.

Residual Value Guarantees

Residual value guarantees exist primarily in railcar leases at Alabama Power and Georgia Power and the amounts probable of being paid under those guarantees are included in the lease payments. All such amounts are immaterial as of March 31, 2019.

Lease and Nonlease Components

For all asset categories, with the exception of electric generating units, gas pipelines, and real estate leases, the registrants combine lease payments and any nonlease components, such as asset maintenance, for purposes of calculating the lease obligation and the right-of-use asset.

Balance sheet amounts recorded for operating and finance leases are as follows:

	As of March 31, 2019
	Southern  Company(*)		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Operating Leases
Operating lease ROU assets, net	$	1,926	$	160	$	1,519	$	8	$	372	$	86
Operating lease obligations - current	$	239	$	47	$	139	$	3	$	22	$	13
Operating lease obligations - non current	1,752		147		1,404		5		371		71
Total operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance Leases
Finance lease ROU assets, net	$	242	$	4	$	145	$	—	$	—	$	—
Finance lease obligations - current	$	38	$	1	$	10	$	—	$	—	$	—
Finance lease obligations - noncurrent	207		3		161		—		—		—
Total finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

(*) Includes operating lease ROU assets, net and operating lease obligations classified as held for sale.

Lease costs for the three months ended March 31, 2019, which includes both amounts recognized as operations and maintenance expense and amounts capitalized as part of the cost of another asset, are as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease cost
Operating lease cost	$	69	$	7	$	49	$	1	$	7	$	4
Finance lease cost:
Amortization of ROU assets	7		—		4		—		—		—
Interest on lease obligations	3		—		4		—		—		—
Total finance lease cost	10		—		8		—		—		—
Short-term lease costs	14		5		3		—		—		—
Variable lease cost	19		—		16		—		1		—
Sublease income	—		—		—		—		—		—
Total lease cost	$	112	$	12	$	76	$	1	$	8	$	4

Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities subject to PPAs.

Other information with respect to cash and noncash activities related to leases, as well as weighted-average lease terms and discount rates, is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Other information
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$	74	$	13	$	32	$	1	$	7	$	4
Operating cash flows from finance leases	6		—		13		—		—		—
Financing cash flows from finance leases	8		—		2		—		—		—
ROU assets obtained in exchange for new operating lease obligations	15		2		4		—		—		—
ROU assets obtained in exchange for new finance lease obligations	29		—		28		—		—		—

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
Weighted-average remaining lease term in years:
Operating leases	13.5		3.8		10.1		6.8		33.7		9.0
Finance leases	18.5		14.8		11.3		—		—		—
Weighted-average discount rate:
Operating leases	4.49	%	3.33	%	4.42	%	4.03	%	5.68	%	3.70	%
Finance leases	5.00	%	3.75	%	10.68	%	—	%	—	%	—	%

Maturities of lease liabilities are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Maturity Analysis
Operating leases:
2019 (remaining)	$	253	$	46	$	182	$	2	$	17	$	12
2020	291		53		202		2		22		16
2021	274		52		197		1		23		16
2022	263		52		195		1		23		12
2023	198		3		196		1		24		10
Thereafter	1,637		1		984		2		848		36
Total	2,916		207		1,956		9		957		102
Less: Present value discount	925		13		413		1		564		18
Operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance leases:
2019 (remaining)	$	24	$	1	$	22	$	—	$	—	$	—
2020	32		1		28		—		—		—
2021	26		1		25		—		—		—
2022	22		1		25		—		—		—
2023	18		1		25		—		—		—
Thereafter	273		—		165		—		—		—
Total	395		5		290		—		—		—
Less: Present value discount	150		1		119		—		—		—
Finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

Payments made under PPAs at Georgia Power for energy generated from certain renewable energy facilities accounted for as operating and finance leases are considered variable lease costs and are therefore not reflected in the above maturity analysis. As of March 31, 2019, Southern Company and Southern Power have additional operating leases, primarily for land, that have not yet commenced. These operating leases are expected to commence during the remainder of 2019 through 2021, with lease terms of up to 30 years, and have estimated total obligations of $77 million.

For additional information on each registrant's operating lease obligations at December 31, 2018, see Note 9 to the financial statements in Item 8 of the Form 10-K.

Lessor

With the exception of Southern Company Gas, the registrants are each considered lessors in various arrangements that have been determined to contain a lease due to the customer's ability to control the use of the underlying asset owned by the applicable registrant. For the traditional electric operating companies, these arrangements consist of outdoor lighting contracts accounted for as operating leases with initial terms of up to five years, after which the contracts renew on a month-to-month basis at the customer's option. For Mississippi Power, these arrangements also include tolling arrangements related to electric generating units accounted for as sales-type leases with terms of up to 20 years. For Southern Power, these arrangements consist of PPAs related to electric generating units, including renewable energy facilities, accounted for as operating leases with terms of up to 28 years. For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as operating leases with terms of up to 15 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with remaining terms of up to 24 years.

Lease income for the three months ended March 31, 2019 is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease income - interest income on sales-type leases	$	2	$	—	$	2	$	—	$	—
Lease income - operating leases	71		19		—		41		9
Variable lease income	66		—		—		72		—
Total lease income	$	139	$	19	$	2	$	113	$	9

No profit or loss was recognized by Mississippi Power upon commencement of a sales-type lease during the first quarter 2019.

Lease income for Southern Power is included in wholesale revenues. 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. Scheduled payments to be received under outdoor lighting contracts, tolling arrangements, and PPAs accounted for as leases are presented in the following maturity analyses.

The undiscounted cash flows to be received under tolling arrangements accounted for as sales-type leases are as follows:

	As of March 31, 2019
	Southern Company		Mississippi Power
	(in millions)
2019 (remaining)	$	11	$	11
2020	14		14
2021	14		14
2022	13		13
2023	12		12
Thereafter	135		135
Total undiscounted cash flows	$	199	$	199
Lease receivable	108		108
Difference between undiscounted cash flows and discounted cash flows	$	91	$	91

The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases (adjusted for intercompany eliminations) are as follows:

	As of March 31, 2019
	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
2019 (remaining)	$	163	$	20	$	123	$	26
2020	188		26		128		34
2021	183		18		131		34
2022	174		8		134		34
2023	171		2		137		34
Thereafter	1,809		—		1,017		498
Total	$	2,688	$	74	$	1,670	$	660

Southern Power receives payments for renewable energy under PPAs accounted for as operating leases that are considered contingent rents and are therefore not reflected in the table above. Southern Power allocates revenue to the nonlease components of PPAs based on the stand-alone selling price of capacity and energy. The undiscounted cash flows to be received under outdoor lighting contracts accounted for as operating leases at Alabama Power and Mississippi Power are immaterial.

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Segment and Related Information

3 Months Ended

Mar. 31, 2019

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 – Alabama Power, Georgia Power, and Mississippi Power – 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 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, wholesale gas services, 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 $87 million for the three months ended March 31, 2019 and $83 million for the three months ended March 31, 2018. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for each of the three months ended March 31, 2019 and 2018. Revenues from sales of natural gas from Southern Company Gas to Southern Power were $17 million for the three months ended March 31, 2019 and $36 million for the three months ended March 31, 2018. 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 energy technologies and services to electric utilities and large industrial, commercial, institutional, and municipal customers, as well as investments in telecommunications and 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, 2019 and 2018 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, 2019:
Operating revenues	$	3,445	$	443	$	(93	)	$	3,795	$	1,474	$	182		$	(39	)	$	5,412
Segment net income (loss)(a)(b)(c)	565		56		—			621		270		1,195			(2		)	2,084
At March 31, 2019:
Goodwill	$	—	$	2	$	—		$	2	$	5,015	$	268		$	(1	)	$	5,284
Total assets	76,798		15,104		(779		)	91,123		20,952		3,391			(1,370		)	114,096
Three Months Ended March 31, 2018:
Operating revenues	$	3,979	$	509	$	(106	)	$	4,382	$	1,639	$	401		$	(50	)	$	6,372
Segment net income (loss)(a)(b)(d)	612		121		—			733		279		(74		)	—			938
At December 31, 2018:
Goodwill	$	—	$	2	$	—		$	2	$	5,015	$	298		$	—		$	5,315
Total assets	79,382		14,883		(306		)	93,959		21,448		3,285			(1,778		)	116,914

(a) Attributable to Southern Company.

(b) Segment net income (loss) for the traditional electric operating companies includes pre-tax charges for estimated losses on plants under construction of $2 million ($1 million after tax) and $44 million ($33 million after tax) for the three months ended March 31, 2019 and 2018, respectively. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) under "Mississippi Power – Kemper County Energy Facility" for additional information.

(c) Segment net income (loss) for the "All Other" column includes the preliminary pre-tax gain associated with the sale of Gulf Power of $2.5 billion ($1.3 billion after tax) for the three months ended March 31, 2019. See Note (K) under "Southern Company" for additional information.

(d) Segment net income (loss) for Southern Company Gas includes a goodwill impairment charge of $42 million for the three months ended March 31, 2018 related to the sale of Pivotal Home Solutions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2019	$	3,084	$	499	$	212	$	3,795
Three Months Ended March 31, 2018	3,568		623		191		4,382

	Southern Company Gas' Revenues
	Gas Distribution Operations(a)		Gas Marketing Services(b)		Other		Total
	(in millions)
Three Months Ended March 31, 2019	$	1,161	$	229	$	84	$	1,474
Three Months Ended March 31, 2018	1,200		271		168		1,639

(a) Operating revenues for the three gas distribution operations dispositions were $167 million for the three months ended March 31, 2018.

(b) Operating revenues for Pivotal Home Solutions were $32 million for the three months ended March 31, 2018.

Southern Company Gas

Southern Company Gas manages its business through four reportable segments – gas distribution operations, gas pipeline investments, wholesale gas services, 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, two significant pipeline construction projects, 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.

Wholesale gas services provides natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engages in natural gas storage and gas pipeline arbitrage and related activities.

Gas marketing services provides natural gas marketing to end-use customers primarily in Georgia and Illinois through SouthStar Energy Services, LLC.

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

Business segment financial data for the three months ended March 31, 2019 and 2018 was as follows:

	Gas Distribution Operations(a)		Gas Pipeline Investments		Wholesale Gas Services(b)		Gas Marketing Services(c)(d)		Total		All Other			Eliminations			Consolidated
	(in millions)
Three Months Ended March 31, 2019:
Operating revenues	$	1,172	$	8	$	86	$	229	$	1,495	$	11		$	(32	)	$	1,474
Segment net income (loss)	133		32		47		61		273		(3		)	—			270
Total assets at March 31, 2019:	17,379		1,781		821		1,611		21,592		10,900			(11,540		)	20,952
Three Months Ended March 31, 2018:
Operating revenues	$	1,212	$	8	$	166	$	271	$	1,657	$	15		$	(33	)	$	1,639
Segment net income (loss)	149		27		104		13		293		(14		)	—			279
Total assets at December 31, 2018:	17,266		1,763		1,302		1,587		21,918		11,112			(11,582		)	$	21,448

(a) Operating revenues for the three gas distribution operations dispositions were $167 million for the three months ended March 31, 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

(b) The revenues for wholesale gas services are netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended March 31, 2019	$	1,926	$	88	$	2,014	$	1,928	$	86
Three Months Ended March 31, 2018	1,938		167		2,105		1,939		166

(c) Operating revenues for the gas marketing services disposition were $32 million for the three months ended March 31, 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

(d) Segment net income (loss) for gas marketing services includes a goodwill impairment charge of $42 million for the three months ended March 31, 2018 related to the sale of Pivotal Home Solutions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

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Introduction (Policies)

3 Months Ended

Mar. 31, 2019

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 as of December 31, 2018 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, 2019 and 2018. 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, 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 results of operations, financial position, or cash flows of any registrant.

Recently Adopted Accounting Standards

In 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (ASU 2016-02). ASU 2016-02 requires lessees to recognize on the balance sheet a lease liability and a right-of-use asset for all leases. ASU 2016-02 also changes the recognition, measurement, and presentation of expense associated with leases and provides clarification regarding the identification of certain components of contracts that would represent a lease. The accounting required by lessors is relatively unchanged and there is no change to the accounting for existing leveraged leases. The registrants adopted the new standard effective January 1, 2019. See Note (L) for additional information and related disclosures.

Goodwill and Other Intangible Assets

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.

Restricted Cash

At December 31, 2018, Georgia Power had restricted cash related to the redemption of pollution control revenue bonds, which were redeemed in January 2019. See Note (F) under "Financing Activities" for additional information. At both March 31, 2019 and December 31, 2018, Southern Company Gas had restricted cash held as collateral for worker's compensation, life insurance, and long-term disability insurance.

Natural Gas For Sale

Southern Company Gas, with the exception of Nicor Gas, carries natural gas inventory 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. Southern Company Gas had no material adjustment in any period presented.

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. Nicor Gas' inventory decrement at March 31, 2019 is expected to be restored prior to year end.

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 Southern Power 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 obligation is 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

Interest Rate Derivatives

Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. The derivatives employed as hedging instruments are structured to minimize ineffectiveness. 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. The derivatives employed as hedging instruments are structured to minimize ineffectiveness.

Southern Company, the traditional electric operating companies, Southern Power, and Southern Company Gas 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. Southern Company Gas' wholesale gas operations use various contracts in its commercial activities that generally meet the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with 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 traditional electric operating companies, Southern Power, and Southern Company Gas 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 of operating margins 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 the respective fuel cost recovery clauses.

• 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.

A

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Introduction (Tables)

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Goodwill

Goodwill at March 31, 2019 and December 31, 2018 was as follows:

	At March 31, 2019		At December 31, 2018
	(in millions)
Southern Company	$	5,284	$	5,315
Southern Company Gas:
Gas distribution operations	$	4,034	$	4,034
Gas marketing services	981		981
Southern Company Gas total	$	5,015	$	5,015

Schedule of Other Intangible Assets, Finite-Lived

Other intangible assets were as follows:

	At March 31, 2019							At December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net
	(in millions)							(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	211	$	(100	)	$	111	$	223	$	(94	)	$	129
Trade names	70		(22		)	48		70		(21		)	49
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
PPA fair value adjustments	405		(67		)	338		405		(61		)	344
Other	11		(6		)	5		11		(5		)	6
Total other intangible assets subject to amortization	$	761	$	(251	)	$	510	$	773	$	(235	)	$	538
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—			75		75		—			75
Total other intangible assets	$	836	$	(251	)	$	585	$	848	$	(235	)	$	613
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	405	$	(67	)	$	338	$	405	$	(61	)	$	344
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(89	)	$	67	$	156	$	(84	)	$	72
Trade names	26		(8		)	18		26		(7		)	19
Wholesale gas services
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
Total other intangible assets subject to amortization	$	246	$	(153	)	$	93	$	246	$	(145	)	$	101

Schedule of Other Intangible Assets, Indefinite-Lived

Other intangible assets were as follows:

	At March 31, 2019							At December 31, 2018
	Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization			Other Intangible Assets, Net
	(in millions)							(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	211	$	(100	)	$	111	$	223	$	(94	)	$	129
Trade names	70		(22		)	48		70		(21		)	49
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
PPA fair value adjustments	405		(67		)	338		405		(61		)	344
Other	11		(6		)	5		11		(5		)	6
Total other intangible assets subject to amortization	$	761	$	(251	)	$	510	$	773	$	(235	)	$	538
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—			75		75		—			75
Total other intangible assets	$	836	$	(251	)	$	585	$	848	$	(235	)	$	613
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	405	$	(67	)	$	338	$	405	$	(61	)	$	344
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(89	)	$	67	$	156	$	(84	)	$	72
Trade names	26		(8		)	18		26		(7		)	19
Wholesale gas services
Storage and transportation contracts	64		(56		)	8		64		(54		)	10
Total other intangible assets subject to amortization	$	246	$	(153	)	$	93	$	246	$	(145	)	$	101

Finite-lived Intangible Assets Amortization Expense

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2019
	(in millions)
Southern Company	$	17
Southern Power(a)	$	6
Southern Company Gas
Gas marketing services(b)	$	6
Wholesale gas services(a)	2
Southern Company Gas total	$	8

(a) Recorded as a reduction to operating revenues.

(b) Included in depreciation and amortization.

Schedule of Cash and Cash Equivalents

The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amounts shown in the condensed statements of cash flows for the registrants that had restricted cash at March 31, 2019 and/or December 31, 2018:

	Southern Company			Southern Company Gas
	(in millions)
At March 31, 2019
Cash and cash equivalents	$	1,361		$	57
Restricted cash:
Other accounts and notes receivable	4			4
Total cash, cash equivalents, and restricted cash	$	1,364	(*)	$	61

(*) Total does not add due to rounding.

	Southern Company		Georgia Power		Southern Company Gas
	(in millions)
At December 31, 2018
Cash and cash equivalents	$	1,396	$	4	$	64
Cash and cash equivalents held for sale	9		—		—
Restricted cash:
Restricted cash	—		108		—
Other accounts and notes receivable	114		—		6
Total cash, cash equivalents, and restricted cash	$	1,519	$	112	$	70

Restrictions on Cash and Cash Equivalents

The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amounts shown in the condensed statements of cash flows for the registrants that had restricted cash at March 31, 2019 and/or December 31, 2018:

	Southern Company			Southern Company Gas
	(in millions)
At March 31, 2019
Cash and cash equivalents	$	1,361		$	57
Restricted cash:
Other accounts and notes receivable	4			4
Total cash, cash equivalents, and restricted cash	$	1,364	(*)	$	61

(*) Total does not add due to rounding.

	Southern Company		Georgia Power		Southern Company Gas
	(in millions)
At December 31, 2018
Cash and cash equivalents	$	1,396	$	4	$	64
Cash and cash equivalents held for sale	9		—		—
Restricted cash:
Restricted cash	—		108		—
Other accounts and notes receivable	114		—		6
Total cash, cash equivalents, and restricted cash	$	1,519	$	112	$	70

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Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Cost Recovery Clauses

The recovery balances for certain of Alabama Power's, Georgia Power's, and Mississippi Power's regulatory clauses at March 31, 2019 and December 31, 2018 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2019		December 31, 2018
		(in millions)
Alabama Power
Rate CNP Compliance	Deferred under recovered regulatory clause revenues	$	—	$	42
	Customer accounts receivable	25		—
Rate CNP PPA	Deferred under recovered regulatory clause revenues	21		25
Retail Energy Cost Recovery(*)	Deferred under recovered regulatory clause revenues	—		109
	Other regulatory liabilities, deferred	2		—
Natural Disaster Reserve	Other regulatory liabilities, deferred	22		20
Georgia Power
Fuel Cost Recovery	Receivables – under recovered fuel clause revenues	$	73	$	115
Mississippi Power
Fuel Cost Recovery	Over recovered retail fuel costs	$	10	$	8

(*) In accordance with an accounting order issued on February 5, 2019 by the Alabama PSC, Alabama Power utilized $75 million of the 2018 Rate RSE refund liability to reduce the Rate ECR under recovered balance. See Note 2 to the financial statements under "Alabama Power – Rate ECR" in Item 8 of the Form 10-K for additional information.

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4 by the expected in-service dates of November 2021 and November 2022, respectively, is as follows:

	(in billions)
Base project capital cost forecast(a)(b)	$	8.0
Construction contingency estimate	0.4
Total project capital cost forecast(a)(b)	8.4
Net investment as of March 31, 2019(b)	(4.9		)
Remaining estimate to complete(a)	$	3.5

(a) Excludes financing costs expected to be capitalized through AFUDC of approximately $325 million.

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

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Revenue from Contracts with Customers (Tables)

3 Months Ended

Mar. 31, 2019

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following tables disaggregate revenue sources for the three months ended March 31, 2019 and 2018:

	For the Three Months Ended March 31, 2019			For the Three Months Ended March 31, 2018
	(in millions)
Southern Company
Operating revenues
Retail electric revenues(a)
Residential	$	1,288		$	1,539
Commercial	1,093			1,243
Industrial	677			756
Other	26			30
Natural gas distribution revenues	1,163			1,224
Alternative revenue programs(b)	(2		)	(24		)
Total retail electric and gas distribution revenues	$	4,245		$	4,768
Wholesale energy revenues(c)(d)	367			472
Wholesale capacity revenues(d)	132			151
Other natural gas revenues(e)(f)	313			407
Other revenues(g)	355			574
Total operating revenues	$	5,412		$	6,372

(a) Retail electric revenues include $8 million and $18 million of revenues accounted for as leases for the three months ended March 31, 2019 and 2018, respectively, and a (net reduction) or net increase of $(103) million and $117 million for the three months ended March 31, 2019 and 2018, respectively, from certain cost recovery mechanisms that are not accounted for as revenue under ASC 606.

(b) Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period.

(c) Wholesale energy revenues include $53 million and $93 million for the three months ended March 31, 2019 and 2018, respectively, of revenues accounted for as derivatives, primarily related to physical energy sales in the wholesale electricity market.

(d) Wholesale energy and wholesale capacity revenues include $66 million and $25 million, respectively, for the three months ended March 31, 2019 and $69 million and $30 million, respectively, for the three months ended March 31, 2018 related to PPAs accounted for as leases.

(e) Other natural gas revenues related to Southern Company Gas' energy and risk management activities are presented net of the related costs of those activities and include gross third-party revenues of $1.9 billion for each of the three months ended March 31, 2019 and 2018, of which $1.2 billion and $1.1 billion, respectively, relates to contracts that are accounted for as derivatives. See Note (M) under "Southern Company Gas" for additional information on the components of wholesale gas services operating revenues.

(f) Other natural gas revenues for the three months ended March 31, 2019 include $9 million of revenues accounted for as leases.

(g) Other revenues include $96 million and $90 million for the three months ended March 31, 2019 and 2018, respectively, of revenues not accounted for under ASC 606, including $31 million and $33 million in 2019 and 2018, respectively, accounted for as leases.

	Alabama Power		Georgia Power		Mississippi Power
	(in millions)
For the Three Months Ended March 31, 2019
Operating revenues
Retail revenues(a)(b)
Residential	$	540	$	688	$	60
Commercial	354		674		65
Industrial	313		289		74
Other	6		17		4
Total retail electric revenues	$	1,213	$	1,668	$	203
Wholesale energy revenues(c)	94		18		78
Wholesale capacity revenues	27		14		1
Other revenues(b)(d)	74		133		5
Total operating revenues	$	1,408	$	1,833	$	287
For the Three Months Ended March 31, 2018
Operating revenues
Retail revenues(a)(b)
Residential	$	570	$	744	$	60
Commercial	371		717		62
Industrial	338		316		70
Other	6		21		2
Total retail electric revenues	$	1,285	$	1,798	$	194
Wholesale energy revenues(c)	101		40		98
Wholesale capacity revenues	24		14		4
Other revenues(b)(d)	63		109		6
Total operating revenues	$	1,473	$	1,961	$	302

(a) Retail revenues at Alabama Power, Georgia Power, and Mississippi Power include a net increase or (net reduction) of $(57) million, $(47) million, and $1 million, respectively, for the three months ended March 31, 2019 and $47 million, $10 million, and $76 million, respectively, for the three months ended March 31, 2018 related to certain cost recovery mechanisms that are not accounted for as revenue under ASC 606.

(b) Retail revenues and other revenues at Georgia Power include $8 million and $11 million, respectively, for the three months ended March 31, 2019 and $18 million and $33 million, respectively, for the three months ended March 31, 2018 of revenues accounted for as leases.

(c) Wholesale energy revenues at Alabama Power, Georgia Power, and Mississippi Power include $3 million, $4 million, and $1 million, respectively, for the three months ended March 31, 2019 and $5 million, $7 million, and $1 million, respectively, for the three months ended March 31, 2018 accounted for as derivatives primarily related to physical energy sales in the wholesale electricity market.

(d) Other revenues at Alabama Power and Georgia Power include $28 million and $31 million, respectively, for the three months ended March 31, 2019 and $25 million and $26 million, respectively, for the three months ended March 31, 2018 of revenues not accounted for under ASC 606.

	For the Three Months Ended March 31, 2019		For the Three Months Ended March 31, 2018
	(in millions)
Southern Power
PPA capacity revenues(a)	$	127	$	138
PPA energy revenues(a)	227		254
Non-PPA revenues(b)	85		115
Other revenues	4		2
Total operating revenues	$	443	$	509

(a) PPA capacity revenues and PPA energy revenues include $41 million and $72 million, respectively, for the three months ended March 31, 2019 and $47 million and $76 million, respectively, for the three months ended March 31, 2018 related to PPAs accounted for as leases.

(b) Non-PPA revenues include $45 million and $79 million for the three months ended March 31, 2019 and 2018, respectively, of revenues from short-term sales related to physical energy sales from uncovered capacity in the wholesale electricity market.

	For the Three Months Ended March 31, 2019			For the Three Months Ended March 31, 2018
	(in millions)
Southern Company Gas
Operating revenues
Natural gas distribution revenues
Residential	$	601		$	660
Commercial	170			192
Transportation	256			277
Industrial	17			17
Other	119			78
Alternative revenue programs(a)	(2		)	(24		)
Total natural gas distribution revenues	$	1,161		$	1,200
Gas pipeline investments(b)	8			8
Wholesale gas services(c)	66			146
Gas marketing services(d)	229			271
Other revenues	10			14
Total operating revenues	$	1,474		$	1,639

(a) Alternative revenue program revenues are presented net of any previously recognized program amounts billed to customers during the same accounting period.

(b) Revenues from gas pipeline investments include $8 million for the three months ended March 31, 2019 accounted for as leases.

(c) Wholesale gas services revenues are presented net of the related costs associated with its energy trading and risk management activities. Operating revenues, as presented, include gross third-party revenues of $1.9 billion for each of the three months ended March 31, 2019 and 2018, of which $1.2 billion and $1.1 billion, respectively, relates to contracts accounted for as derivatives. See Note (M) under "Southern Company Gas" for additional information on the components of wholesale gas services operating revenues.

(d) Gas marketing services includes $6 million and $4 million for the three months ended March 31, 2019 and 2018, respectively, of revenues not accounted for under ASC 606.

Contract with Customer, Asset and Liability and Revenue Recognized

The following table reflects revenue from contracts with customers recognized in the three-month period ended March 31, 2019 included in the contract liability at December 31, 2018:

	Three Months Ended March 31, 2019
	(in millions)
Southern Company	$	17
Southern Power	10

The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers as of March 31, 2019 and December 31, 2018:

	Receivables				Contract Assets				Contract Liabilities
	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018
	(in millions)
Southern Company(*)	$	2,522	$	2,630	$	84	$	102	$	62	$	32
Alabama Power	514		520		1		—		10		12
Georgia Power	668		721		41		58		25		7
Mississippi Power	85		100		—		—		—		—
Southern Power	99		118		—		—		4		11
Southern Company Gas	948		952		—		—		1		2

(*) Includes amounts related to held for sale investments.

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction

Registrants with revenues from contracts with customers related to these performance obligations remaining at March 31, 2019 expect the revenues to be recognized as follows:

	2019 (remaining)		2020		2021		2022		2023		Thereafter
	(in millions)
Southern Company(*)	$	451	$	349	$	315	$	310	$	301	$	2,219
Alabama Power	16		22		27		23		22		140
Georgia Power	30		38		40		30		31		82
Mississippi Power	2		3		1		—		—		—
Southern Power	248		295		270		276		269		2,143

(*) Includes amounts related to held for sale investments.

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Consolidated Entities and Equity Method Investments (Tables)

3 Months Ended

Mar. 31, 2019

Regulated Operations [Abstract]

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments as of March 31, 2019 and December 31, 2018 and related income from those investments for the three-month periods ended March 31, 2019 and 2018 were as follows:

Investment Balance	March 31, 2019		December 31, 2018
	(in millions)
SNG	$	1,262	$	1,261
Atlantic Coast Pipeline	96		83
PennEast Pipeline	75		71
Other	124		123
Total	$	1,557	$	1,538

Selected financial information of SNG for the three months ended March 31, 2019 and 2018 is as follows:

Income Statement Information	Three Months Ended March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
Revenues	$	166	$	160
Operating income	106		99
Net income	84		78

Schedule of Other Nonoperating Income, by Component

Earnings from Equity Method Investments	Three Months Ended March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
SNG	$	42	$	39
Atlantic Coast Pipeline	3		1
PennEast Pipeline	2		1
Other	1		1
Total	$	48	$	42

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Financing (Tables)

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Credit Arrangements by Company

The following table outlines the committed credit arrangements by company as of March 31, 2019:

	Expires
Company	2019		2020		2022		Total		Unused(d)
	(in millions)
Southern Company(a)	$	—	$	—	$	2,000	$	2,000	$	1,999
Alabama Power	33		500		800		1,333		1,333
Georgia Power	—		—		1,750		1,750		1,736
Mississippi Power	100		—		—		100		100
Southern Power(b)	—		—		750		750		741
Southern Company Gas(c)	—		—		1,900		1,900		1,895
Other	30		—		—		30		30
Southern Company Consolidated	$	163	$	500	$	7,200	$	7,863	$	7,834

(a) Represents the Southern Company parent entity.

(b) Does not include Southern Power Company's $120 million continuing letter of credit facility for standby letters of credit expiring in 2021, of which $24 million was unused at March 31, 2019. Southern Power's subsidiaries are not parties to its bank credit arrangement.

(c) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $1.4 billion of this arrangement. Southern Company Gas' committed credit arrangement also includes $500 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to this multi-year credit arrangement, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

(d) Amounts used are for letters of credit.

Schedule of Long-term Debt Financing Activities

The following table outlines the long-term debt financing activities for Southern Company and its subsidiaries for the first three months of 2019:

Company	Senior Note Maturities, Redemptions, and Repurchases		Revenue Bond Issuances and Reofferings of Purchased Bonds		Revenue Bond Maturities, Redemptions, and Repurchases		Other Long-Term Debt Issuances		Other Long-Term Debt Redemptions and Maturities(a)
	(in millions)
Southern Company(b)	$	2,100	$	—	$	—	$	—	$	—
Alabama Power	200		—		—		—		—
Georgia Power	—		343		108		835		2
Mississippi Power	—		43		—		—		—
Other	—		—		—		—		19
Southern Company Consolidated	$	2,300	$	386	$	108	$	835	$	21

(a) Includes reductions in finance lease obligations resulting from cash payments under finance leases.

(b) Represents the Southern Company parent entity.

Shares Used to Compute Diluted Earnings Per Share

Shares used to compute diluted earnings per share were as follows:

	Three Months Ended March 31, 2019	Three Months Ended March 31, 2018
	(in millions)
As reported shares	1,038	1,011
Effect of stock-based compensation	7	5
Diluted shares	1,045	1,016

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Retirement Benefits (Tables)

3 Months Ended

Mar. 31, 2019

Retirement Benefits [Abstract]

Pension Plans and Postretirement Plans

Components of the net periodic benefit costs for the three months ended March 31, 2019 and 2018 are presented in the following tables.

Three Months Ended March 31, 2019	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Power			Southern Company Gas
	(in millions)
Pension Plans
Service cost	$	73		$	17		$	19		$	3		$	2		$	6
Interest cost	123			28			39			6			1			9
Expected return on plan assets	(221		)	(51		)	(73		)	(10		)	(2		)	(15		)
Amortization:
Prior service costs	—			—			—			—			—			(1		)
Regulatory asset	—			—			—			—			—			3
Net (gain)/loss	30			9			11			1			—			1
Net periodic pension cost (income)	$	5		$	3		$	(4	)	$	—		$	1		$	3
Postretirement Benefits
Service cost	$	5		$	1		$	1		$	—		$	—		$	1
Interest cost	17			4			7			1			—			2
Expected return on plan assets	(16		)	(6		)	(6		)	—			—			(2		)
Amortization:
Prior service costs	1			1			—			—			—			—
Regulatory asset	—			—			—			—			—			2
Net (gain)/loss	(1		)	—			—			—			—			(1		)
Net periodic postretirement benefit cost	$	6		$	—		$	2		$	1		$	—		$	2

Three Months Ended March 31, 2018	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Power			Southern Company Gas
	(in millions)
Pension Plans
Service cost	$	90		$	19		$	22		$	4		$	2		$	8
Interest cost	116			25			35			5			1			10
Expected return on plan assets	(236		)	(51		)	(74		)	(10		)	(3		)	(18		)
Amortization:
Prior service costs	1			—			—			—			—			(1		)
Regulatory asset	—			—			—			—			—			3
Net (gain)/loss	53			14			17			3			1			3
Net periodic pension cost (income)	$	24		$	7		$	—		$	2		$	1		$	5
Postretirement Benefits
Service cost	$	6		$	1		$	2		$	—		$	—		$	1
Interest cost	19			4			7			1			—			2
Expected return on plan assets	(17		)	(6		)	(6		)	—			—			(2		)
Amortization:
Prior service costs	2			1			—			—			—			—
Regulatory asset	—			—			—			—			—			1
Net (gain)/loss	3			—			2			—			—			—
Net periodic postretirement benefit cost	$	13		$	—		$	5		$	1		$	—		$	2

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2019

Fair Value Disclosures [Abstract]

Assets and Liabilities Measured at Fair Value on a Recurring Basis

As of March 31, 2019, 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:
As of March 31, 2019:	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)(b)	$	322	$	128	$	4	$	—	$	454
Foreign currency derivatives	—		38		—		—		38
Investments in trusts:(c)(d)
Domestic equity	682		120		—		—		802
Foreign equity	60		195		—		—		255
U.S. Treasury and government agency securities	—		283		—		—		283
Municipal bonds	—		73		—		—		73
Pooled funds – fixed income	—		14		—		—		14
Corporate bonds	24		298		—		—		322
Mortgage and asset backed securities	—		72		—		—		72
Private equity	—		—		—		48		48
Cash and cash equivalents	1		—		—		—		1
Other	28		4		—		—		32
Cash equivalents	907		3		—		—		910
Other investments	9		14		—		—		23
Total	$	2,033	$	1,242	$	4	$	48	$	3,327
Liabilities:
Energy-related derivatives(a)(b)	$	466	$	106	$	23	$	—	$	595
Interest rate derivatives	—		35		—		—		35
Foreign currency derivatives	—		24		—		—		24
Contingent consideration	—		—		21		—		21
Total	$	466	$	165	$	44	$	—	$	675

	Fair Value Measurements Using:
As of March 31, 2019:	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	$	—	$	6	$	—	$	—	$	6
Nuclear decommissioning trusts:(c)
Domestic equity	446		108		—		—		554
Foreign equity	60		57		—		—		117
U.S. Treasury and government agency securities	—		18		—		—		18
Municipal bonds	—		1		—		—		1
Corporate bonds	24		139		—		—		163
Mortgage and asset backed securities	—		24		—		—		24
Private equity	—		—		—		48		48
Other	5		—		—		—		5
Cash equivalents	569		3		—		—		572
Other investments	—		14		—		—		14
Total	$	1,104	$	370	$	—	$	48	$	1,522
Liabilities:
Energy-related derivatives	$	—	$	7	$	—	$	—	$	7
Georgia Power
Assets:
Energy-related derivatives	$	—	$	9	$	—	$	—	$	9
Nuclear decommissioning trusts:(c)(d)
Domestic equity	236		1		—		—		237
Foreign equity	—		134		—		—		134
U.S. Treasury and government agency securities	—		265		—		—		265
Municipal bonds	—		72		—		—		72
Corporate bonds	—		160		—		—		160
Mortgage and asset backed securities	—		47		—		—		47
Other	23		4		—		—		27
Total	$	259	$	692	$	—	$	—	$	951
Liabilities:
Energy-related derivatives	$	—	$	16	$	—	$	—	$	16
Interest rate derivatives	—		2		—		—		2
Total	$	—	$	18	$	—	$	—	$	18

	Fair Value Measurements Using:
As of March 31, 2019:	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	$	—	$	3	$	—	$	—	$	3
Cash equivalents	202		—		—		—		202
Total	$	202	$	3	$	—	$	—	$	205
Liabilities:
Energy-related derivatives	$	—	$	6	$	—	$	—	$	6
Southern Power
Assets:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1
Foreign currency derivatives	—		38		—		—		38
Cash equivalents	10		—		—		—		10
Total	$	10	$	39	$	—	$	—	$	49
Liabilities:
Energy-related derivatives	$	—	$	3	$	—	$	—	$	3
Foreign currency derivatives	—		24		—		—		24
Contingent consideration	—		—		21		—		21
Total	$	—	$	27	$	21	$	—	$	48
Southern Company Gas
Assets:
Energy-related derivatives(a)(b)	$	322	$	108	$	4	$	—	$	434
Non-qualified deferred compensation trusts:
Domestic equity	—		11		—		—		11
Foreign equity	—		4		—		—		4
Pooled funds – fixed income	—		14		—		—		14
Cash equivalents	1		—		—		—		1
Cash equivalents	13		—		—		—		13
Total	$	336	$	137	$	4	$	—	$	477
Liabilities:
Energy-related derivatives(a)(b)	$	466	$	73	$	23	$	—	$	562

(a) Energy-related derivatives exclude $11 million associated with premiums and certain weather derivatives accounted for based on intrinsic value rather than fair value.

(b) Energy-related derivatives exclude cash collateral of $190 million.

(c) 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.

(d) Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. As of March 31, 2019, approximately $72 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 for the three months ended March 31, 2019 and decreased for the three months ended March 31, 2018 by the amounts shown in the table below. 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 March 31, 2019		Three Months Ended March 31, 2018
	(in millions)
Southern Company	$	152	$	(11	)
Alabama Power	87		(5		)
Georgia Power	65		(6		)

Financial Instruments for Which Carrying Amount Did Not Equal Fair Value

As of March 31, 2019, 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 millions)
Long-term debt, including securities due within one year:
Carrying amount	$	42,535	$	7,921	$	10,910	$	1,619	$	4,995	$	5,928
Fair value	43,910		8,424		11,249		1,619		5,131		6,176

(*) The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the Merger. Southern Company Gas amortizes the fair value adjustments over the lives of the respective bonds.

Fair Value of Commodity Derivative Contracts that Include a Significant Unobservable Component

The following table includes transfers to Level 3, which represent the fair value of Southern Company Gas' commodity derivative contracts that include a significant unobservable component for the first time during the period.

	Three Months Ended March 31, 2019
	(in millions)
Beginning balance	$	—
Transfers to Level 3	(30		)
Changes in fair value	11
Ending balance	$	(19	)

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Derivatives (Tables)

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Energy-Related Derivatives

At March 31, 2019, 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(*)	538	2022	2029
Alabama Power	72	2022	—
Georgia Power	153	2022	—
Mississippi Power	61	2022	—
Southern Power	9	2020	—
Southern Company Gas(*)	243	2021	2029

(*) Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 3.8 billion mmBtu and short natural gas positions of 3.6 billion mmBtu as of March 31, 2019, which is also included in Southern Company's total volume.

Schedule of Interest Rate Derivatives

At March 31, 2019, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2019
	(in millions)					(in millions)
Fair Value Hedges of Existing Debt
Southern Company(*)	$	300	2.75%	3-month LIBOR+0.92%	June 2020	$	(3	)
Southern Company(*)	1,500		2.35%	1-month LIBOR+0.87%	July 2021	(30		)
Georgia Power	200		4.25%	3-month LIBOR+2.46%	December 2019	(2		)
Southern Company Consolidated	$	2,000				$	(35	)

(*) Represents the Southern Company parent entity.

Schedule of Foreign Currency Derivatives

At March 31, 2019, 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, 2019
	(in millions)			(in millions)				(in millions)
Cash Flow Hedges of Existing Debt
Southern Power	$	677	2.95%	€	600	1.00%	June 2022	$	2
Southern Power	564		3.78%	500		1.85%	June 2026	11
Total	$	1,241		€	1,100			$	13

Fair Value of Energy-Related Derivatives and Interest Rate Derivatives

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

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	12		$	10		$	8		$	23
Other deferred charges and assets/Other deferred credits and liabilities	11			21			9			26
Assets held for sale, current/Liabilities held for sale, current	—			—			—			6
Total derivatives designated as hedging instruments for regulatory purposes	$	23		$	31		$	17		$	55
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	1		$	3		$	3		$	7
Other deferred charges and assets/Other deferred credits and liabilities	—			1			1			2
Interest rate derivatives:
Other current assets/Other current liabilities	—			20			—			19
Other deferred charges and assets/Other deferred credits and liabilities	—			15			—			30
Foreign currency derivatives:
Other current assets/Other current liabilities	—			24			—			23
Other deferred charges and assets/Other deferred credits and liabilities	38			—			75			—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	39		$	63		$	79		$	81
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	259		$	291		$	561		$	575
Other deferred charges and assets/Other deferred credits and liabilities	171			269			180			325
Total derivatives not designated as hedging instruments	$	430		$	560		$	741		$	900
Gross amounts recognized	$	492		$	654		$	837		$	1,036
Gross amounts offset(a)	$	(333	)	$	(523	)	$	(524	)	$	(801	)
Net amounts recognized in the Balance Sheets(b)	$	159		$	131		$	313		$	235

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	3		$	2		$	3		$	4
Other deferred charges and assets/Other deferred credits and liabilities	3			5			3			6
Total derivatives designated as hedging instruments for regulatory purposes	$	6		$	7		$	6		$	10
Gross amounts recognized	$	6		$	7		$	6		$	10
Gross amounts offset	$	(5	)	$	(5	)	$	(4	)	$	(4	)
Net amounts recognized in the Balance Sheets	$	1		$	2		$	2		$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	4		$	5		$	2		$	8
Other deferred charges and assets/Other deferred credits and liabilities	5			11			4			13
Total derivatives designated as hedging instruments for regulatory purposes	$	9		$	16		$	6		$	21
Derivatives designated as hedging instruments in cash flow and fair value hedges
Interest rate derivatives:
Other current assets/Other current liabilities	$	—		$	2		$	—		$	2
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	—		$	2		$	—		$	2
Gross amounts recognized	$	9		$	18		$	6		$	23
Gross amounts offset	$	(8	)	$	(8	)	$	(6	)	$	(6	)
Net amounts recognized in the Balance Sheets	$	1		$	10		$	—		$	17

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	2		$	2		$	1		$	3
Other deferred charges and assets/Other deferred credits and liabilities	1			4			2			6
Total derivatives designated as hedging instruments for regulatory purposes	$	3		$	6		$	3		$	9
Gross amounts recognized	$	3		$	6		$	3		$	9
Gross amounts offset	$	(3	)	$	(3	)	$	(2	)	$	(2	)
Net amounts recognized in the Balance Sheets	$	—		$	3		$	1		$	7
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	1		$	2		$	3		$	6
Other deferred charges and assets/Other deferred credits and liabilities	—			1			1			2
Foreign currency derivatives:
Other current assets/Other current liabilities	—			24			—			23
Other deferred charges and assets/Other deferred credits and liabilities	38			—			75			—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	39		$	27		$	79		$	31
Gross amounts recognized	$	39		$	27		$	79		$	31
Gross amounts offset	$	(1	)	$	(1	)	$	(3	)	$	(3	)
Net amounts recognized in the Balance Sheets	$	38		$	26		$	76		$	28
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	$	3		$	1		$	2		$	8
Other deferred charges and assets/Other deferred credits and liabilities	1			—			—			1
Total derivatives designated as hedging instruments for regulatory purposes	$	4		$	1		$	2		$	9
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-current	$	—		$	1		$	—		$	1
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	—		$	1		$	—		$	1

	As of March 31, 2019						As of December 31, 2018
Derivative Category and Balance Sheet Location	Assets			Liabilities			Assets			Liabilities
	(in millions)						(in millions)
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	$	259		$	291		$	559		$	574
Other deferred charges and assets/Other deferred credits and liabilities	171			269			180			325
Total derivatives not designated as hedging instruments	$	430		$	560		$	739		$	899
Gross amounts of recognized	$	434		$	562		$	741		$	909
Gross amounts offset(a)	$	(316	)	$	(506	)	$	(508	)	$	(785	)
Net amounts recognized in the Balance Sheets(b)	$	118		$	56		$	233		$	124

(a) Gross amounts offset include cash collateral held on deposit in broker margin accounts of $190 million and $277 million as of March 31, 2019 and December 31, 2018, respectively.

(b) Net amounts of derivative instruments outstanding exclude premium and intrinsic value associated with weather derivatives of $11 million and $8 million as of March 31, 2019 and December 31, 2018, respectively.

Pre-tax Effects of Unrealized Derivative Gains (Losses) Arising from Energy-Related Derivative Instruments

At March 31, 2019 and December 31, 2018, 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 at March 31, 2019
Derivative Category and Balance Sheet Location	Southern Company(*)			Alabama Power			Georgia Power			Mississippi Power			Southern Company Gas(*)
	(in millions)
Energy-related derivatives:
Other regulatory assets, current	$	(5	)	$	(1	)	$	(2	)	$	(1	)	$	(1	)
Other regulatory assets, deferred	(11		)	(2		)	(6		)	(3		)	—
Other regulatory liabilities, current	7			1			1			1			4
Total energy-related derivative gains (losses)	$	(9	)	$	(2	)	$	(7	)	$	(3	)	$	3

(*) Fair value gains and losses recorded in regulatory assets and liabilities include cash collateral held on deposit in broker margin accounts of $2 million at March 31, 2019.

Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet at December 31, 2018
Derivative Category and Balance Sheet Location	Southern Company			Alabama Power			Georgia Power			Mississippi Power			Southern Company Gas
	(in millions)
Energy-related derivatives:
Other regulatory assets, current	$	(19	)	$	(3	)	$	(6	)	$	(2	)	$	(8	)
Other regulatory assets, deferred	(16		)	(3		)	(9		)	(4		)	—
Assets held for sale, current	(6		)	—			—			—			—
Other regulatory liabilities, current	1			—			—			—			1
Total energy-related derivative gains (losses)	$	(40	)	$	(6	)	$	(15	)	$	(6	)	$	(7	)

Pre-tax Effects of Interest Rate Derivatives, Designated as Cash Flow Hedging Instruments

For the three months ended March 31, 2019 and 2018, the pre-tax effects of cash flow hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended March 31,
	2019			2018
	(in millions)
Southern Company
Energy-related derivatives	$	—		$	12
Interest rate derivatives	—			(2		)
Foreign currency derivatives	(39		)	53
Total	$	(39	)	$	63
Southern Power
Energy-related derivatives	$	—		$	11
Foreign currency derivatives	(39		)	53
Total	$	(39	)	$	64

Schedule of Cash Flow Hedging Instruments, Statements of Financial Performance and Financial Position, Location

For the three months ended March 31, 2019 and 2018, 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,
	2019			2018
	(in millions)
Southern Company
Total depreciation and amortization	$	751		$	769
Gain (loss) on energy-related cash flow hedges(a)	(3		)	1
Total interest expense, net of amounts capitalized	(430		)	(458		)
Gain (loss) on interest rate cash flow hedges(a)	(5		)	(5		)
Gain (loss) on foreign currency cash flow hedges(a)	(6		)	(5		)
Gain (loss) on interest rate fair value hedges(b)	14			(24		)
Total other income (expense), net	78			60
Gain (loss) on foreign currency cash flow hedges(a)(c)	(24		)	36
Southern Power
Total depreciation and amortization	$	119		$	114
Gain (loss) on energy-related cash flow hedges(a)	(3		)	1
Total interest expense, net of amounts capitalized	(44		)	(47		)
Gain (loss) on foreign currency cash flow hedges(a)	(6		)	(5		)
Total other income (expense), net	2			3
Gain (loss) on foreign currency cash flow hedges(a)(c)	(24		)	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 Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location

As of March 31, 2019 and December 31, 2018, 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	As of March 31, 2019			As of December 31, 2018			As of March 31, 2019		As of December 31, 2018
	(in millions)						(in millions)
Southern Company
Securities due within one year	$	(499	)	$	(498	)	$	1	$	2
Long-term debt	(2,065		)	(2,052		)	28		41
Georgia Power
Securities due within one year	$	(499	)	$	(498	)	$	1	$	2
Long-term debt	—			—			—		—

Pre-tax Effect of Interest Rate and Energy Related Derivatives

For the three months ended March 31, 2019 and 2018, 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	2019		2018
		(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	33	$	(15	)
	Cost of natural gas	8		2
Total derivatives in non-designated hedging relationships		$	41	$	(13	)

(*) Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for the three months ended March 31, 2019 and 2018.

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Acquisitions and Dispositions (Tables)

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Schedule of Construction Projects

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	Expected COD	PPA Contract Period
Mankato expansion(a)	Natural Gas	385	Mankato, MN	May 2019	20 years
Wildhorse Mountain(b)	Wind	100	Pushmataha County, OK	Fourth quarter 2019	20 years
Reading(c)	Wind	200	Osage and Lyon Counties, KS	Second quarter 2020	12 years

(a) In November 2018, Southern Power entered into an agreement to sell all of its equity interests in Plant Mankato, including this expansion currently under construction. This transaction is subject to FERC and state commission approvals and is expected to close mid-2019. The ultimate outcome of this matter cannot be determined at this time. See "Sales of Natural Gas and Biomass Plants" below.

(b) In May 2018, Southern Power purchased 100% of the Wildhorse Mountain facility. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

(c) In August 2018, Southern Power purchased 100% of the membership interests of the Reading facility from the joint development arrangement with Renewable Energy Systems Americas, Inc. described below. Southern Power may enter into a tax equity partnership, in which case it would then own 100% of the class B membership interests. The ultimate outcome of this matter cannot be determined at this time.

Disposal Groups, Including Discontinued Operations

Gulf Power and Southern Power's equity interests in Plant Oleander and Plant Stanton Unit A (together, the Florida Plants) represented individually significant components of Southern Company and Southern Power, respectively; therefore, pre-tax profit for these components for the three months ended March 31, 2018 is presented below:

	For the Three Months Ended March 31, 2018
	(in millions)
Earnings before income taxes:
Gulf Power	$	55
Southern Power's Florida Plants	$	8

The following table provides Southern Company's and Southern Power's major classes of assets and liabilities classified as held for sale at March 31, 2019 and December 31, 2018:

	Southern Company		Southern Power
	(in millions)
At March 31, 2019
Assets Held for Sale:
Current assets	$	55	$	11
Total property, plant, and equipment	637		604
Goodwill and other intangible assets	82		40
Other non-current assets	44		—
Total Assets Held for Sale	$	818	$	655
Liabilities Held for Sale:
Current liabilities	$	38	$	9
Other non-current liabilities	39		—
Total Liabilities Held for Sale	$	77	$	9
At December 31, 2018
Assets Held for Sale:
Current assets	$	393	$	8
Total property, plant, and equipment	4,583		536
Goodwill and other intangible assets	40		40
Other non-current assets	727		—
Total Assets Held for Sale	$	5,743	$	584
Liabilities Held for Sale:
Current liabilities	$	425	$	15
Long-term debt	1,286		—
Accumulated deferred income taxes	618		—
Other non-current liabilities	932		—
Total Liabilities Held for Sale	$	3,261	$	15

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Leases (Tables)

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Major Categories of Lease Obligations

The major categories of lease obligations are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Electric generating units	$	1,094	$	159	$	1,606	$	—	$	—	$	—
Real estate/land	803		3		63		2		393		83
Communication towers	131		1		3		—		—		—
Railcars	55		25		26		3		—		—
Other	153		10		16		3		—		1
Total	$	2,236	$	198	$	1,714	$	8	$	393	$	84

Balance Sheet Amounts Recorded for Operating and Financing Leases

Balance sheet amounts recorded for operating and finance leases are as follows:

	As of March 31, 2019
	Southern  Company(*)		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Operating Leases
Operating lease ROU assets, net	$	1,926	$	160	$	1,519	$	8	$	372	$	86
Operating lease obligations - current	$	239	$	47	$	139	$	3	$	22	$	13
Operating lease obligations - non current	1,752		147		1,404		5		371		71
Total operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance Leases
Finance lease ROU assets, net	$	242	$	4	$	145	$	—	$	—	$	—
Finance lease obligations - current	$	38	$	1	$	10	$	—	$	—	$	—
Finance lease obligations - noncurrent	207		3		161		—		—		—
Total finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

(*) Includes operating lease ROU assets, net and operating lease obligations classified as held for sale.

Lease Costs and Other Information

Lease costs for the three months ended March 31, 2019, which includes both amounts recognized as operations and maintenance expense and amounts capitalized as part of the cost of another asset, are as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease cost
Operating lease cost	$	69	$	7	$	49	$	1	$	7	$	4
Finance lease cost:
Amortization of ROU assets	7		—		4		—		—		—
Interest on lease obligations	3		—		4		—		—		—
Total finance lease cost	10		—		8		—		—		—
Short-term lease costs	14		5		3		—		—		—
Variable lease cost	19		—		16		—		1		—
Sublease income	—		—		—		—		—		—
Total lease cost	$	112	$	12	$	76	$	1	$	8	$	4

Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities subject to PPAs.

Other information with respect to cash and noncash activities related to leases, as well as weighted-average lease terms and discount rates, is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Other information
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$	74	$	13	$	32	$	1	$	7	$	4
Operating cash flows from finance leases	6		—		13		—		—		—
Financing cash flows from finance leases	8		—		2		—		—		—
ROU assets obtained in exchange for new operating lease obligations	15		2		4		—		—		—
ROU assets obtained in exchange for new finance lease obligations	29		—		28		—		—		—

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
Weighted-average remaining lease term in years:
Operating leases	13.5		3.8		10.1		6.8		33.7		9.0
Finance leases	18.5		14.8		11.3		—		—		—
Weighted-average discount rate:
Operating leases	4.49	%	3.33	%	4.42	%	4.03	%	5.68	%	3.70	%
Finance leases	5.00	%	3.75	%	10.68	%	—	%	—	%	—	%

Maturities of Operating Lease Liabilities

Maturities of lease liabilities are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Maturity Analysis
Operating leases:
2019 (remaining)	$	253	$	46	$	182	$	2	$	17	$	12
2020	291		53		202		2		22		16
2021	274		52		197		1		23		16
2022	263		52		195		1		23		12
2023	198		3		196		1		24		10
Thereafter	1,637		1		984		2		848		36
Total	2,916		207		1,956		9		957		102
Less: Present value discount	925		13		413		1		564		18
Operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance leases:
2019 (remaining)	$	24	$	1	$	22	$	—	$	—	$	—
2020	32		1		28		—		—		—
2021	26		1		25		—		—		—
2022	22		1		25		—		—		—
2023	18		1		25		—		—		—
Thereafter	273		—		165		—		—		—
Total	395		5		290		—		—		—
Less: Present value discount	150		1		119		—		—		—
Finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

Maturities of Finance Lease Liabilities

Maturities of lease liabilities are as follows:

	As of March 31, 2019
	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Maturity Analysis
Operating leases:
2019 (remaining)	$	253	$	46	$	182	$	2	$	17	$	12
2020	291		53		202		2		22		16
2021	274		52		197		1		23		16
2022	263		52		195		1		23		12
2023	198		3		196		1		24		10
Thereafter	1,637		1		984		2		848		36
Total	2,916		207		1,956		9		957		102
Less: Present value discount	925		13		413		1		564		18
Operating lease obligations	$	1,991	$	194	$	1,543	$	8	$	393	$	84
Finance leases:
2019 (remaining)	$	24	$	1	$	22	$	—	$	—	$	—
2020	32		1		28		—		—		—
2021	26		1		25		—		—		—
2022	22		1		25		—		—		—
2023	18		1		25		—		—		—
Thereafter	273		—		165		—		—		—
Total	395		5		290		—		—		—
Less: Present value discount	150		1		119		—		—		—
Finance lease obligations	$	245	$	4	$	171	$	—	$	—	$	—

Lease Income, Sales-type Leases

Lease income for the three months ended March 31, 2019 is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease income - interest income on sales-type leases	$	2	$	—	$	2	$	—	$	—
Lease income - operating leases	71		19		—		41		9
Variable lease income	66		—		—		72		—
Total lease income	$	139	$	19	$	2	$	113	$	9

Lease Income, Operating Leases

Lease income for the three months ended March 31, 2019 is as follows:

	For the Three Months Ended March 31, 2019
	Southern Company		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Lease income - interest income on sales-type leases	$	2	$	—	$	2	$	—	$	—
Lease income - operating leases	71		19		—		41		9
Variable lease income	66		—		—		72		—
Total lease income	$	139	$	19	$	2	$	113	$	9

Undiscounted Cash Flows to be Received Under Tolling Arrangements Accounted for as Sales-type Leases

The undiscounted cash flows to be received under tolling arrangements accounted for as sales-type leases are as follows:

	As of March 31, 2019
	Southern Company		Mississippi Power
	(in millions)
2019 (remaining)	$	11	$	11
2020	14		14
2021	14		14
2022	13		13
2023	12		12
Thereafter	135		135
Total undiscounted cash flows	$	199	$	199
Lease receivable	108		108
Difference between undiscounted cash flows and discounted cash flows	$	91	$	91

Undiscounted Cash Flows to be Received Under PPAs Accounted for as Operating Leases

The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases (adjusted for intercompany eliminations) are as follows:

	As of March 31, 2019
	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
2019 (remaining)	$	163	$	20	$	123	$	26
2020	188		26		128		34
2021	183		18		131		34
2022	174		8		134		34
2023	171		2		137		34
Thereafter	1,809		—		1,017		498
Total	$	2,688	$	74	$	1,670	$	660

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Segment and Related Information (Tables)

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Financial Data for Business Segments

Financial data for business segments and products and services for the three months ended March 31, 2019 and 2018 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, 2019:
Operating revenues	$	3,445	$	443	$	(93	)	$	3,795	$	1,474	$	182		$	(39	)	$	5,412
Segment net income (loss)(a)(b)(c)	565		56		—			621		270		1,195			(2		)	2,084
At March 31, 2019:
Goodwill	$	—	$	2	$	—		$	2	$	5,015	$	268		$	(1	)	$	5,284
Total assets	76,798		15,104		(779		)	91,123		20,952		3,391			(1,370		)	114,096
Three Months Ended March 31, 2018:
Operating revenues	$	3,979	$	509	$	(106	)	$	4,382	$	1,639	$	401		$	(50	)	$	6,372
Segment net income (loss)(a)(b)(d)	612		121		—			733		279		(74		)	—			938
At December 31, 2018:
Goodwill	$	—	$	2	$	—		$	2	$	5,015	$	298		$	—		$	5,315
Total assets	79,382		14,883		(306		)	93,959		21,448		3,285			(1,778		)	116,914

(a) Attributable to Southern Company.

(b) Segment net income (loss) for the traditional electric operating companies includes pre-tax charges for estimated losses on plants under construction of $2 million ($1 million after tax) and $44 million ($33 million after tax) for the three months ended March 31, 2019 and 2018, respectively. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) under "Mississippi Power – Kemper County Energy Facility" for additional information.

(c) Segment net income (loss) for the "All Other" column includes the preliminary pre-tax gain associated with the sale of Gulf Power of $2.5 billion ($1.3 billion after tax) for the three months ended March 31, 2019. See Note (K) under "Southern Company" for additional information.

(d) Segment net income (loss) for Southern Company Gas includes a goodwill impairment charge of $42 million for the three months ended March 31, 2018 related to the sale of Pivotal Home Solutions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

Business segment financial data for the three months ended March 31, 2019 and 2018 was as follows:

	Gas Distribution Operations(a)		Gas Pipeline Investments		Wholesale Gas Services(b)		Gas Marketing Services(c)(d)		Total		All Other			Eliminations			Consolidated
	(in millions)
Three Months Ended March 31, 2019:
Operating revenues	$	1,172	$	8	$	86	$	229	$	1,495	$	11		$	(32	)	$	1,474
Segment net income (loss)	133		32		47		61		273		(3		)	—			270
Total assets at March 31, 2019:	17,379		1,781		821		1,611		21,592		10,900			(11,540		)	20,952
Three Months Ended March 31, 2018:
Operating revenues	$	1,212	$	8	$	166	$	271	$	1,657	$	15		$	(33	)	$	1,639
Segment net income (loss)	149		27		104		13		293		(14		)	—			279
Total assets at December 31, 2018:	17,266		1,763		1,302		1,587		21,918		11,112			(11,582		)	$	21,448

(a) Operating revenues for the three gas distribution operations dispositions were $167 million for the three months ended March 31, 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

(b) The revenues for wholesale gas services are netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended March 31, 2019	$	1,926	$	88	$	2,014	$	1,928	$	86
Three Months Ended March 31, 2018	1,938		167		2,105		1,939		166

(c) Operating revenues for the gas marketing services disposition were $32 million for the three months ended March 31, 2018. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

(d) Segment net income (loss) for gas marketing services includes a goodwill impairment charge of $42 million for the three months ended March 31, 2018 related to the sale of Pivotal Home Solutions. See Note 15 to the financial statements in Item 8 of the Form 10-K under "Southern Company Gas" for additional information.

Financial Data for Products and Services

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2019	$	3,084	$	499	$	212	$	3,795
Three Months Ended March 31, 2018	3,568		623		191		4,382

	Southern Company Gas' Revenues
	Gas Distribution Operations(a)		Gas Marketing Services(b)		Other		Total
	(in millions)
Three Months Ended March 31, 2019	$	1,161	$	229	$	84	$	1,474
Three Months Ended March 31, 2018	1,200		271		168		1,639

(a) Operating revenues for the three gas distribution operations dispositions were $167 million for the three months ended March 31, 2018.

(b) Operating revenues for Pivotal Home Solutions were $32 million for the three months ended March 31, 2018.

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Introduction - Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
SOUTHERN Co GAS
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Inventory decrement	$ 0	$ 0

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Introduction - Goodwill (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Goodwill [Line Items]
Goodwill	$ 5,284	$ 5,315
SOUTHERN Co GAS
Goodwill [Line Items]
Goodwill	5,015	$ 5,015
SOUTHERN Co GAS | Gas Distribution Operations
Goodwill [Line Items]
Goodwill	4,034
SOUTHERN Co GAS | Gas Marketing Services
Goodwill [Line Items]
Goodwill	$ 981

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Introduction - Other Intangible Assets (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Other intangible assets subject to amortization:
Gross Carrying Amount	$ 761	$ 773
Accumulated Amortization	(251)	(235)
Other Intangible Assets, Net	510	538
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75	75
Total other intangible assets
Gross Carrying Amount	836	848
Other Intangible Assets, Net	585	613
Customer relationships
Other intangible assets subject to amortization:
Gross Carrying Amount	211	223
Accumulated Amortization	(100)	(94)
Other Intangible Assets, Net	111	129
Trade names
Other intangible assets subject to amortization:
Gross Carrying Amount	70	70
Accumulated Amortization	(22)	(21)
Other Intangible Assets, Net	48	49
Other
Other intangible assets subject to amortization:
Gross Carrying Amount	11	11
Accumulated Amortization	(6)	(5)
Other Intangible Assets, Net	5	6
SOUTHERN POWER CO
Other intangible assets subject to amortization:
Accumulated Amortization	(67)	(61)
SOUTHERN POWER CO | PPA fair value adjustments
Other intangible assets subject to amortization:
Gross Carrying Amount	405	405
Accumulated Amortization	(67)	(61)
Other Intangible Assets, Net	338	344
SOUTHERN Co GAS
Other intangible assets subject to amortization:
Gross Carrying Amount	246	246
Accumulated Amortization	(153)	(145)
Other Intangible Assets, Net	93	101
Total other intangible assets
Other Intangible Assets, Net	93	101
SOUTHERN Co GAS | Customer relationships
Other intangible assets subject to amortization:
Gross Carrying Amount	156	156
Accumulated Amortization	(89)	(84)
Other Intangible Assets, Net	67	72
SOUTHERN Co GAS | Trade names
Other intangible assets subject to amortization:
Gross Carrying Amount	26	26
Accumulated Amortization	(8)	(7)
Other Intangible Assets, Net	18	19
SOUTHERN Co GAS | Storage and transportation contracts
Other intangible assets subject to amortization:
Gross Carrying Amount	64	64
Accumulated Amortization	(56)	(54)
Other Intangible Assets, Net	$ 8	$ 10

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Introduction - Intangibles, Amortization (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 17
SOUTHERN POWER CO
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	6
SOUTHERN Co GAS
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	8
Gas Marketing Services | SOUTHERN Co GAS
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	6
Wholesale Gas Services | SOUTHERN Co GAS
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 2

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Introduction - Restricted Cash (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	$ 1,361	$ 1,396
Cash and cash equivalents held for sale		9
Restricted cash:
Total cash, cash equivalents, and restricted cash	1,364	1,519	$ 2,290	$ 2,147
Restricted cash
Restricted cash:
Restricted cash		0
Other accounts and notes receivable
Restricted cash:
Restricted cash	4	114
GEORGIA POWER CO
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	9	4
Cash and cash equivalents held for sale		0
Restricted cash:
Total cash, cash equivalents, and restricted cash	9	112	1,158	852
GEORGIA POWER CO | Restricted cash
Restricted cash:
Restricted cash		108
GEORGIA POWER CO | Other accounts and notes receivable
Restricted cash:
Restricted cash		0
SOUTHERN Co GAS
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	57	64
Cash and cash equivalents held for sale		0
Restricted cash:
Total cash, cash equivalents, and restricted cash	61	70	$ 100	$ 78
SOUTHERN Co GAS | Restricted cash
Restricted cash:
Restricted cash		0
SOUTHERN Co GAS | Other accounts and notes receivable
Restricted cash:
Restricted cash	$ 4	$ 6

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Regulatory Matters - Cost Recovery Clauses (Details) - USD ($) $ in Millions	Mar. 31, 2019	Feb. 05, 2019	Dec. 31, 2018
ALABAMA POWER CO
Loss Contingencies [Line Items]
Rate RSE Refund Liability		$ 75
ALABAMA POWER CO | Deferred under recovered regulatory clause revenues
Loss Contingencies [Line Items]
Rate CNP Compliance	$ 0		$ 42
Rate CNP PPA	21		25
Retail Energy Cost Recovery()	0		109
ALABAMA POWER CO | Customer accounts receivable
Loss Contingencies [Line Items]
Rate CNP Compliance	25		0
ALABAMA POWER CO | Other regulatory liabilities, deferred
Loss Contingencies [Line Items]
Retail Energy Cost Recovery()	2		0
Natural Disaster Reserve	22		20
GEORGIA POWER CO | Receivables – under recovered fuel clause revenues
Loss Contingencies [Line Items]
Fuel Cost Recovery	73		115
MISSISSIPPI POWER CO | Over recovered retail fuel costs
Loss Contingencies [Line Items]
Fuel Cost Recovery	$ 10		$ 8

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Regulatory Matters - Alabama Power (Details) - USD ($) $ in Millions	Apr. 15, 2019	Mar. 31, 2019	Feb. 28, 2019	Dec. 31, 2018
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Plant in service, net of depreciation		$ (71,839)		$ (72,668)
Other utility plant, net		1,315		0
ALABAMA POWER CO
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Plant in service, net of depreciation		(19,363)		(20,414)
Other utility plant, net		$ 1,315		$ 0
ALABAMA POWER CO | Restatement Adjustment
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Plant in service, net of depreciation			$ 1,300
Other utility plant, net			$ 1,300
ALABAMA POWER CO | Subsequent Event | Restatement Adjustment
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Capitalized asset retirement costs, net	$ 700
Regulatory asset to be recovered over the units' remaining useful lives	700
ALABAMA POWER CO | Plant Gorgas Units 8, 9, and 10 | Subsequent Event | Restatement Adjustment
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net investment costs	740
Regulatory asset to be recovered over the units' remaining useful lives	$ 740

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Regulatory Matters - Nuclear Construction (Details) - GEORGIA POWER CO $ in Millions						1 Months Ended		3 Months Ended	12 Months Ended			36 Months Ended
	Jan. 01, 2021	Jan. 01, 2020	Feb. 19, 2019 USD ($)	Jan. 11, 2018 USD ($)	Jan. 01, 2016	Dec. 31, 2018 USD ($) appeal	Aug. 31, 2018 USD ($)	Mar. 31, 2019 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2009 USD ($) utility MW	Dec. 31, 2022 USD ($)	Dec. 31, 2014	Dec. 31, 2013
Loss Contingencies [Line Items]
Number of construction units approved | utility											2
Electric generating capacity in mega watts under consortium agreement | MW											1,100
Additional construction capital costs				$ 3,300.0
Estimated in-service capital cost											$ 4,418.0
Financing costs collected, net of tax								$ 1,900.0
Increase in NCCR tariff						$ 88.0
Amendment to estimated in-service capital cost				$ 5,680.0
Retail rate of return on common equity														10.95%
Number of appeals | appeal						2
Requested capital construction costs			$ 5,400.0
Deferred approval of expenditures related to administrative claim			$ 51.6
FFB Loan
Loss Contingencies [Line Items]
Long-term line of credit								3,460.0
Eligible project costs to be reimbursed								$ 5,130.0
Plant Vogtle Units 3 And 4
Loss Contingencies [Line Items]
Proportionate ownership share								45.70%
Construction financing costs								$ 1,900.0
Base project capital cost forecast, monthly								50.0
Monthly AFUDC								12.0
Percentage of ownership interest required for voting for continuing construction							90.00%						90.00%
Cost settlement agreement revised forecast, net of payments								$ 7,300.0
Public utilities, approved return on equity percentage					10.00%
Public utilities, approved return on equity, monthly percentage decrease								0.10%
Return on equity reduction, negative impact on earnings										$ 100.0
Requested capital construction costs							$ 578.0
Guarantor obligations								$ 1,700.0
Customer refund								$ 188.0
Plant Vogtle Units 3 And 4 | Scenario, Forecast
Loss Contingencies [Line Items]
Construction financing costs									$ 3,100.0
Public utilities, approved return on equity percentage	5.30%	8.30%
Return on equity reduction, negative impact on earnings									$ 75.0			$ 635.0
Plant Vogtle Units 3 And 4 | Vogtle Owners
Loss Contingencies [Line Items]
Period of notice required in the event letters of credit are not renewed								30 days

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Regulatory Matters - Nuclear Construction Cost and Schedule (Details) - GEORGIA POWER CO - Plant Vogtle Units 3 And 4 $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Loss Contingencies [Line Items]
Base project capital cost forecast	$ 8,000
Construction contingency estimate	400
Total project capital cost forecast	8,400
Net investment as of March 31, 2019	(4,900)
Remaining estimate to complete	3,500
Expected capitalized costs	325
Guarantor obligations	1,700
Customer refund	$ 188

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Regulatory Matters - Mississippi Power (Details) $ in Millions	Mar. 28, 2019 USD ($)
MRA Revenue | MISSISSIPPI POWER CO
Loss Contingencies [Line Items]
Decrease in base rate under cost based electric tariff	$ 3.7

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Regulatory Matters - Kemper County Energy Facility (Details) - MISSISSIPPI POWER CO - Kemper IGCC - USD ($) $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended	48 Months Ended
	Dec. 31, 2018	Mar. 31, 2019	Dec. 31, 2019	Dec. 31, 2023
Loss Contingencies [Line Items]
Pre-tax charge to income		$ 2
Asset retirement obligation, liabilities incurred, net of tax		1
Asset retirement obligation, expected cost		$ 10
Government grants received	$ 387
Scenario, Forecast
Loss Contingencies [Line Items]
Asset retirement obligation, liabilities incurred			$ 11
Minimum | Scenario, Forecast
Loss Contingencies [Line Items]
Asset retirement obligation, liabilities incurred				$ 2
Maximum | Scenario, Forecast
Loss Contingencies [Line Items]
Asset retirement obligation, liabilities incurred				$ 6

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Regulatory Matters - Southern Company Gas (Details) $ in Millions				1 Months Ended		12 Months Ended
	Apr. 16, 2019 USD ($) intervenor	Apr. 08, 2019 USD ($)	Dec. 31, 2018 USD ($)	Dec. 31, 2018 USD ($)	Nov. 30, 2018 USD ($)	Dec. 31, 2018
Nicor Gas
Loss Contingencies [Line Items]
Approved increase (decrease) in fuel rates amount					$ 230
Public utilities, approved return on equity percentage					10.60%
Regulatory equity ratio					54.00%	52.00%
Virginia Natural Gas
Loss Contingencies [Line Items]
Approved increase (decrease) in fuel rates amount				$ (14)
Bill credits			$ 14
Subsequent Event | Nicor Gas
Loss Contingencies [Line Items]
Public utilities, approved return on equity percentage	9.86%
Regulatory equity ratio	54.00%
Number of intervenors | intervenor	2
Requested increase in rate amounts	$ 180
Subsequent Event | SAVE | Virginia Natural Gas
Loss Contingencies [Line Items]
Infrastructure replacement program, proposed investment amount		$ 370
Infrastructure replacement program, petitioned investment renewal term		5 years
Infrastructure replacement program, petitioned investment term		6 years
Infrastructure replacement program, proposed investment variance amount		$ 10
Subsequent Event | SAVE | 2018 | Virginia Natural Gas
Loss Contingencies [Line Items]
Approved investment amount		35
Subsequent Event | SAVE | 2019 | Virginia Natural Gas
Loss Contingencies [Line Items]
Infrastructure replacement program, proposed investment amount		40
Infrastructure replacement program, proposed investment variance amount		6
Subsequent Event | SAVE | 2020 | Virginia Natural Gas
Loss Contingencies [Line Items]
Infrastructure replacement program, proposed investment amount		50
Infrastructure replacement program, proposed investment variance amount		8
Subsequent Event | SAVE | 2021 | Virginia Natural Gas
Loss Contingencies [Line Items]
Infrastructure replacement program, proposed investment amount		60
Infrastructure replacement program, proposed investment variance amount		9
Subsequent Event | SAVE | 2022 | Virginia Natural Gas
Loss Contingencies [Line Items]
Infrastructure replacement program, proposed investment amount		70
Infrastructure replacement program, proposed investment variance amount		10
Subsequent Event | SAVE | 2023 | Virginia Natural Gas
Loss Contingencies [Line Items]
Infrastructure replacement program, proposed investment amount		70
Infrastructure replacement program, proposed investment variance amount		10
Subsequent Event | SAVE | 2024 | Virginia Natural Gas
Loss Contingencies [Line Items]
Infrastructure replacement program, proposed investment amount		70
Infrastructure replacement program, proposed investment variance amount		$ 10

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Regulatory Matters - FERC Matters (Details) - Open Access Transmission Tariff - SCS	May 10, 2018
Loss Contingencies [Line Items]
Public utilities, approved return on equity percentage	10.60%
Moratorium period	5 years

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Contingencies - General Litigation Matters (Details) $ in Millions	1 Months Ended				3 Months Ended	12 Months Ended
	May 31, 2019 USD ($)	Nov. 30, 2018 defendant plaintiff	May 31, 2018 USD ($) agreement	Apr. 30, 2018	Mar. 31, 2019 USD ($)	Dec. 31, 2017 claim
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff		10
Pending Litigation | Putative Securities Class Action
Loss Contingencies [Line Items]
Increase in the purported class period						1 day
Pending Litigation | Shareholder Derivative Lawsuits
Loss Contingencies [Line Items]
Pending number of claims | claim						2
Stay period			30 days	30 days
MISSISSIPPI POWER CO | Pending Litigation | Martin Product Sales, LLC Litigation
Loss Contingencies [Line Items]
Number of agreements | agreement			2
MISSISSIPPI POWER CO | Pending Litigation | Purported Violations Of Mississippi Consumer Protection Act
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff		4
Number of defendants | defendant		3
Martin Product Sales, LLC Litigation | Martin Product Sales, LLC Litigation
Loss Contingencies [Line Items]
Damages sought by litigation			$ 143
SOUTHERN POWER CO
Loss Contingencies [Line Items]
Withholding of construction contract payments					$ 26
SOUTHERN POWER CO | RE Roserock, LLC | RE Roserock, LLC
Loss Contingencies [Line Items]
Ownership percentage by parent					51.00%
RE Roserock, LLC
Loss Contingencies [Line Items]
Insurance proceeds					$ 5
RE Roserock, LLC | Scenario, Forecast | Subsequent Event
Loss Contingencies [Line Items]
Amount paid to other party	$ 26

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Contingencies - Environmental Remediation (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
GEORGIA POWER CO
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 18	$ 23
SOUTHERN Co GAS
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	289	$ 294
Location One | SOUTHERN Co GAS
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 2

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Contingencies - Other Matters (Details) - Subsequent Event - Scenario, Forecast - Plant Daniel Units 1 And 2	60 Months Ended
	Jan. 15, 2024 USD ($)
GULF POWER CO
Loss Contingencies [Line Items]
Undivided ownership interest to be sold	50.00%
Undivided ownership interest, ownership interest in individual unit	100.00%
MISSISSIPPI POWER CO
Loss Contingencies [Line Items]
Payments to acquire business	$ 1
Option to purchase, period	120 days

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Revenue from Contracts with Customers - Disaggregate Revenue Sources (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 5,412	$ 6,372
Revenue from leases	139
Total retail electric and gas distribution revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	4,245	4,768
Retail electric revenues
Disaggregation of Revenue [Line Items]
Revenue from leases	8	18
Increase (decrease) in revenue from cost recovery mechanisms	(103)	117
Residential
Disaggregation of Revenue [Line Items]
Total operating revenues	1,288	1,539
Commercial
Disaggregation of Revenue [Line Items]
Total operating revenues	1,093	1,243
Industrial
Disaggregation of Revenue [Line Items]
Total operating revenues	677	756
Other
Disaggregation of Revenue [Line Items]
Total operating revenues	26	30
Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,163	1,224
Alternative revenue programs
Disaggregation of Revenue [Line Items]
Total operating revenues	(2)	(24)
Wholesale energy revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	367	472
Revenue from leases	66	69
Revenue from transactions accounted for as derivatives	53	93
Wholesale capacity revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	132	151
Revenue from leases	25	30
Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	313	407
Revenue from leases	9
Other revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	355	574
Revenue from leases	31	33
Revenues not accounted for under ASC 606	96	90
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Total operating revenues	1,408	1,473
ALABAMA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,213	1,285
Increase (decrease) in revenue from cost recovery mechanisms	(57)	47
ALABAMA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total operating revenues	540	570
ALABAMA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total operating revenues	354	371
ALABAMA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total operating revenues	313	338
ALABAMA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total operating revenues	6	6
ALABAMA POWER CO | Wholesale energy revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	94	101
Revenue from transactions accounted for as derivatives	3	5
ALABAMA POWER CO | Wholesale capacity revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	27	24
ALABAMA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	74	63
Revenues not accounted for under ASC 606	28	25
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Total operating revenues	1,833	1,961
Revenue from leases	19
GEORGIA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,668	1,798
Revenue from leases	8	18
Increase (decrease) in revenue from cost recovery mechanisms	(47)	10
GEORGIA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total operating revenues	688	744
GEORGIA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total operating revenues	674	717
GEORGIA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total operating revenues	289	316
GEORGIA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total operating revenues	17	21
GEORGIA POWER CO | Wholesale energy revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	18	40
Revenue from transactions accounted for as derivatives	4	7
GEORGIA POWER CO | Wholesale capacity revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	14	14
GEORGIA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	133	109
Revenue from leases	11	33
Revenues not accounted for under ASC 606	31	26
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Total operating revenues	287	302
Revenue from leases	2
MISSISSIPPI POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	203	194
Increase (decrease) in revenue from cost recovery mechanisms	1	76
MISSISSIPPI POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total operating revenues	60	60
MISSISSIPPI POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total operating revenues	65	62
MISSISSIPPI POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total operating revenues	74	70
MISSISSIPPI POWER CO | Other
Disaggregation of Revenue [Line Items]
Total operating revenues	4	2
MISSISSIPPI POWER CO | Wholesale energy revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	78	98
Revenue from transactions accounted for as derivatives	1	1
MISSISSIPPI POWER CO | Wholesale capacity revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1	4
MISSISSIPPI POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	5	6
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Total operating revenues	443	509
Revenue from leases	113
SOUTHERN POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	127	138
Revenue from leases	41	47
SOUTHERN POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	227	254
Revenue from leases	72	76
SOUTHERN POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	85	115
Revenue from transactions accounted for as derivatives	45	79
SOUTHERN POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	4	2
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Total operating revenues	1,474	1,639
Revenue from leases	9
SOUTHERN Co GAS | Wholesale Gas Services | Third Party Gross Revenues
Disaggregation of Revenue [Line Items]
Revenue from transactions accounted for as derivatives	1,200	1,100
SOUTHERN Co GAS | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,161	1,200
SOUTHERN Co GAS | Residential
Disaggregation of Revenue [Line Items]
Total operating revenues	601	660
SOUTHERN Co GAS | Commercial
Disaggregation of Revenue [Line Items]
Total operating revenues	170	192
SOUTHERN Co GAS | Transportation
Disaggregation of Revenue [Line Items]
Total operating revenues	256	277
SOUTHERN Co GAS | Industrial
Disaggregation of Revenue [Line Items]
Total operating revenues	17	17
SOUTHERN Co GAS | Other
Disaggregation of Revenue [Line Items]
Total operating revenues	119	78
SOUTHERN Co GAS | Alternative revenue programs
Disaggregation of Revenue [Line Items]
Total operating revenues	(2)	(24)
SOUTHERN Co GAS | Gas pipeline investments
Disaggregation of Revenue [Line Items]
Total operating revenues	8	8
Revenue from leases	8
SOUTHERN Co GAS | Wholesale Gas Services
Disaggregation of Revenue [Line Items]
Total operating revenues	66	146
SOUTHERN Co GAS | Gas marketing services
Disaggregation of Revenue [Line Items]
Total operating revenues	229	271
Revenues not accounted for under ASC 606	6	4
SOUTHERN Co GAS | Other revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	10	14
Operating Segments | SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Total operating revenues	1,495	1,657
Operating Segments | SOUTHERN Co GAS | Wholesale Gas Services
Disaggregation of Revenue [Line Items]
Total operating revenues	86	166
Operating Segments | SOUTHERN Co GAS | Wholesale Gas Services | Third Party Gross Revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	$ 1,926	$ 1,938

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Revenue from Contracts with Customers - Contract Balances (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Receivables	$ 2,522	$ 2,630
Contract Assets	84	102
Contract Liabilities	62	32
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Receivables	514	520
Contract Assets	1	0
Contract Liabilities	10	12
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Receivables	668	721
Contract Assets	41	58
Contract Liabilities	25	7
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Receivables	85	100
Contract Assets	0	0
Contract Liabilities	0	0
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Receivables	99	118
Contract Assets	0	0
Contract Liabilities	4	11
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Receivables	948	952
Contract Assets	0	0
Contract Liabilities	$ 1	$ 2

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Revenue from Contracts with Customers - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Contract assets	$ 84	$ 102
Contract liabilities	62	32
Unregulated Distributed Generation
Disaggregation of Revenue [Line Items]
Contract assets	34	39
Contract liabilities	$ 25	11
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Performance obligation, expected timing of satisfaction	Georgia Power had contract assets primarily related to unregulated service agreements where payment is contingent on project completion and fixed retail customer bill programs where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over the one-year contract term.
Contract assets	$ 41	58
Contract liabilities	$ 25	$ 7

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Revenue from Contracts with Customers - Revenue from Contracts with Customers (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers recognized	$ 17
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers recognized	$ 10

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Revenue from Contracts with Customers - Performance Obligations (Details) $ in Millions	Mar. 31, 2019 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 451
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 349
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
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]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 310
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 301
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,219
Performance obligation, expected timing of satisfaction
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 16
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 22
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 27
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 23
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 22
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 140
Performance obligation, expected timing of satisfaction
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 30
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 38
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 40
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 30
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 31
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 82
Performance obligation, expected timing of satisfaction
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2
Performance obligation, expected timing of satisfaction	1 year
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 3
Performance obligation, expected timing of satisfaction	1 year
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1
Performance obligation, expected timing of satisfaction	1 year
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction	1 year
MISSISSIPPI POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction	1 year
MISSISSIPPI 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	$ 0
Performance obligation, expected timing of satisfaction
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 248
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 295
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 270
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 276
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 269
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,143
Performance obligation, expected timing of satisfaction

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Consolidated Entities and Equity Method Investments - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) investor
SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	67.00%
Global Atlantic
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	33.00%
SP Solar Holdings I, LP | Variable Interest Entity, Primary Beneficiary | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Assets	$ 6,500
Liabilities	373
Noncontrolling interests related to other partners' interests	$ 1,200
SP Wind | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	60.00%
Number of financial investors | investor	3
SP Wind | Financial Investors
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	40.00%
SP Wind | Variable Interest Entity, Primary Beneficiary | SOUTHERN POWER CO
Schedule of Equity Method Investments [Line Items]
Assets	$ 2,600
Liabilities	141
Noncontrolling interests related to other partners' interests	$ 46

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Consolidated Entities and Equity Method Investments - Balance Sheet Equity Method Investment Carrying Amount (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Investment Balance	$ 1,598	$ 1,580
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,557	1,538
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,262	1,261
SOUTHERN Co GAS | Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Investment Balance	96	83
SOUTHERN Co GAS | PennEast Pipeline
Schedule of Equity Method Investments [Line Items]
Investment Balance	75	71
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Investment Balance	$ 124	$ 123

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Consolidated Entities and Equity Method Investments - Income Statement Equity Method Investment Carrying Amount (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	$ 48	$ 41
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	48	42
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	42	39
SOUTHERN Co GAS | Atlantic Coast Pipeline
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	3	1
SOUTHERN Co GAS | PennEast Pipeline
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	2	1
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	$ 1	$ 1

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Consolidated Entities and Equity Method Investments - Investment in SNG (Details) - SNG - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Statement Information
Revenues	$ 166	$ 160
Operating income	106	99
Net income	$ 84	$ 78

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Financing - Narrative (Details) shares in Millions	1 Months Ended		3 Months Ended		12 Months Ended
	Mar. 31, 2019 USD ($)	Jan. 31, 2019 USD ($)	Mar. 31, 2019 USD ($) loan shares	Mar. 31, 2018 USD ($) shares	Dec. 31, 2014	Apr. 30, 2019 USD ($)	Aug. 31, 2018
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	$ 1,400,000,000		$ 1,400,000,000
Maximum borrowing capacity	7,863,000,000		7,863,000,000
Repayments of short-term debt			$ 1,750,000,000	$ 150,000,000
Stock-based compensation awards not included in the diluted earnings per share calculation because they were anti-dilutive (in shares) | shares			0	0
Senior Notes
Debt Instrument [Line Items]
Repayments of debt		$ 1,200,000,000
Senior Notes | 1.85% Notes
Debt Instrument [Line Items]
Interest rate		1.85%
Repurchase amount		$ 522,000,000
Debt face amount		$ 1,000,000,000
Senior Notes | Series 2014B Notes
Debt Instrument [Line Items]
Interest rate		2.15%
Repurchase amount		$ 180,000,000
Debt face amount		350,000,000
Senior Notes | Series 2018A Notes
Debt Instrument [Line Items]
Repurchase amount		504,000,000
Debt face amount		750,000,000
Notes Payable to Banks | Uncommitted Bank Credit Arrangement
Debt Instrument [Line Items]
Repayments of short-term debt		250,000,000
Notes Payable to Banks | Floating Rate Bank Term Loan Agreement
Debt Instrument [Line Items]
Repayments of short-term debt		1,500,000,000
ALABAMA POWER CO
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	854,000,000		$ 854,000,000
Fixed rate pollution control revenue bonds outstanding	87,000,000		87,000,000
Maximum borrowing capacity	1,333,000,000		1,333,000,000
GEORGIA POWER CO
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	550,000,000		550,000,000
Fixed rate pollution control revenue bonds outstanding	345,000,000		345,000,000
Maximum borrowing capacity	1,750,000,000		1,750,000,000
Repayments of short-term debt			0	$ 150,000,000
GEORGIA POWER CO | Subsequent Event
Debt Instrument [Line Items]
Fixed rate pollution control revenue bonds outstanding						$ 115,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project) First Series 1992
Debt Instrument [Line Items]
Redeemed aggregate principal amount		13,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Eighth Series 1994
Debt Instrument [Line Items]
Redeemed aggregate principal amount		20,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 1995
Debt Instrument [Line Items]
Redeemed aggregate principal amount		$ 75,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Bartow County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Bowen Project), First Series 2009
Debt Instrument [Line Items]
Debt face amount	173,000,000		173,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), First Series 2013
Debt Instrument [Line Items]
Debt face amount	105,000,000		105,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 2008
Debt Instrument [Line Items]
Debt face amount	65,000,000		$ 65,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1994 | Subsequent Event
Debt Instrument [Line Items]
Debt face amount						55,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Fourth Series 1995 | Subsequent Event
Debt Instrument [Line Items]
Debt face amount						30,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Ninth Series 1994 | Subsequent Event
Debt Instrument [Line Items]
Debt face amount						20,000,000
GEORGIA POWER CO | Municipal bonds | Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia Power Company Plant Vogtle Project), Second Series 1994 | Subsequent Event
Debt Instrument [Line Items]
Debt face amount						$ 10,000,000
GEORGIA POWER CO | Plant Vogtle Units 3 And 4
Debt Instrument [Line Items]
Undivided ownership interest					45.70%
GEORGIA POWER CO | Term Loan
Debt Instrument [Line Items]
Number of term loan facilities | loan			2
GEORGIA POWER CO | 2014 FFB Credit Facility
Debt Instrument [Line Items]
Eligible project costs to be reimbursed			$ 5,130,000,000
Eligible project costs to be reimbursed, percentage					70.00%
Borrowings made	$ 835,000,000
Interest rate	3.213%		3.213%
Borrowings outstanding	$ 3,460,000,000		$ 3,460,000,000
Amortization period for line of credit facility					5 years
GEORGIA POWER CO | 2014 FFB Credit Facility | U.S. Treasury Rate
Debt Instrument [Line Items]
Basis spread					0.375%
GEORGIA POWER CO | Additional FFB Credit Facility
Debt Instrument [Line Items]
Eligible project costs to be reimbursed, percentage	70.00%
Amounts received under Guarantee Settlement Agreement, less Custumer Refunds	$ 1,492,000,000		1,492,000,000
MISSISSIPPI POWER CO
Debt Instrument [Line Items]
Variable rate pollution control revenue bonds outstanding	40,000,000		40,000,000
Maximum borrowing capacity	100,000,000		100,000,000
MISSISSIPPI POWER CO | Municipal bonds | Mississippi Business Finance Corporation Pollution Control Revenue Refunding Bonds, Series 2002
Debt Instrument [Line Items]
Debt face amount	43,000,000		43,000,000
Traditional Electric Operating Companies
Debt Instrument [Line Items]
Fixed rate pollution control revenue bonds outstanding	432,000,000		432,000,000
SOUTHERN POWER CO
Debt Instrument [Line Items]
Maximum borrowing capacity	750,000,000		750,000,000
SOUTHERN Co GAS
Debt Instrument [Line Items]
Maximum borrowing capacity	1,900,000,000		1,900,000,000
Nicor Gas
Debt Instrument [Line Items]
Maximum borrowing capacity	$ 500,000,000		$ 500,000,000
Plant Vogtle Units 3 And 4 | GEORGIA POWER CO
Debt Instrument [Line Items]
Undivided ownership interest	45.70%		45.70%
Failure to vote, percentage of ownership interests					90.00%		90.00%

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Financing - Schedule of Credit Arrangements (Details)	Mar. 31, 2019 USD ($)
Line of Credit Facility [Line Items]
Expires, 2019	$ 163,000,000
Expires, 2020	500,000,000
Expires, 2022	7,200,000,000
Total	7,863,000,000
Unused	7,834,000,000
Southern Company
Line of Credit Facility [Line Items]
Expires, 2019	0
Expires, 2020	0
Expires, 2022	2,000,000,000
Total	2,000,000,000
Unused	1,999,000,000
ALABAMA POWER CO
Line of Credit Facility [Line Items]
Expires, 2019	33,000,000
Expires, 2020	500,000,000
Expires, 2022	800,000,000
Total	1,333,000,000
Unused	1,333,000,000
GEORGIA POWER CO
Line of Credit Facility [Line Items]
Expires, 2019	0
Expires, 2020	0
Expires, 2022	1,750,000,000
Total	1,750,000,000
Unused	1,736,000,000
MISSISSIPPI POWER CO
Line of Credit Facility [Line Items]
Expires, 2019	100,000,000
Expires, 2020	0
Expires, 2022	0
Total	100,000,000
Unused	100,000,000
SOUTHERN POWER CO
Line of Credit Facility [Line Items]
Expires, 2019	0
Expires, 2020	0
Expires, 2022	750,000,000
Total	750,000,000
Unused	741,000,000
SOUTHERN POWER CO | Standby Letters of Credit
Line of Credit Facility [Line Items]
Total	120,000,000
Unused	24,000,000
SOUTHERN Co GAS
Line of Credit Facility [Line Items]
Expires, 2019	0
Expires, 2020	0
Expires, 2022	1,900,000,000
Total	1,900,000,000
Unused	1,895,000,000
Other
Line of Credit Facility [Line Items]
Expires, 2019	30,000,000
Expires, 2020	0
Expires, 2022	0
Total	30,000,000
Unused	30,000,000
Southern Company Gas Capital
Line of Credit Facility [Line Items]
Total	1,400,000,000
Nicor Gas
Line of Credit Facility [Line Items]
Total	$ 500,000,000

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Financing - Schedule of Long-Term Debt Financing Activities (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Debt Instrument [Line Items]
Senior Note Maturities, Redemptions, and Repurchases	$ 2,300
Revenue Bond Issuances and Reofferings of Purchased Bonds	386
Revenue Bond Maturities, Redemptions, and Repurchases	108
Other Long-Term Debt Issuances	835
Other Long-Term Debt Redemptions and Maturities	21
Southern Company
Debt Instrument [Line Items]
Senior Note Maturities, Redemptions, and Repurchases	2,100
Revenue Bond Issuances and Reofferings of Purchased Bonds	0
Revenue Bond Maturities, Redemptions, and Repurchases	0
Other Long-Term Debt Issuances	0
Other Long-Term Debt Redemptions and Maturities	0
ALABAMA POWER CO
Debt Instrument [Line Items]
Senior Note Maturities, Redemptions, and Repurchases	200
Revenue Bond Issuances and Reofferings of Purchased Bonds	0
Revenue Bond Maturities, Redemptions, and Repurchases	0
Other Long-Term Debt Issuances	0
Other Long-Term Debt Redemptions and Maturities	0
GEORGIA POWER CO
Debt Instrument [Line Items]
Senior Note Maturities, Redemptions, and Repurchases	0
Revenue Bond Issuances and Reofferings of Purchased Bonds	343
Revenue Bond Maturities, Redemptions, and Repurchases	108
Other Long-Term Debt Issuances	835
Other Long-Term Debt Redemptions and Maturities	2
MISSISSIPPI POWER CO
Debt Instrument [Line Items]
Senior Note Maturities, Redemptions, and Repurchases	0
Revenue Bond Issuances and Reofferings of Purchased Bonds	43
Revenue Bond Maturities, Redemptions, and Repurchases	0
Other Long-Term Debt Issuances	0
Other Long-Term Debt Redemptions and Maturities	0
Other
Debt Instrument [Line Items]
Senior Note Maturities, Redemptions, and Repurchases	0
Revenue Bond Issuances and Reofferings of Purchased Bonds	0
Revenue Bond Maturities, Redemptions, and Repurchases	0
Other Long-Term Debt Issuances	0
Other Long-Term Debt Redemptions and Maturities	$ 19

XML

Financing - Shares Used to Compute Diluted Earnings Per Share (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Debt Disclosure [Abstract]
As reported shares	1,038	1,011
Effect of stock-based compensation	7	5
Diluted shares	1,045	1,016

XML

Income Taxes (Details)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	39.80%	10.80%
ALABAMA POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	21.90%	26.30%
MISSISSIPPI POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	15.50%	(34.70%)
SOUTHERN POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	(49.80%)	(647.00%)
SOUTHERN Co GAS
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	22.30%	27.20%

XML

Retirement Benefits (Details) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Amortization:
Net (gain)/loss
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, expected future employer contributions, remainder of fiscal year	$ 0
Pension Plans | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	17,000,000	19,000,000
Interest cost	28,000,000	25,000,000
Expected return on plan assets	(51,000,000)	(51,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	9,000,000	14,000,000
Net periodic pension cost (income)	3,000,000	7,000,000
Pension Plans | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	19,000,000	22,000,000
Interest cost	39,000,000	35,000,000
Expected return on plan assets	(73,000,000)	(74,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	11,000,000	17,000,000
Net periodic pension cost (income)	(4,000,000)	0
Pension Plans | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	3,000,000	4,000,000
Interest cost	6,000,000	5,000,000
Expected return on plan assets	(10,000,000)	(10,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	1,000,000	3,000,000
Net periodic pension cost (income)	0	2,000,000
Pension Plans | SOUTHERN POWER CO
Pension Plans and Postretirement Plans
Service cost	2,000,000	2,000,000
Interest cost	1,000,000	1,000,000
Expected return on plan assets	(2,000,000)	(3,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	0	1,000,000
Net periodic pension cost (income)	1,000,000	1,000,000
Pension Plans | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	6,000,000	8,000,000
Interest cost	9,000,000	10,000,000
Expected return on plan assets	(15,000,000)	(18,000,000)
Amortization:
Prior service costs	(1,000,000)	(1,000,000)
Regulatory asset	3,000,000	3,000,000
Net (gain)/loss	1,000,000	3,000,000
Net periodic pension cost (income)	3,000,000	5,000,000
Pension Plans | Southern Company
Pension Plans and Postretirement Plans
Service cost	73,000,000	90,000,000
Interest cost	123,000,000	116,000,000
Expected return on plan assets	(221,000,000)	(236,000,000)
Amortization:
Prior service costs	0	1,000,000
Regulatory asset	0	0
Net (gain)/loss	30,000,000	53,000,000
Net periodic pension cost (income)	5,000,000	24,000,000
Postretirement Benefits | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	1,000,000	1,000,000
Interest cost	4,000,000	4,000,000
Expected return on plan assets	(6,000,000)	(6,000,000)
Amortization:
Prior service costs	1,000,000	1,000,000
Regulatory asset	0	0
Net (gain)/loss	0	0
Net periodic pension cost (income)	0	0
Postretirement Benefits | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	1,000,000	2,000,000
Interest cost	7,000,000	7,000,000
Expected return on plan assets	(6,000,000)	(6,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	0	2,000,000
Net periodic pension cost (income)	2,000,000	5,000,000
Postretirement Benefits | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	0	0
Interest cost	1,000,000	1,000,000
Expected return on plan assets	0	0
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	0	0
Net periodic pension cost (income)	1,000,000	1,000,000
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:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	0	0
Net periodic pension cost (income)	0	0
Postretirement Benefits | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	1,000,000	1,000,000
Interest cost	2,000,000	2,000,000
Expected return on plan assets	(2,000,000)	(2,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	2,000,000	1,000,000
Net (gain)/loss	(1,000,000)	0
Net periodic pension cost (income)	2,000,000	2,000,000
Postretirement Benefits | Southern Company
Pension Plans and Postretirement Plans
Service cost	5,000,000	6,000,000
Interest cost	17,000,000	19,000,000
Expected return on plan assets	(16,000,000)	(17,000,000)
Amortization:
Prior service costs	1,000,000	2,000,000
Regulatory asset	0	0
Net (gain)/loss	(1,000,000)	3,000,000
Net periodic pension cost (income)	$ 6,000,000	$ 13,000,000

XML

Fair Value Measurements - Assets and Liabilities Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Assets:
Derivatives	$ 159	$ 313
Liabilities:
Derivatives	131	235
Collateral already posted, aggregate fair value	190
ALABAMA POWER CO
Assets:
Derivatives	1	2
Liabilities:
Derivatives	2	6
GEORGIA POWER CO
Assets:
Derivatives	1	0
Investments in trusts	72
Liabilities:
Derivatives	10	17
MISSISSIPPI POWER CO
Assets:
Derivatives	0	1
Liabilities:
Derivatives	3	7
SOUTHERN POWER CO
Assets:
Derivatives	38	76
Liabilities:
Derivatives	26	28
SOUTHERN Co GAS
Assets:
Derivatives	118	233
Liabilities:
Derivatives	56	124
Collateral already posted, aggregate fair value	190	$ 277
Fair Value, Measurements, Recurring
Assets:
Cash equivalents	910
Other investments	23
Total	3,327
Liabilities:
Contingent consideration	21
Total	675
Fair Value, Measurements, Recurring | Weather Derivative
Liabilities:
Derivatives	11
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	907
Other investments	9
Total	2,033
Liabilities:
Contingent consideration	0
Total	466
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	3
Other investments	14
Total	1,242
Liabilities:
Contingent consideration	0
Total	165
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Other investments	0
Total	4
Liabilities:
Contingent consideration	21
Total	44
Fair Value, Measurements, Recurring | Net Asset Value as a Practical Expedient (NAV)
Assets:
Total	48
Fair Value, Measurements, Recurring | Energy-related derivatives
Assets:
Derivatives	454
Liabilities:
Derivatives	595
Fair Value, Measurements, Recurring | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	322
Liabilities:
Derivatives	466
Fair Value, Measurements, Recurring | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	128
Liabilities:
Derivatives	106
Fair Value, Measurements, Recurring | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	4
Liabilities:
Derivatives	23
Fair Value, Measurements, Recurring | Interest rate derivatives
Liabilities:
Derivatives	35
Fair Value, Measurements, Recurring | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	35
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Foreign currency derivatives
Assets:
Derivatives	38
Liabilities:
Derivatives	24
Fair Value, Measurements, Recurring | Foreign currency derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Foreign currency derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	38
Liabilities:
Derivatives	24
Fair Value, Measurements, Recurring | Foreign currency derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Domestic equity
Assets:
Investments in trusts	802
Fair Value, Measurements, Recurring | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	682
Fair Value, Measurements, Recurring | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	120
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	255
Fair Value, Measurements, Recurring | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	60
Fair Value, Measurements, Recurring | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	195
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	283
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	283
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	73
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	73
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	14
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	14
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	322
Fair Value, Measurements, Recurring | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	24
Fair Value, Measurements, Recurring | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	298
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	72
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	72
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	48
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	48
Fair Value, Measurements, Recurring | Cash and cash equivalents
Assets:
Investments in trusts	1
Fair Value, Measurements, Recurring | Cash and cash equivalents | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	1
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	32
Fair Value, Measurements, Recurring | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	28
Fair Value, Measurements, Recurring | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	4
Fair Value, Measurements, Recurring | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO
Assets:
Cash equivalents	572
Other investments	14
Total	1,522
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	569
Other investments	0
Total	1,104
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	3
Other investments	14
Total	370
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	48
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives
Assets:
Derivatives	6
Liabilities:
Derivatives	7
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	6
Liabilities:
Derivatives	7
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	554
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	446
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	108
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	117
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	60
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	57
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	18
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	18
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	163
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	24
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	139
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	24
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	24
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	48
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	48
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other
Assets:
Investments in trusts	5
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	5
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO
Assets:
Total	951
Liabilities:
Total	18
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Total	259
Liabilities:
Total	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Total	692
Liabilities:
Total	18
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	9
Liabilities:
Derivatives	16
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	9
Liabilities:
Derivatives	16
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	2
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	2
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	237
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	236
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	134
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	134
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	265
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	265
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	72
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	72
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	160
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	160
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	47
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	47
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	27
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	23
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	4
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	202
Total	205
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	202
Total	202
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	3
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	3
Liabilities:
Derivatives	6
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	3
Liabilities:
Derivatives	6
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	10
Total	49
Liabilities:
Contingent consideration	21
Total	48
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	10
Total	10
Liabilities:
Contingent consideration	0
Total	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	39
Liabilities:
Contingent consideration	0
Total	27
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Total	0
Liabilities:
Contingent consideration	21
Total	21
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives
Assets:
Derivatives	1
Liabilities:
Derivatives	3
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	1
Liabilities:
Derivatives	3
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
Assets:
Derivatives	38
Liabilities:
Derivatives	24
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	38
Liabilities:
Derivatives	24
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS
Assets:
Cash equivalents	13
Total	477
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	13
Total	336
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	0
Total	137
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Total	4
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives
Assets:
Derivatives	434
Liabilities:
Derivatives	562
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	322
Liabilities:
Derivatives	466
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	108
Liabilities:
Derivatives	73
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	4
Liabilities:
Derivatives	23
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity
Assets:
Non-qualified deferred compensation trusts	11
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	11
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	4
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	4
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	14
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	14
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 and cash equivalents
Assets:
Non-qualified deferred compensation trusts	1
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash and cash equivalents | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	1
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash and cash equivalents | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash and 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, 2019	Mar. 31, 2018
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ 152	$ (11)
ALABAMA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	87	(5)
GEORGIA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ 65	$ (6)

XML

Fair Value Measurements - Narrative (Details) $ in Millions	Mar. 31, 2019 USD ($) $ / MMBTU	Dec. 31, 2018 USD ($)
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Derivatives	$ 131	$ 235
ALABAMA POWER CO
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Derivatives	2	6
ALABAMA POWER CO | Private equity
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Fair value	48
Unfunded commitments	49
SOUTHERN Co GAS
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Derivatives	56	$ 124
SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | Energy-related derivatives
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Fair value of derivatives	$ 19
SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | Energy-related derivatives | Forward Price | Valuation, Market Approach | Minimum
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Measurement input (usd per mmbtu) | $ / MMBTU	0.07
SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3) | Energy-related derivatives | Forward Price | Valuation, Market Approach | Maximum
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Measurement input (usd per mmbtu) | $ / MMBTU	1.15

XML

Fair Value Measurements - Financial Instruments for which Carrying Amount did not Equal Fair Value (Details) $ in Millions	Mar. 31, 2019 USD ($)
Long-term debt, including securities due within one year:
Carrying amount	$ 42,535
Fair value	43,910
ALABAMA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	7,921
Fair value	8,424
GEORGIA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	10,910
Fair value	11,249
MISSISSIPPI POWER CO
Long-term debt, including securities due within one year:
Carrying amount	1,619
Fair value	1,619
SOUTHERN POWER CO
Long-term debt, including securities due within one year:
Carrying amount	4,995
Fair value	5,131
SOUTHERN Co GAS
Long-term debt, including securities due within one year:
Carrying amount	5,928
Fair value	$ 6,176

XML

Fair Value Measurements - Fair Value of Commodity Derivative Contracts that Include a Significant Unobservable Component (Details) - SOUTHERN Co GAS $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 0
Transfers to Level 3	(30)
Changes in fair value	11
Ending balance	$ (19)

XML

Derivatives - Energy-Related and Interest Rate Derivatives (Details) MMBTU in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) MMBTU
Energy-related, Natural Gas
Energy-related derivative contracts
Net Purchased mmBtu | MMBTU	538
Interest rate derivatives
Interest rate derivatives
Notional Amount | $	$ 2,000,000,000
Fair Value Gain (Loss) at March 31, 2019 | $	(35,000,000)
Southern Company | Interest rate derivatives | June 2020 | Fair Value Hedges of Existing Debt
Interest rate derivatives
Notional Amount | $	$ 300,000,000
Interest Rate Received	2.75%
Fair Value Gain (Loss) at March 31, 2019 | $	$ (3,000,000)
Southern Company | Interest rate derivatives | July 2021 | Fair Value Hedges of Existing Debt
Interest rate derivatives
Notional Amount | $	$ 1,500,000,000
Interest Rate Received	2.35%
Fair Value Gain (Loss) at March 31, 2019 | $	$ (30,000,000)
Southern Company | LIBOR | Interest rate derivatives | June 2020 | Fair Value Hedges of Existing Debt
Interest rate derivatives
Weighted Average Interest Rate Paid	0.92%
Southern Company | LIBOR | Interest rate derivatives | July 2021 | Fair Value Hedges of Existing Debt
Interest rate derivatives
Weighted Average Interest Rate Paid	0.87%
ALABAMA POWER CO | Energy-related, Natural Gas
Energy-related derivative contracts
Net Purchased mmBtu | MMBTU	72
GEORGIA POWER CO | Energy-related, Natural Gas
Energy-related derivative contracts
Net Purchased mmBtu | MMBTU	153
GEORGIA POWER CO | Interest rate derivatives | December 2019 | Fair Value Hedges of Existing Debt
Interest rate derivatives
Notional Amount | $	$ 200,000,000
Interest Rate Received	4.25%
Fair Value Gain (Loss) at March 31, 2019 | $	$ (2,000,000)
GEORGIA POWER CO | LIBOR | Interest rate derivatives | December 2019 | Fair Value Hedges of Existing Debt
Interest rate derivatives
Weighted Average Interest Rate Paid	2.46%
MISSISSIPPI POWER CO | Energy-related, Natural Gas
Energy-related derivative contracts
Net Purchased mmBtu | MMBTU	61
SOUTHERN POWER CO | Energy-related, Natural Gas
Energy-related derivative contracts
Net Purchased mmBtu | MMBTU	9
SOUTHERN Co GAS | Energy-related, Natural Gas
Energy-related derivative contracts
Net Purchased mmBtu | MMBTU	243
SOUTHERN Co GAS | Energy-related, Natural Gas | Derivatives not designated as hedging instruments | Long
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume | MMBTU	3,800
SOUTHERN Co GAS | Energy-related, Natural Gas | Derivatives not designated as hedging instruments | Short
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume | MMBTU	3,600

XML

Derivatives - Narrative (Details) MMBTU in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) MMBTU	Dec. 31, 2018 USD ($)
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	40
Cash flow hedge gain (loss) to be reclassified within twelve months	$ (19,000,000)
Collateral already posted, aggregate fair value	$ 190,000,000
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
Cash flow hedge gain (loss) to be reclassified within twelve months	$ 0
GEORGIA POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	12
Cash flow hedge gain (loss) to be reclassified within twelve months	$ 0
MISSISSIPPI POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	5
Cash flow hedge gain (loss) to be reclassified within twelve months	$ 0
SOUTHERN POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	13
Cash flow hedge gain (loss) to be reclassified within twelve months	$ 0
Parent Company and Southern Power
Derivative [Line Items]
Foreign currency cash flow hedge gain (loss) to be reclassified during next 12 months	(24,000,000)
Registrants | Derivative Counterparties
Derivative [Line Items]
Collateral already posted, aggregate fair value	0
SOUTHERN Co GAS
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	0
Collateral already posted, aggregate fair value	$ 190,000,000	$ 277,000,000

XML

Derivatives - Foreign Currency Derivatives (Details) - 3 months ended Mar. 31, 2019 - Cash Flow Hedges of Existing Debt - Foreign currency derivatives € in Millions, $ in Millions	USD ($)	EUR (€)
Derivative [Line Items]
Pay Notional	$ 1,241
Receive Notional | €		€ 1,100
Fair Value Gain (Loss) at March 31, 2019	13
SOUTHERN POWER CO | June 2022
Derivative [Line Items]
Pay Notional	$ 677
Pay Rate	2.95%
Receive Notional | €		600
Receive Rate	1.00%
Fair Value Gain (Loss) at March 31, 2019	$ 2
SOUTHERN POWER CO | June 2026
Derivative [Line Items]
Pay Notional	$ 564
Pay Rate	3.78%
Receive Notional | €		€ 500
Receive Rate	1.85%
Fair Value Gain (Loss) at March 31, 2019	$ 11

XML

Derivatives - Derivative Financial Statement Presentation and Amounts With Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivatives, assets	$ 492	$ 837
Derivatives, liabilities	654	1,036
Derivative asset, Gross amounts offset	(333)	(524)
Derivative liability, Gross amounts offset	(523)	(801)
Derivative asset	159	313
Derivative liability	131	235
Collateral already posted, aggregate fair value	190
Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivatives, assets	430	741
Derivatives, liabilities	560	900
Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	259	561
Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	291	575
Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	171	180
Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	269	325
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges
Derivatives, Fair Value [Line Items]
Derivatives, assets	23	17
Derivatives, liabilities	31	55
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	12	8
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	10	23
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	11	9
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	21	26
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivatives, assets	39	79
Derivatives, liabilities	63	81
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	1	3
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	3	7
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	1
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	1	2
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	20	19
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	15	30
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	24	23
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	38	75
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	0	0
ALABAMA POWER CO
Derivatives, Fair Value [Line Items]
Derivatives, assets	6	6
Derivatives, liabilities	7	10
Derivative asset, Gross amounts offset	(5)	(4)
Derivative liability, Gross amounts offset	(5)	(4)
Derivative asset	1	2
Derivative liability	2	6
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivatives, assets	6	6
Derivatives, liabilities	7	10
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	3	3
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	2	4
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	3	3
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	5	6
GEORGIA POWER CO
Derivatives, Fair Value [Line Items]
Derivatives, assets	9	6
Derivatives, liabilities	18	23
Derivative asset, Gross amounts offset	(8)	(6)
Derivative liability, Gross amounts offset	(8)	(6)
Derivative asset	1	0
Derivative liability	10	17
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivatives, assets	9	6
Derivatives, liabilities	16	21
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	4	2
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	5	8
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	5	4
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	11	13
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
Derivatives, liabilities	2	2
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	2	2
MISSISSIPPI POWER CO
Derivatives, Fair Value [Line Items]
Derivatives, assets	3	3
Derivatives, liabilities	6	9
Derivative asset, Gross amounts offset	(3)	(2)
Derivative liability, Gross amounts offset	(3)	(2)
Derivative asset	0	1
Derivative liability	3	7
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivatives, assets	3	3
Derivatives, liabilities	6	9
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	2	1
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	2	3
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	1	2
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	4	6
SOUTHERN POWER CO
Derivatives, Fair Value [Line Items]
Derivatives, assets	39	79
Derivatives, liabilities	27	31
Derivative asset, Gross amounts offset	(1)	(3)
Derivative liability, Gross amounts offset	(1)	(3)
Derivative asset	38	76
Derivative liability	26	28
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivatives, assets	39	79
Derivatives, liabilities	27	31
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	1	3
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	2	6
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	1
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	1	2
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Under recovered fuel balance
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	24	23
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	38	75
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	0	0
SOUTHERN Co GAS
Derivatives, Fair Value [Line Items]
Derivatives, assets	434	741
Derivatives, liabilities	562	909
Derivative asset, Gross amounts offset	(316)	(508)
Derivative liability, Gross amounts offset	(506)	(785)
Derivative asset	118	233
Derivative liability	56	124
Collateral already posted, aggregate fair value	190	277
Weather derivative premium	11	8
SOUTHERN Co GAS | Gain (loss) on energy-related cash flow hedges
Derivatives, Fair Value [Line Items]
Collateral already posted, aggregate fair value	2
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges
Derivatives, Fair Value [Line Items]
Derivatives, assets	430	739
Derivatives, liabilities	560	899
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	171	180
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	269	325
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivatives, assets	259	559
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Gain (loss) on energy-related cash flow hedges | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	291	574
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges
Derivatives, Fair Value [Line Items]
Derivatives, assets	4	2
Derivatives, liabilities	1	9
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivatives, assets	1	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	0	1
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivatives, assets	3	2
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	1	8
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
Derivatives, liabilities	1	1
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	1	1
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Assets held for sale, current
Derivatives, Fair Value [Line Items]
Derivatives, assets	0	0
Southern Company | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Gain (loss) on energy-related cash flow hedges | Liabilities held for sale, current
Derivatives, Fair Value [Line Items]
Derivatives, liabilities	$ 0	$ 6

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Derivatives - Pre-tax Effects of Derivatives Designated as Cash Flow Hedging Instruments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Collateral already posted, aggregate fair value	$ 190
Gain (Loss) Recognized in OCI on Derivative	(39)	$ 63
SOUTHERN POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(39)	64
SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Collateral already posted, aggregate fair value	190		$ 277
Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(9)		(40)
Gain (Loss) Recognized in OCI on Derivative	0	12
Energy-related derivatives | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(5)		(19)
Energy-related derivatives | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(11)		(16)
Energy-related derivatives | Assets held for sale, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)			(6)
Energy-related derivatives | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	7		1
Energy-related derivatives | ALABAMA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(2)		(6)
Energy-related derivatives | ALABAMA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(1)		(3)
Energy-related derivatives | ALABAMA POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(2)		(3)
Energy-related derivatives | ALABAMA POWER CO | Assets held for sale, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)			0
Energy-related derivatives | ALABAMA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	1		0
Energy-related derivatives | GEORGIA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(7)		(15)
Energy-related derivatives | GEORGIA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(2)		(6)
Energy-related derivatives | GEORGIA POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(6)		(9)
Energy-related derivatives | GEORGIA POWER CO | Assets held for sale, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)			0
Energy-related derivatives | GEORGIA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	1		0
Energy-related derivatives | MISSISSIPPI POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(3)		(6)
Energy-related derivatives | MISSISSIPPI POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(1)		(2)
Energy-related derivatives | MISSISSIPPI POWER CO | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(3)		(4)
Energy-related derivatives | MISSISSIPPI POWER CO | Assets held for sale, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)			0
Energy-related derivatives | MISSISSIPPI POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	1		0
Energy-related derivatives | SOUTHERN POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	0	11
Energy-related derivatives | SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	3		(7)
Collateral already posted, aggregate fair value	2
Energy-related derivatives | SOUTHERN Co GAS | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	(1)		(8)
Energy-related derivatives | SOUTHERN Co GAS | Other regulatory assets, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	0		0
Energy-related derivatives | SOUTHERN Co GAS | Assets held for sale, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)			0
Energy-related derivatives | SOUTHERN Co GAS | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	4		$ 1
Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	0	(2)
Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(39)	53
Foreign currency derivatives | SOUTHERN POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	$ (39)	$ 53

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Derivatives - Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Derivative [Line Items]
Depreciation and amortization	$ 751	$ 769
Total interest expense, net of amounts capitalized	(430)	(458)
Total other income (expense), net	78	60
Cash Flow Hedging | Gain (loss) on energy-related cash flow hedges | Total depreciation and amortization
Derivative [Line Items]
Gain (loss) on hedge	(3)	1
Cash Flow Hedging | Interest rate derivatives | Total interest expense, net of amounts capitalized
Derivative [Line Items]
Gain (loss) on hedge	(5)	(5)
Cash Flow Hedging | Foreign currency derivatives | Total interest expense, net of amounts capitalized
Derivative [Line Items]
Gain (loss) on hedge	(6)	(5)
Cash Flow Hedging | Foreign currency derivatives | Total other income (expense), net
Derivative [Line Items]
Gain (loss) on hedge	(24)	36
Fair Value Hedging | Interest rate derivatives | Total interest expense, net of amounts capitalized
Derivative [Line Items]
Gain (loss) on hedge	14	(24)
SOUTHERN POWER CO
Derivative [Line Items]
Depreciation and amortization	119	114
Total interest expense, net of amounts capitalized	(44)	(47)
Total other income (expense), net	2	3
SOUTHERN POWER CO | Cash Flow Hedging | Gain (loss) on energy-related cash flow hedges | Total depreciation and amortization
Derivative [Line Items]
Gain (loss) on hedge	(3)	1
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Total interest expense, net of amounts capitalized
Derivative [Line Items]
Gain (loss) on hedge	(6)	(5)
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Total other income (expense), net
Derivative [Line Items]
Gain (loss) on hedge	(24)	36
SOUTHERN Co GAS
Derivative [Line Items]
Depreciation and amortization	118	129
Total interest expense, net of amounts capitalized	(59)	(59)
Total other income (expense), net	$ 5	$ 12

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Derivatives - Cumulative Basis Adjustments for Fair Value Hedges (Details) - Fair Value Hedging - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Securities due within one year
Derivative [Line Items]
Carrying Amount of the Hedged Item	$ (499)	$ (498)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	1	2
Securities due within one year | GEORGIA POWER CO
Derivative [Line Items]
Carrying Amount of the Hedged Item	(499)	(498)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	1	2
Long-term debt
Derivative [Line Items]
Carrying Amount of the Hedged Item	(2,065)	(2,052)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	28	41
Long-term debt | GEORGIA POWER CO
Derivative [Line Items]
Carrying Amount of the Hedged Item	0	0
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	$ 0	$ 0

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Derivatives - Pre-tax Effects of Derivatives Not Designated as Hedging (Details) - Derivatives not designated as hedging instruments - Energy-related derivatives - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 41	$ (13)
Natural gas revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	33	(15)
Total cost of natural gas
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	8	2
SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	41	(13)
SOUTHERN Co GAS | Natural gas revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	33	(15)
SOUTHERN Co GAS | Total cost of natural gas
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 8	$ 2

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Acquisitions and Dispositions - Southern Company's Sale of Gulf Power (Details) - USD ($) $ in Millions		3 Months Ended		12 Months Ended
	Jan. 01, 2019	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Preliminary gain		$ 2,503	$ (1)
Disposal Group, Disposed of by Sale, Not Discontinued Operations | GULF POWER CO
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from divestiture of businesses, net of cash divested	$ 5,800
Amount of indebtedness assumed at closing	$ 1,300
Disposal Group, Disposed of by Sale, Not Discontinued Operations | GULF POWER CO | Scenario, Forecast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Preliminary gain				$ 2,500
Preliminary gain, net of tax				$ 1,300

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Acquisitions and Dispositions - Southern Power Narrative (Details) $ in Millions	14 Months Ended
	Dec. 31, 2019 USD ($) MW	May 31, 2019 MW	Mar. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Business Acquisition [Line Items]
Construction work in progress			$ 7,598	$ 7,254
Property, plant, and equipment, subject to lien			114,096	116,914
SOUTHERN POWER CO
Business Acquisition [Line Items]
Construction work in progress			409	430
Property, plant, and equipment, subject to lien			15,104	$ 14,883
SOUTHERN POWER CO | Lien
Business Acquisition [Line Items]
Property, plant, and equipment, subject to lien			538
SOUTHERN POWER CO | Disposal Group, Held-for-sale, Not Discontinued Operations | Mankato expansion | Scenario, Forecast
Business Acquisition [Line Items]
Proceeds from divestiture of businesses, net of cash divested	$ 650
Approximate nameplate capacity (MW) | MW	385
SOUTHERN POWER CO | Disposal Group, Held-for-sale, Not Discontinued Operations | Nacogdoches Biomass-Fueled Facility | Subsequent Event | Scenario, Forecast
Business Acquisition [Line Items]
Nacogdoches biomass-fueled facility	$ 460
SOUTHERN POWER CO | Wind Generating Facility
Business Acquisition [Line Items]
Equipment marketed for sale			53
SOUTHERN POWER CO | Series of Construction Projects
Business Acquisition [Line Items]
Construction work in progress			347
SOUTHERN POWER CO | Series of Construction Projects | Minimum
Business Acquisition [Line Items]
Estimated future construction payments			575
SOUTHERN POWER CO | Series of Construction Projects | Maximum
Business Acquisition [Line Items]
Estimated future construction payments			$ 640
SOUTHERN POWER CO | Mankato expansion | Scenario, Forecast
Business Acquisition [Line Items]
Approximate nameplate capacity (MW) | MW		385

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Acquisitions and Dispositions - Schedule of Construction Projects (Details) - SOUTHERN POWER CO - MW	1 Months Ended	3 Months Ended
	May 31, 2019	Jun. 30, 2020	Dec. 31, 2019	Aug. 31, 2018	May 31, 2018
Wild Horse Mountain | Wild Horse Mountain
Business Acquisition [Line Items]
Ownership percentage by parent					100.00%
Wild Horse Mountain | Wild Horse Mountain | Class B Membership Interest
Business Acquisition [Line Items]
Ownership percentage by parent					100.00%
Reading | Reading
Business Acquisition [Line Items]
Ownership percentage by parent				100.00%
Reading | Reading | Class B Membership Interest
Business Acquisition [Line Items]
Ownership percentage by parent				100.00%
Scenario, Forecast | Mankato expansion
Business Acquisition [Line Items]
Approximate Nameplate Capacity (MW)	385
PPA Contract Period	20 years
Scenario, Forecast | Wild Horse Mountain
Business Acquisition [Line Items]
Approximate Nameplate Capacity (MW)			100
PPA Contract Period			20 years
Scenario, Forecast | Reading
Business Acquisition [Line Items]
Approximate Nameplate Capacity (MW)		200
PPA Contract Period		12 years

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Acquisitions and Dispositions - Assets Held for Sale (Details) - USD ($) $ in Millions	Mar. 31, 2019	Dec. 31, 2018
Assets Held for Sale:
Current assets	$ 55	$ 393
Liabilities Held for Sale:
Current liabilities	38	425
Other non-current liabilities	39	2,836
SOUTHERN POWER CO
Liabilities Held for Sale:
Current liabilities	9	15
Disposal Group, Held-for-sale, Not Discontinued Operations
Assets Held for Sale:
Current assets	55	393
Total property, plant, and equipment	637	4,583
Goodwill and other intangible assets	82	40
Other non-current assets	44	727
Total Assets Held for Sale	818	5,743
Liabilities Held for Sale:
Current liabilities	38	425
Long-term debt		1,286
Accumulated deferred income taxes		618
Other non-current liabilities	39	932
Total Liabilities Held for Sale	77	3,261
Disposal Group, Held-for-sale, Not Discontinued Operations | SOUTHERN POWER CO
Assets Held for Sale:
Current assets	11	8
Total property, plant, and equipment	604	536
Goodwill and other intangible assets	40	40
Other non-current assets	0	0
Total Assets Held for Sale	655	584
Liabilities Held for Sale:
Current liabilities	9	15
Long-term debt		0
Accumulated deferred income taxes		0
Other non-current liabilities	0	0
Total Liabilities Held for Sale	$ 9	$ 15

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Acquisitions and Dispositions - Pre-tax Profit (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018 USD ($)
GULF POWER CO
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Earnings before income taxes	$ 55
SOUTHERN POWER CO | Florida Plants
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Earnings before income taxes	$ 8

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Leases - Major Categories of Lease Obligations (Details) $ in Millions	Mar. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Lease obligations	$ 2,236
Electric generating units
Lessee, Lease, Description [Line Items]
Lease obligations	1,094
Real estate/land
Lessee, Lease, Description [Line Items]
Lease obligations	803
Communication towers
Lessee, Lease, Description [Line Items]
Lease obligations	131
Railcars
Lessee, Lease, Description [Line Items]
Lease obligations	55
Other
Lessee, Lease, Description [Line Items]
Lease obligations	153
ALABAMA POWER CO
Lessee, Lease, Description [Line Items]
Lease obligations	198
ALABAMA POWER CO | Electric generating units
Lessee, Lease, Description [Line Items]
Lease obligations	159
ALABAMA POWER CO | Real estate/land
Lessee, Lease, Description [Line Items]
Lease obligations	3
ALABAMA POWER CO | Communication towers
Lessee, Lease, Description [Line Items]
Lease obligations	1
ALABAMA POWER CO | Railcars
Lessee, Lease, Description [Line Items]
Lease obligations	25
ALABAMA POWER CO | Other
Lessee, Lease, Description [Line Items]
Lease obligations	10
GEORGIA POWER CO
Lessee, Lease, Description [Line Items]
Lease obligations	1,714
GEORGIA POWER CO | Electric generating units
Lessee, Lease, Description [Line Items]
Lease obligations	1,606
GEORGIA POWER CO | Real estate/land
Lessee, Lease, Description [Line Items]
Lease obligations	63
GEORGIA POWER CO | Communication towers
Lessee, Lease, Description [Line Items]
Lease obligations	3
GEORGIA POWER CO | Railcars
Lessee, Lease, Description [Line Items]
Lease obligations	26
GEORGIA POWER CO | Other
Lessee, Lease, Description [Line Items]
Lease obligations	16
MISSISSIPPI POWER CO
Lessee, Lease, Description [Line Items]
Lease obligations	8
MISSISSIPPI POWER CO | Electric generating units
Lessee, Lease, Description [Line Items]
Lease obligations	0
MISSISSIPPI POWER CO | Real estate/land
Lessee, Lease, Description [Line Items]
Lease obligations	2
MISSISSIPPI POWER CO | Communication towers
Lessee, Lease, Description [Line Items]
Lease obligations	0
MISSISSIPPI POWER CO | Railcars
Lessee, Lease, Description [Line Items]
Lease obligations	3
MISSISSIPPI POWER CO | Other
Lessee, Lease, Description [Line Items]
Lease obligations	3
SOUTHERN POWER CO
Lessee, Lease, Description [Line Items]
Lease obligations	393
SOUTHERN POWER CO | Electric generating units
Lessee, Lease, Description [Line Items]
Lease obligations	0
SOUTHERN POWER CO | Real estate/land
Lessee, Lease, Description [Line Items]
Lease obligations	393
SOUTHERN POWER CO | Communication towers
Lessee, Lease, Description [Line Items]
Lease obligations	0
SOUTHERN POWER CO | Railcars
Lessee, Lease, Description [Line Items]
Lease obligations	0
SOUTHERN POWER CO | Other
Lessee, Lease, Description [Line Items]
Lease obligations	0
SOUTHERN Co GAS
Lessee, Lease, Description [Line Items]
Lease obligations	84
SOUTHERN Co GAS | Electric generating units
Lessee, Lease, Description [Line Items]
Lease obligations	0
SOUTHERN Co GAS | Real estate/land
Lessee, Lease, Description [Line Items]
Lease obligations	83
SOUTHERN Co GAS | Communication towers
Lessee, Lease, Description [Line Items]
Lease obligations	0
SOUTHERN Co GAS | Railcars
Lessee, Lease, Description [Line Items]
Lease obligations	0
SOUTHERN Co GAS | Other
Lessee, Lease, Description [Line Items]
Lease obligations	$ 1

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Leases - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Remaining terms	13 years 6 months
Total estimate obligations of leases that have not yet commenced	$ 77
Maximum
Lessee, Lease, Description [Line Items]
Lease term, lease not yet commenced	30 years
Real estate | Maximum
Lessee, Lease, Description [Line Items]
Remaining terms	25 years
Communication towers | Maximum
Lessee, Lease, Description [Line Items]
Lessee, lease term	10 years
Lessee, renewal period	20 years
Fuel cells | Maximum
Lessee, Lease, Description [Line Items]
Lessor, lease term, operating lease	15 years
GEORGIA POWER CO
Lessee, Lease, Description [Line Items]
Remaining terms	10 years 1 month
Lease obligations	$ 1,543
GEORGIA POWER CO | Real estate | Maximum
Lessee, Lease, Description [Line Items]
Remaining terms	25 years
GEORGIA POWER CO | Electric generating units | Affiliate
Lessee, Lease, Description [Line Items]
Lease obligations	$ 670
GEORGIA POWER CO | Electric generating units | Minimum
Lessee, Lease, Description [Line Items]
Remaining terms	4 years
GEORGIA POWER CO | Electric generating units | Maximum
Lessee, Lease, Description [Line Items]
Remaining terms	18 years
GEORGIA POWER CO | Outdoor lighting | Maximum
Lessee, Lease, Description [Line Items]
Lessor, lease term, operating lease	5 years
SOUTHERN Co GAS
Lessee, Lease, Description [Line Items]
Remaining terms	9 years
Lease obligations	$ 84
SOUTHERN Co GAS | Maximum
Lessee, Lease, Description [Line Items]
Lessor, remaining term	24 years
SOUTHERN Co GAS | Real estate | Maximum
Lessee, Lease, Description [Line Items]
Remaining terms	25 years
SOUTHERN POWER CO
Lessee, Lease, Description [Line Items]
Remaining terms	33 years 8 months
Lease obligations	$ 393
Total estimate obligations of leases that have not yet commenced	$ 77
SOUTHERN POWER CO | Maximum
Lessee, Lease, Description [Line Items]
Lease term, lease not yet commenced	30 years
SOUTHERN POWER CO | Land | Maximum
Lessee, Lease, Description [Line Items]
Lessee, lease term	48 years
SOUTHERN POWER CO | Electric generating units | Maximum
Lessee, Lease, Description [Line Items]
Lessor, lease term, operating lease	28 years
ALABAMA POWER CO
Lessee, Lease, Description [Line Items]
Remaining terms	3 years 9 months
Lease obligations	$ 194
ALABAMA POWER CO | Electric generating units | Minimum
Lessee, Lease, Description [Line Items]
Remaining terms	4 years
ALABAMA POWER CO | Electric generating units | Maximum
Lessee, Lease, Description [Line Items]
Remaining terms	18 years
ALABAMA POWER CO | Outdoor lighting | Maximum
Lessee, Lease, Description [Line Items]
Lessor, lease term, operating lease	5 years
MISSISSIPPI POWER CO
Lessee, Lease, Description [Line Items]
Remaining terms	6 years 9 months
Lease obligations	$ 8
MISSISSIPPI POWER CO | Electric generating units | Maximum
Lessee, Lease, Description [Line Items]
Lessor, lease term, sales-type lease	20 years
MISSISSIPPI POWER CO | Outdoor lighting | Maximum
Lessee, Lease, Description [Line Items]
Lessor, lease term, operating lease	5 years

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Leases - Balance Sheet Amounts Recorded for Operating and Financing Leases (Details) $ in Millions	Mar. 31, 2019 USD ($)
Operating Leases
Operating lease ROU assets, net, including held for sale	$ 1,926
Operating lease ROU assets, net	1,881
Operating lease obligations - current, including held for sale	239
Operating lease obligations - current	226
Operating lease obligations - non current, including held for sale	1,752
Operating lease obligations - non current	1,720
Total operating lease obligations, including held for sale	1,991
Finance Leases
Finance lease ROU assets, net	242
Finance lease obligations - current	38
Finance lease obligations - noncurrent	207
Total finance lease obligations	245
ALABAMA POWER CO
Operating Leases
Operating lease ROU assets, net	160
Operating lease obligations - current	47
Operating lease obligations - non current	147
Total operating lease obligations	194
Finance Leases
Finance lease ROU assets, net	4
Finance lease obligations - current	1
Finance lease obligations - noncurrent	3
Total finance lease obligations	4
GEORGIA POWER CO
Operating Leases
Operating lease ROU assets, net	1,519
Operating lease obligations - current	139
Operating lease obligations - non current	1,404
Total operating lease obligations	1,543
Finance Leases
Finance lease ROU assets, net	145
Finance lease obligations - current	10
Finance lease obligations - noncurrent	161
Total finance lease obligations	171
MISSISSIPPI POWER CO
Operating Leases
Operating lease ROU assets, net	8
Operating lease obligations - current	3
Operating lease obligations - non current	5
Total operating lease obligations	8
Finance Leases
Finance lease ROU assets, net	0
Finance lease obligations - current	0
Finance lease obligations - noncurrent	0
Total finance lease obligations	0
SOUTHERN POWER CO
Operating Leases
Operating lease ROU assets, net	372
Operating lease obligations - current	22
Operating lease obligations - non current	371
Total operating lease obligations	393
Finance Leases
Finance lease ROU assets, net	0
Finance lease obligations - current	0
Finance lease obligations - noncurrent	0
Total finance lease obligations	0
SOUTHERN Co GAS
Operating Leases
Operating lease ROU assets, net	86
Operating lease obligations - current	13
Operating lease obligations - non current	71
Total operating lease obligations	84
Finance Leases
Finance lease ROU assets, net	0
Finance lease obligations - current	0
Finance lease obligations - noncurrent	0
Total finance lease obligations	$ 0

XML

Leases - Lease Costs (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Lease cost
Operating lease cost	$ 69
Finance lease cost:
Amortization of ROU assets	7
Interest on lease obligations	3
Total finance lease cost	10
Short-term lease costs	14
Variable lease cost	19
Sublease income	0
Total lease cost	112
ALABAMA POWER CO
Lease cost
Operating lease cost	7
Finance lease cost:
Amortization of ROU assets	0
Interest on lease obligations	0
Total finance lease cost	0
Short-term lease costs	5
Variable lease cost	0
Sublease income	0
Total lease cost	12
GEORGIA POWER CO
Lease cost
Operating lease cost	49
Finance lease cost:
Amortization of ROU assets	4
Interest on lease obligations	4
Total finance lease cost	8
Short-term lease costs	3
Variable lease cost	16
Sublease income	0
Total lease cost	76
MISSISSIPPI POWER CO
Lease cost
Operating lease cost	1
Finance lease cost:
Amortization of ROU assets	0
Interest on lease obligations	0
Total finance lease cost	0
Short-term lease costs	0
Variable lease cost	0
Sublease income	0
Total lease cost	1
SOUTHERN POWER CO
Lease cost
Operating lease cost	7
Finance lease cost:
Amortization of ROU assets	0
Interest on lease obligations	0
Total finance lease cost	0
Short-term lease costs	0
Variable lease cost	1
Sublease income	0
Total lease cost	8
SOUTHERN Co GAS
Lease cost
Operating lease cost	4
Finance lease cost:
Amortization of ROU assets	0
Interest on lease obligations	0
Total finance lease cost	0
Short-term lease costs	0
Variable lease cost	0
Sublease income	0
Total lease cost	$ 4

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Leases - Other Information (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$ 74
Operating cash flows from finance leases	6
Financing cash flows from finance leases	8
ROU assets obtained in exchange for new operating lease obligations	15
ROU assets obtained in exchange for new finance lease obligations	$ 29
Weighted-average remaining lease term in years:
Operating leases	13 years 6 months
Finance leases	18 years 6 months
Weighted-average discount rate:
Operating leases	4.49%
Finance leases	5.00%
ALABAMA POWER CO
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$ 13
Operating cash flows from finance leases	0
Financing cash flows from finance leases	0
ROU assets obtained in exchange for new operating lease obligations	2
ROU assets obtained in exchange for new finance lease obligations	$ 0
Weighted-average remaining lease term in years:
Operating leases	3 years 9 months
Finance leases	14 years 9 months
Weighted-average discount rate:
Operating leases	3.33%
Finance leases	3.75%
GEORGIA POWER CO
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$ 32
Operating cash flows from finance leases	13
Financing cash flows from finance leases	2
ROU assets obtained in exchange for new operating lease obligations	4
ROU assets obtained in exchange for new finance lease obligations	$ 28
Weighted-average remaining lease term in years:
Operating leases	10 years 1 month
Finance leases	11 years 3 months
Weighted-average discount rate:
Operating leases	4.42%
Finance leases	10.68%
MISSISSIPPI POWER CO
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$ 1
Operating cash flows from finance leases	0
Financing cash flows from finance leases	0
ROU assets obtained in exchange for new operating lease obligations	0
ROU assets obtained in exchange for new finance lease obligations	$ 0
Weighted-average remaining lease term in years:
Operating leases	6 years 9 months
Weighted-average discount rate:
Operating leases	4.03%
SOUTHERN POWER CO
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$ 7
Operating cash flows from finance leases	0
Financing cash flows from finance leases	0
ROU assets obtained in exchange for new operating lease obligations	0
ROU assets obtained in exchange for new finance lease obligations	$ 0
Weighted-average remaining lease term in years:
Operating leases	33 years 8 months
Weighted-average discount rate:
Operating leases	5.68%
SOUTHERN Co GAS
Cash paid for amounts included in the measurements of lease obligations:
Operating cash flows from operating leases	$ 4
Operating cash flows from finance leases	0
Financing cash flows from finance leases	0
ROU assets obtained in exchange for new operating lease obligations	0
ROU assets obtained in exchange for new finance lease obligations	$ 0
Weighted-average remaining lease term in years:
Operating leases	9 years
Weighted-average discount rate:
Operating leases	3.70%

XML

Leases - Maturities of Lease Liabilities (Details) $ in Millions	Mar. 31, 2019 USD ($)
Operating leases:
2019 (remaining)	$ 253
2020	291
2021	274
2022	263
2023	198
Thereafter	1,637
Total	2,916
Less: Present value discount	925
Operating lease obligations, including held for sale	1,991
Finance leases:
2019 (remaining)	24
2020	32
2021	26
2022	22
2023	18
Thereafter	273
Total	395
Less: Present value discount	150
Finance lease obligations	245
ALABAMA POWER CO
Operating leases:
2019 (remaining)	46
2020	53
2021	52
2022	52
2023	3
Thereafter	1
Total	207
Less: Present value discount	13
Operating lease obligations	194
Finance leases:
2019 (remaining)	1
2020	1
2021	1
2022	1
2023	1
Thereafter	0
Total	5
Less: Present value discount	1
Finance lease obligations	4
GEORGIA POWER CO
Operating leases:
2019 (remaining)	182
2020	202
2021	197
2022	195
2023	196
Thereafter	984
Total	1,956
Less: Present value discount	413
Operating lease obligations	1,543
Finance leases:
2019 (remaining)	22
2020	28
2021	25
2022	25
2023	25
Thereafter	165
Total	290
Less: Present value discount	119
Finance lease obligations	171
MISSISSIPPI POWER CO
Operating leases:
2019 (remaining)	2
2020	2
2021	1
2022	1
2023	1
Thereafter	2
Total	9
Less: Present value discount	1
Operating lease obligations	8
Finance leases:
2019 (remaining)	0
2020	0
2021	0
2022	0
2023	0
Thereafter	0
Total	0
Less: Present value discount	0
Finance lease obligations	0
SOUTHERN POWER CO
Operating leases:
2019 (remaining)	17
2020	22
2021	23
2022	23
2023	24
Thereafter	848
Total	957
Less: Present value discount	564
Operating lease obligations	393
Finance leases:
2019 (remaining)	0
2020	0
2021	0
2022	0
2023	0
Thereafter	0
Total	0
Less: Present value discount	0
Finance lease obligations	0
SOUTHERN Co GAS
Operating leases:
2019 (remaining)	12
2020	16
2021	16
2022	12
2023	10
Thereafter	36
Total	102
Less: Present value discount	18
Operating lease obligations	84
Finance leases:
2019 (remaining)	0
2020	0
2021	0
2022	0
2023	0
Thereafter	0
Total	0
Less: Present value discount	0
Finance lease obligations	$ 0

XML

Leases - Lease Income (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	$ 2
Lease income - operating leases	71
Variable lease income	66
Total lease income	139
GEORGIA POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0
Lease income - operating leases	19
Variable lease income	0
Total lease income	19
MISSISSIPPI POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	2
Lease income - operating leases	0
Variable lease income	0
Total lease income	2
SOUTHERN POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0
Lease income - operating leases	41
Variable lease income	72
Total lease income	113
SOUTHERN Co GAS
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0
Lease income - operating leases	9
Variable lease income	0
Total lease income	$ 9

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Leases - Undiscounted Cash Flows to be Received Under Tolling Arrangements Accounted for as Sales-type Leases (Details) $ in Millions	Mar. 31, 2019 USD ($)
Lessor, Lease, Description [Line Items]
2019 (remaining)	$ 11
2020	14
2021	14
2022	13
2023	12
Thereafter	135
Total undiscounted cash flows	199
Lease receivable	108
Difference between undiscounted cash flows and discounted cash flows	91
MISSISSIPPI POWER CO
Lessor, Lease, Description [Line Items]
2019 (remaining)	11
2020	14
2021	14
2022	13
2023	12
Thereafter	135
Total undiscounted cash flows	199
Lease receivable	108
Difference between undiscounted cash flows and discounted cash flows	$ 91

XML

Leases - Undiscounted Cash Flows to be Received Under PPAs Accounted for as Operating Leases (Details) $ in Millions	Mar. 31, 2019 USD ($)
Lessor, Lease, Description [Line Items]
2019 (remaining)	$ 163
2020	188
2021	183
2022	174
2023	171
Thereafter	1,809
Total	2,688
GEORGIA POWER CO
Lessor, Lease, Description [Line Items]
2019 (remaining)	20
2020	26
2021	18
2022	8
2023	2
Thereafter	0
Total	74
SOUTHERN POWER CO
Lessor, Lease, Description [Line Items]
2019 (remaining)	123
2020	128
2021	131
2022	134
2023	137
Thereafter	1,017
Total	1,670
SOUTHERN Co GAS
Lessor, Lease, Description [Line Items]
2019 (remaining)	26
2020	34
2021	34
2022	34
2023	34
Thereafter	498
Total	$ 660

XML

Segment and Related Information - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) state pipeline segment	Mar. 31, 2018 USD ($)
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	3
Total operating revenues	$ 5,412	$ 6,372
Natural gas
Segment Reporting Information [Line Items]
Total operating revenues	1,474	1,607
SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Total operating revenues	443	509
SOUTHERN POWER CO | Wholesale revenues, affiliates
Segment Reporting Information [Line Items]
Total operating revenues	87	83
SOUTHERN POWER CO | Traditional Electric Operating Companies | Wholesale revenues, affiliates
Segment Reporting Information [Line Items]
Total operating revenues	$ 87	83
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	4
Total operating revenues	$ 1,474	1,639
Number of reportable segments | segment	4
SOUTHERN Co GAS | Pipeline
Segment Reporting Information [Line Items]
Number of pipeline construction projects | pipeline	2
SOUTHERN Co GAS | SNG
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%
SOUTHERN Co GAS | Natural gas
Segment Reporting Information [Line Items]
Total operating revenues	$ 1,476	1,631
SOUTHERN Co GAS | Traditional Electric Operating Companies | Natural gas
Segment Reporting Information [Line Items]
Total operating revenues	0	0
SOUTHERN Co GAS | Southern Company | Natural gas
Segment Reporting Information [Line Items]
Total operating revenues	$ 17	$ 36

XML

Segment and Related Information - Financial Data for Business Segments (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($)	Mar. 31, 2018 USD ($) utility	Dec. 31, 2018 USD ($)
Segment Reporting Information [Line Items]
Operating revenues	$ 5,412	$ 6,372
Segment net income (loss)	2,084	938
Goodwill	5,284		$ 5,315
Total assets	114,096		116,914
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,474	1,639
Segment net income (loss)	270	279
Goodwill	5,015		5,015
Total assets	20,952		21,448
Goodwill impairment	0	$ 42
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Segment Reporting Information [Line Items]
Number of natural gas distribution utilities disposed | utility		3
Traditional Electric Operating Companies | GEORGIA POWER AND MISSISSIPPI POWER CO | Kemper County Energy Facility
Segment Reporting Information [Line Items]
Public utilities, property, plant and equipment, amount of loss (recovery) on plant abandonment	2	$ 44
Public utilities, property, plant and equipment, amount of loss (recovery) on plant abandonment after tax	1	33
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,474	1,639
SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Pivotal Home Solutions
Segment Reporting Information [Line Items]
Goodwill impairment		42
All Other | Disposal Group, Disposed of by Sale, Not Discontinued Operations | GULF POWER CO
Segment Reporting Information [Line Items]
Preliminary pre-tax gain	2,500
Preliminary after-tax gain	1,300
Gas Distribution Operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	4,034
Gas Distribution Operations | SOUTHERN Co GAS | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Segment Reporting Information [Line Items]
Operating revenues		167
Gas Marketing Services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	981
Operating revenues		32
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,495	1,657
Segment net income (loss)	273	293
Total assets	21,592		21,918
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,474	1,639
Segment net income (loss)	270	279
Goodwill	5,015		5,015
Total assets	20,952		21,448
Operating Segments | All Other
Segment Reporting Information [Line Items]
Operating revenues	182	401
Segment net income (loss)	1,195	(74)
Goodwill	268		298
Total assets	3,391		3,285
Operating Segments | All Other | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	11	15
Segment net income (loss)	(3)	(14)
Total assets	10,900		11,112
Operating Segments | Gas Distribution Operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,172	1,212
Segment net income (loss)	133	149
Total assets	17,379		17,266
Operating Segments | Gas Pipeline Investments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	8	8
Segment net income (loss)	32	27
Total assets	1,781		1,763
Operating Segments | Wholesale Gas Services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	86	166
Segment net income (loss)	47	104
Total assets	821		1,302
Less Gross Gas Costs	1,928	1,939
Operating Segments | Wholesale Gas Services | SOUTHERN Co GAS | Third Party Gross Revenues
Segment Reporting Information [Line Items]
Operating revenues	1,926	1,938
Operating Segments | Wholesale Gas Services | SOUTHERN Co GAS | Intercompany Revenues
Segment Reporting Information [Line Items]
Operating revenues	88	167
Operating Segments | Wholesale Gas Services | SOUTHERN Co GAS | Total Gross Revenues
Segment Reporting Information [Line Items]
Operating revenues	2,014	2,105
Operating Segments | Gas Marketing Services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	229	271
Segment net income (loss)	61	13
Total assets	1,611		1,587
Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(39)	(50)
Segment net income (loss)	(2)	0
Goodwill	(1)		0
Total assets	(1,370)		(1,778)
Eliminations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	(32)	(33)
Segment net income (loss)	0	0
Total assets	(11,540)		(11,582)
Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	3,795	4,382
Segment net income (loss)	621	733
Goodwill	2		2
Total assets	91,123		93,959
Electric Utilities | Operating Segments | Traditional Electric Operating Companies
Segment Reporting Information [Line Items]
Operating revenues	3,445	3,979
Segment net income (loss)	565	612
Goodwill	0		0
Total assets	76,798		79,382
Electric Utilities | Operating Segments | SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	443	509
Segment net income (loss)	56	121
Goodwill	2		2
Total assets	15,104		14,883
Electric Utilities | Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(93)	(106)
Segment net income (loss)	0	$ 0
Goodwill	0		0
Total assets	$ (779)		$ (306)

XML

Segment and Related Information - Financial Data for Products and Services (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Concentration Risk [Line Items]
Operating revenues	$ 5,412	$ 6,372
Retail
Concentration Risk [Line Items]
Operating revenues	3,084	3,568
Wholesale
Concentration Risk [Line Items]
Operating revenues	499	623
Other
Concentration Risk [Line Items]
Operating revenues	168	161
Gas Distribution Operations
Concentration Risk [Line Items]
Operating revenues	1,163	1,224
Electric Utilities' Revenues
Concentration Risk [Line Items]
Operating revenues	3,795	4,382
Electric Utilities' Revenues | Retail
Concentration Risk [Line Items]
Operating revenues	3,084	3,568
Electric Utilities' Revenues | Wholesale
Concentration Risk [Line Items]
Operating revenues	499	623
Electric Utilities' Revenues | Other
Concentration Risk [Line Items]
Operating revenues	212	191
Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	1,474	1,639
Southern Company Gas' Revenues | Gas Distribution Operations
Concentration Risk [Line Items]
Operating revenues	1,161	1,200
Southern Company Gas' Revenues | Gas Distribution Operations | Revenues | Product Concentration Risk | Three Gas Distribution Operations
Concentration Risk [Line Items]
Operating revenues		167
Southern Company Gas' Revenues | Gas Marketing Services
Concentration Risk [Line Items]
Operating revenues	229	271
Southern Company Gas' Revenues | Gas Marketing Services | Revenues | Product Concentration Risk | Pivotal Home Solutions
Concentration Risk [Line Items]
Operating revenues		32
Southern Company Gas' Revenues | Other
Concentration Risk [Line Items]
Operating revenues	$ 84	$ 168