2023 Annual Repor t
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Christopher C. Womack
Chairman, President & CEO, Southern Company
Chairman’s Message
Dear Fellow Shareholders,
Southern Company experienced an exceptional year in
2023. Despite headwinds that included higher interest
rates, inflation and historically mild weather, we delivered
operational excellence, outstanding customer service and
strong financial results through hard work, collaborative
teamwork and focused perseverance.
Plant Vogtle Unit 3, the first newly-constructed nuclear
unit to be built in the United States in over three decades,
entered commercial operation in July, proving once again
that we can accomplish difficult tasks. Unit 4 achieved
initial criticality earlier this year and is projected to be in
service during the second quarter of 2024.
Once Unit 4 is in service, Plant Vogtle will become the
largest carbon-free generation asset in the United States.
These units represent a long-term investment in a clean
energy future for the state of Georgia and they are
expected to provide reliable, emissions-free energy to
customers for decades to come.
Excelling at the Fundamentals
Plant Barry Unit 8 is now completed and serving customers
across Alabama. The state-of-the-art combined cycle unit
pairs a gas turbine and steam turbine to generate up to
727 MW–enough energy to power more than 200,000
homes. Constructed on time and within budget, the
addition of Unit 8 makes Plant Barry the largest facility
in Alabama Power’s generation fleet.
In 2023, Southern Company subsidiaries responded to
record summer heat across the South. Mississippi Power
experienced its highest peak load since 2012 and
successfully met customer demand thanks to the dedication
of employees in ensuring optimal running condition of its
generating units and proactive maintenance programs.
In August, Hurricane Idalia made landfall on the
Gulf Coast as a Category 3 hurricane. The storm was
responsible for power outages affecting more than
250,000 customers. Our unified restoration team of
5,500 personnel from Alabama Power, Georgia Power,
Mississippi Power and Southern Company Gas worked
tirelessly to restore power and repair gas lines. Within
72 hours, service was restored for most customers.
Serving Our Customers and Elevating Our Communities
Several years of extraordinary success in attracting
new and expanding businesses to our states underpins
our optimistic outlook for the future. Georgia Power
filed an update to its Integrated Resource Plan with
the Georgia PSC to accommodate the projected energy
needs resulting from that state’s robust economic growth.
The updated plan, which is subject to approval by the
Georgia PSC, includes the deployment of new generation
resources, battery energy storage systems, distributed
energy resources and conventional power plants. Of note,
Georgia Power now anticipates adding approximately
10,000 MW of new renewable resources by 2035, double
its previous projection.
Southern Company has a long history of being a citizen
wherever we serve. We continue to be committed to the
customers and communities we are privileged to serve as
we strive to make lives better.
We amplify, invest in and support causes that advance
equity and social justice in our communities. Since 2020,
Southern Company and our charitable foundations have
invested $201 million as part of our five-year, $225 million
commitment to those communities.
Nicor Gas brought natural gas service to the underserved
community of Hopkins Park, Illinois, providing residents
who have historically relied on propane and wood-fired
stoves to heat their homes with an affordable and
reliable energy option.
Nicor Gas also partnered with Fox Valley Habitat for
Humanity to break ground on a new smart neighborhood
Southern Company 2023 Annual Report
1
Chairman’s Message
(continued)
in northern Illinois. The project aims to build energy-
efficient homes that incorporate smart technology and
advanced energy solutions.
As a Proud Partner of the TOUR Championship and
Official Energy Company of the PGA Tour, Southern
Company has helped generate nearly $50 million for
community charities since the TOUR Championship was
first staged at Atlanta’s East Lake Golf Club in 1998.
Southern Company announced a five-year extension
to our partnership with the National Fish and Wildlife
Foundation that will continue to support conservation
efforts across our service footprint. This partnership has
supported more than 400 on-the-ground conservation
projects, including landscape-scale ecosystem restoration,
watershed management and species conservation.
Leading through Innovation
Southern Company, TerraPower and CORE POWER
successfully initiated pumped-salt operations at the
Integrated Effects Test at TerraPower’s laboratory
in Everett, Washington, a significant milestone in
the development of Generation IV molten salt
reactor technology.
The fund helps drive diversity in the energy ecosystem by
providing access to capital for underrepresented founders
of clean tech companies and it supports diversity and
minority-owned businesses in the associated supply
chain. Southern Company was the inaugural donor to
the fund, which has raised nearly $112 million in limited
partner commitments.
Southern Company continues to receive accolades from a
variety of industry observers. Earlier this year, we were ranked
first among electric and gas utilities in Fortune magazine’s
ranking of the World‘s Most Admired Companies™, and
No. 1 for Black executives by DiversityInc for the second
consecutive year. Alabama Power was ranked No. 1 in
electric utility business customer satisfaction in the large
segment category by J.D. Power. Similarly, J.D. Power
ranked Georgia Power No. 1 in electric utility residential
customer satisfaction, also in the large segment category.
Southern Company also received the Edison Electric
Institute Index Award which measured the total shareholder
return of electric companies over a five-year period ended
December 31, 2022, ranking first in the large cap category
with an impressive 83.4% return. Our next-closest competitor
delivered a 53% return.
Nicor Gas will participate in the Midwest Alliance for
Clean Hydrogen, one of seven regional clean hydrogen
hubs approved by the U.S. Department of Energy.
Southern Company is committed to pursuing hydrogen
projects that support a sustainable future and serve
customer needs with clean energy.
In closing, our customer-focused business model continues
to be the cornerstone for delivering value to customers
and shareholders alike. Our experienced management
team has a long track record of successfully executing on
this time-tested model, and we believe our company is
well-positioned for continued success.
In 2023, Southern Company’s Clean Transportation
division secured over $17 million in funding for electric
vehicle (EV) charging infrastructure. Southern Company
is a founding member of the Electric Power Research
Institute’s EVstoScale 2030 initiative and company
subsidiaries also installed EV charging stations at state
parks, airports and military bases, contributing to our goal
to reach net-zero greenhouse gas emissions by 2050.
Southern Company was named co-chair of the Elevate
Fund, a clean tech energy innovation fund that is part
of the Energy Impact Partners venture capital group.
2
Southern Company 2023 Annual Report
We are grateful for your continued confidence in
Southern Company. It is a privilege to serve you.
Sincerely,
Christopher C. Womack
March 26, 2024
Financial Highlights
4.53
2.26
3.28
3.64
2.95
3.11
3.25
3.41
3.60
3.65
’19
’20
’21
’22
’23
’19
’20
’21
’22
’23
Basic Earnings Per Share
Basic Earnings Per Share–Excluding Items*
(in dollars)
(in dollars)
* Not a financial measure under generally accepted accounting principles.
See Reconciliation of Non-GAAP Financial Metric on page 11 for additional
information and specific adjustments made to this measure by year.
18.15
2.46
2.54
2.62
2.70
2.782.78
11.24
8.57
12.09
12.86
’19
’20
’21
’22
’23
’19
’20
’21
’22
’23
Return On Average Common Equity
Dividends Per Share
(percent)
(in dollars)
Operating Revenues (in millions)
Earnings (in millions)
Basic Earnings Per Share
Diluted Earnings Per Share
Dividends Per Share (amount paid)
Dividend Yield (year-end, percent)
Average Shares Outstanding (in millions)
Return On Average Common Equity (percent)
Book Value Per Share
Market Price Per Share (year-end, closing)
Total Market Value Of Common Stock (year-end, in millions)
Total Assets (in millions)
Total Kilowatt-Hour Sales (in millions)
Retail
Wholesale
Total Utility Customers (year-end, in thousands)
2023
2022
Change
$25,253
$3,976
$3.64
$3.62
$2.78
4.0
1,092
12.86
$28.83
$70.12
$76,488
$139,331
195,507
144,531
50,976
8,861
$29,279
$3,524
$3.28
$3.26
$2.70
3.8
1,075
12.09
$27.93
$71.41
$77,750
$134,891
204,273
147,981
56,292
8,795
(13.8)%
12.8 %
11.0 %
11.0 %
3.0 %
5.3 %
1.6 %
6.4 %
3.2 %
(1.8)%
(1.6)%
3.3 %
(4.3)%
(2.3)%
(9.4)%
0.8 %
Southern Company 2023 Annual Report
3
Board of Directors
Christopher C. Womack
Janaki Akella
Henry A. Clark III
Shantella E. Cooper
Anthony F. Earley, Jr.
David J. Grain
Donald M. James
John D. Johns
Dale E. Klein
David E. Meador
Ernest J. Moniz
William G. Smith, Jr.
Kristine L. Svinicki
Lizanne Thomas
E. Jenner Wood III
Management Council
Christopher C. Womack
Bryan D. Anderson
Stanley W. Connally, Jr.
Christopher Cummiskey
Martin B. Davis
Sloane N. Drake
Kimberly S. Greene
James Y. Kerr II
Stephen E. Kuczynski
J. Jeffrey Peoples
Sterling A. Spainhour
Daniel S. Tucker
Anthony L. Wilson
4
Southern Company 2023 Annual Report
Board of Directors
Christopher C. Womack
David J. Grain
Ernest J. Moniz
Chairman, President and CEO, Southern Company
CEO and Managing Director
Cecil and Ida Green Professor of Physics and
Atlanta, GA | Age 66 | elected 2023
Grain Management, LLC (private equity firm)
Engineering Systems emeritus, Massachusetts
Sarasota, FL | Age 61 | elected 2012
Institute of Technology; CEO and Co-Chair,
Janaki Akella
Former Digital Transformation Leader
Google LLC (technology)
Donald M. James
Retired Chairman and CEO
Palo Alto, CA | Age 62 | elected 2019
Vulcan Materials Company (construction materials)
Henry A. Clark III
Pensacola, FL | Age 75 | elected 1999
Retired Senior Advisor, Evercore Inc.
John D. Johns
(global independent investment advisory firm)
Senior Advisor, Blackstone Inc.,
Hobe Sound, FL | Age 74 | elected 2009
Retired Chairman of DLI North America Inc.,
Nuclear Threat Initiative (energy); Former U.S.
Secretary of Energy
Brookline, MA | Age 79 | elected 2018
William G. Smith, Jr.
Chairman, President and CEO
Capital City Bank Group, Inc. (banking)
Tallahassee, FL | Age 70 | elected 2006
Shantella E. Cooper
Founder and CEO, Journey Forward Strategies, LLC
(consulting)
Atlanta, GA | Age 56 | elected 2023
Dale E. Klein
Anthony F. Earley, Jr.
Retired Chairman, President and CEO
PG&E Corporation (energy)
Bloomfield Hills, MI | Age 74 | elected 2019
the oversight company for Protective Life Insurance
Kristine L. Svinicki
Corporation (insurance)
Adjunct Professor, University of Michigan
Birmingham, AL | Age 72 | elected 2015
and former Commissioner and Chairman,
U.S. Nuclear Regulatory Commission (energy)
Milwaukee, WI l Age 57 l elected 2021
Professor in the Cockrell School of Engineering
at the University of Texas at Austin and holder
Lizanne Thomas
of the Reese Endowed Professorship; former
Retired Partner, Jones Day (legal)
Commissioner and Chairman, U.S. Nuclear
Atlanta, GA l Age 66 l elected 2023
Regulatory Commission (energy)
Austin, TX | Age 76 | elected 2010
David E. Meador
E. Jenner Wood III
Retired Corporate Executive Vice President–
Wholesale Banking, SunTrust Banks, Inc. (banking)
Retired Vice Chairman and Chief Administrative
Atlanta, GA | Age 72 | elected 2012
Officer, DTE Energy (energy)
Bloomfield Hills, MI l Age 67 l elected 2023
Management Council
Christopher C. Womack
Chairman, President and CEO
Sloane N. Drake
Executive Vice President and
Sterling A. Spainhour
Executive Vice President and Chief Legal Officer
Womack, 66, joined the company in 1988
Chief Human Resources Officer
Spainhour, 55, joined the company in 2016
Bryan D. Anderson
Drake, 47, joined the company in 2001
Daniel S. Tucker
Executive Vice President and President,
Kimberly S. Greene
Executive Vice President and Chief Financial Officer
External Affairs
Chairman, President and CEO, Georgia Power
Tucker, 53, joined the company in 1998
Anderson, 57, joined the company in 2010
Greene, 57, joined the company in 1991
Anthony L. Wilson
Stanley W. Connally, Jr.
James Y. Kerr II
Chairman, President and CEO, Mississippi Power
Executive Vice President, Operations,
Chairman, President and CEO,
Wilson, 60, joined the company in 1984
Southern Company
Southern Company Gas
Chairman, President and CEO, Southern Company
Kerr, 60, joined the company in 2014
Services, Inc.
Connally, 54, joined the company in 1989
Christopher Cummiskey
Executive Vice President, Chief Commercial
and Customer Solutions Officer
Cummiskey, 49, joined the company in 2013
Martin B. Davis
Executive Vice President and Chief Information Officer
Davis, 61, joined the company in 2015
Stephen E. Kuczynski
Chairman and CEO, Southern Nuclear
Kuczynski, 61, joined the company in 2011
J. Jeffrey Peoples
Chairman, President and CEO, Alabama Power
Peoples, 64, joined the company in 1984
Southern Company 2023 Annual Report
5
Financial Contents
7
Definitions
11
12
14
15
15
Reconciliation of Non-GAAP Financial Metric
Cautionary Statement Regarding Forward-Looking Statements
Southern Company Business
Five-Year Cumulative Performance Graph
Available Information
16 Management’s Report on Internal Control Over Financial Reporting
17
Report of Independent Registered Public Accounting Firm
19 Management’s Discussion and Analysis of Financial Condition and Results of Operations
60
61
62
64
66
67
Consolidated Statements of Income
Consolidated Statements of Comprehensive Income
Consolidated Statements of Cash Flows
Consolidated Balance Sheets
Consolidated Statements of Stockholders’ Equity
Index to the Notes to Financial Statements
68 Notes to Financial Statements
6
Southern Company 2023 Annual Report Definitions
ARP
Georgia Power's Alternate Rate Plans approved by the Georgia PSC;
2019 ARP for the years 2020 through 2022 and 2022 ARP for the
years 2023 through 2025
COVID-19
The novel coronavirus disease declared a pandemic by the World
Health Organization and the Centers for Disease Control and
Prevention in March 2020
AFUDC
Allowance for funds used during construction
CWIP
Construction work in progress
Alabama Power
Alabama Power Company
Amended and Restated Loan Guarantee Agreement
Loan guarantee agreement entered into by Georgia Power with the
DOE in 2014, as amended and restated in March 2019, under which
the proceeds of borrowings may be used to reimburse Georgia Power
for Eligible Project Costs incurred in connection with its construction of
Plant Vogtle Units 3 and 4
AOCI
Accumulated other comprehensive income
ARO
Asset retirement obligation
ASU
Accounting Standards Update
Atlanta Gas Light
Atlanta Gas Light Company, a wholly-owned subsidiary of Southern
Company Gas
Bechtel
Bechtel Power Corporation, the primary contractor for the remaining
construction activities for Plant Vogtle Units 3 and 4
Bechtel Agreement
The 2017 construction completion agreement between the Vogtle
Owners and Bechtel
CCN
Certificate of convenience and necessity
CCR
Coal combustion residuals
CCR Rule
Disposal of Coal Combustion Residuals from Electric Utilities final rule
published by the EPA in 2015
Chattanooga Gas
Chattanooga Gas Company, a wholly-owned subsidiary of Southern
Company Gas
Clean Air Act
Clean Air Act Amendments of 1990
CO2
Carbon dioxide
COD
Commercial operation date
Dalton
City of Dalton, Georgia, an incorporated municipality in the State of
Georgia, acting by and through its Board of Water, Light, and Sinking
Fund Commissioners
Dalton Pipeline
A pipeline facility in Georgia in which Southern Company Gas has a
50% undivided ownership interest
DOE
U.S. Department of Energy
ECCR
Georgia Power's Environmental Compliance Cost Recovery tariff
ECO Plan
Mississippi Power's environmental compliance overview plan
ELG
Effluent limitations guidelines
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
FCC
Federal Communications Commission
FERC
Federal Energy Regulatory Commission
FFB
Federal Financing Bank
FFB Credit Facilities
Note purchase agreements among the DOE, Georgia Power, and the
FFB and related promissory notes which provide for two multi-advance
term loan facilities
Fitch
Fitch Ratings, Inc.
Cooperative Energy
Electric generation and transmission cooperative in Mississippi
FP&L
Florida Power and Light Company
7
Southern Company 2023 Annual Report Definitions
GAAP
U.S. generally accepted accounting principles
KWH
Kilowatt-hour
Georgia Power
Georgia Power Company
GHG
Greenhouse gas
GRAM
Atlanta Gas Light's Georgia Rate Adjustment Mechanism
Guarantee Settlement Agreement
The June 9, 2017 settlement agreement between the Vogtle Owners
and Toshiba related to certain payment obligations of the EPC
Contractor guaranteed by Toshiba
Gulf Power
Gulf Power Company, until January 1, 2019 a wholly-owned subsidiary
of Southern Company; effective January 1, 2021, Gulf Power
Company merged with and into FP&L, with FP&L remaining as the
surviving 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
Illinois Commission
Illinois Commerce Commission
Internal Revenue Code
Internal Revenue Code of 1986, as amended
IPP
Independent power producer
IRA
Inflation Reduction Act
IRP
Integrated resource plan
IRS
Internal Revenue Service
LIBOR
London Interbank Offered Rate
LIFO
Last-in, first-out
LNG
Liquefied natural gas
LTSA
Long-term service agreement
Marketers
Marketers selling retail natural gas in Georgia and certificated by the
Georgia PSC
MEAG Power
Municipal Electric Authority of Georgia
Mississippi Power
Mississippi Power Company
mmBtu
Million British thermal units
Moody's
Moody's Investors Service, Inc.
MPUS
Mississippi Public Utilities Staff
MRA
Municipal and Rural Associations
MW
Megawatt
natural gas distribution utilities
Southern Company Gas' natural gas distribution utilities (Nicor Gas,
Atlanta Gas Light, Virginia Natural Gas, and Chattanooga Gas)
NCCR
Georgia Power's Nuclear Construction Cost Recovery tariff
NDR
Alabama Power's Natural Disaster Reserve
NextEra Energy
NextEra Energy, Inc.
Nicor Gas
Northern Illinois Gas Company, a wholly-owned subsidiary of Southern
Company Gas
ITAAC
Inspections, Tests, Analyses, and Acceptance Criteria, standards
established by the NRC
NOX
Nitrogen oxide
ITC
Investment tax credit
JEA
Jacksonville Electric Authority
8
NRC
U.S. Nuclear Regulatory Commission
NYMEX
New York Mercantile Exchange, Inc.
Southern Company 2023 Annual Report Definitions
NYSE
New York Stock Exchange
OCI
Other comprehensive income
OPC
Oglethorpe Power Corporation (an electric membership corporation)
OTC
Over-the-counter
PennEast Pipeline
PennEast Pipeline Company, LLC, a joint venture in which Southern
Company Gas has a 20% ownership interest
PEP
Mississippi Power's Performance Evaluation Plan
PowerSecure
PowerSecure, Inc., a wholly-owned subsidiary of Southern Company
PowerSouth
PowerSouth Energy Cooperative
PPA
Power purchase agreements, as well as, for Southern Power, contracts
for differences that provide the owner of a renewable facility a certain
fixed price for the electricity sold to the grid
PSC
Public Service Commission
PTC
Production tax credit
Rate CNP
Alabama Power's Rate Certificated New Plant, consisting of Rate
CNP New Plant, Rate CNP Compliance, Rate CNP PPA, and Rate
CNP Depreciation
Rate ECR
Alabama Power's Rate Energy Cost Recovery
Rate 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
ROE
Return on equity
S&P
S&P Global Ratings, a division of S&P Global Inc.
SEC
U.S. Securities and Exchange Commission
SEGCO
Southern Electric Generating Company, 50% owned by each of
Alabama Power and Georgia Power
Sequent
Sequent Energy Management, L.P. and Sequent Energy Canada
Corp., wholly-owned subsidiaries of Southern Company Gas through
June 30, 2021
SNG
Southern Natural Gas Company, L.L.C., a pipeline system in which
Southern Company Gas has a 50% ownership interest
SO2
Sulfur dioxide
SOFR
Secured Overnight Financing Rate
Southern Company
The Southern Company
Southern Company Gas
Southern Company Gas and its subsidiaries
Southern Company Gas Capital
Southern Company Gas Capital Corporation, a 100%-owned subsidiary
of Southern Company Gas
Southern Company power pool
The operating arrangement whereby the integrated generating
resources of the traditional electric operating companies and Southern
Power (excluding subsidiaries) are subject to joint commitment and
dispatch in order to serve their combined load obligations
Southern Company system
Southern Company, the traditional electric operating companies,
Southern Power, Southern Company Gas, SEGCO, Southern Nuclear, SCS,
Southern Linc, PowerSecure, and other subsidiaries
Southern Holdings
Southern Company Holdings, Inc., a wholly-owned subsidiary of
Southern Company
Southern Linc
Southern Communications Services, Inc., a wholly-owned subsidiary of
Southern Company, doing business as Southern Linc
Southern Nuclear
Southern Nuclear Operating Company, Inc., a wholly-owned subsidiary
of Southern Company
Southern Power
Southern Power Company and its subsidiaries
SAVE
Steps to Advance Virginia's Energy, an infrastructure replacement
program at Virginia Natural Gas
SCS
Southern Company Services, Inc., the Southern Company system service
company and a wholly-owned subsidiary of Southern Company
SouthStar
SouthStar Energy Services, LLC (a Marketer), a wholly-owned subsidiary
of Southern Company Gas
SP Solar
SP Solar Holdings I, LP, a limited partnership indirectly owning
substantially all of Southern Power's solar and battery energy storage
facilities, in which Southern Power has a 67% ownership interest
9
Southern Company 2023 Annual Report Definitions
SP Wind
SP Wind Holdings II, LLC, a holding company owning a portfolio of eight
operating wind facilities, in which Southern Power is the controlling
partner in a tax equity arrangement
SRR
Mississippi Power's System Restoration Rider, a tariff for retail property
damage cost recovery and reserve
Subsidiary Registrants
Alabama Power, Georgia Power, Mississippi Power, Southern Power, and
Southern Company Gas
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, and Mississippi Power
Virginia Natural Gas
Virginia Natural Gas, Inc., a wholly-owned subsidiary of Southern
Company Gas
Vogtle 3 and 4 Agreement
Agreement entered into with the EPC Contractor in 2008 by Georgia
Power, acting for itself and as agent for the Vogtle Owners, and
rejected in bankruptcy in July 2017, pursuant to which the EPC
Contractor agreed to design, engineer, procure, construct, and test Plant
Vogtle Units 3 and 4
Vogtle Owners
Georgia Power, OPC, MEAG Power, and Dalton
Vogtle Services Agreement
The June 2017 services agreement between the Vogtle Owners and
the EPC Contractor, as amended and restated in July 2017, for the
EPC Contractor to transition construction management of Plant Vogtle
Units 3 and 4 to Southern Nuclear and to provide ongoing design,
engineering, and procurement services to Southern Nuclear
VCM
Vogtle Construction Monitoring
VIE
Variable interest entity
Virginia Commission
Virginia State Corporation Commission
Westinghouse
Westinghouse Electric Company LLC
Williams Field Services Group
Williams Field Services Group, LLC
10
Southern Company 2023 Annual Report Reconciliation of Non-GAAP Financial Metric
(In millions, except earnings per share)
Net Income - GAAP
Average Shares Outstanding
Basic Earnings Per Share
Net Income - GAAP
Less Non-GAAP Excluding Items:
Acquisition, Disposition, and Integration Impacts(1)
Tax Impact
Estimated Loss on Plants Under Construction(2)
Tax Impact
Wholesale Gas Services(3)
Tax Impact
Impairments(4)
Tax Impact
Loss on Extinguishment of Debt(5)
Tax Impact
Estimated Loss on Qualifying Infrastructure Plant and Other Capital Investments(6)
Tax Impact
Net Income - Excluding Items
Basic Earnings Per Share - Excluding Items
Year Ended December 31,
2023
2022
2021
2020
2019
$ 3,976
1,092
$ 3.64
$ 3,524
1,075
$ 3.28
$ 2,393
1,061
$ 2.26
$ 3,119
1,058
$ 2.95
$ 4,739
1,046
$ 4.53
$ 3,976
$ 3,524
$ 2,393
$ 3,119
$ 4,739
(1)
33
51
(13)
—
—
—
—
(5)
1
(96)
24
$ 3,982
$ 3.65
(115)
32
(199)
51
—
—
(119)
—
—
—
—
—
$ 3,874
$ 3.60
209
(90)
(1,703)
433
18
(3)
(91)
19
(23)
6
—
—
$ 3,618
$ 3.41
60
(22)
(328)
84
17
(3)
(206)
101
(29)
7
—
—
$ 3,438
$ 3.25
2,516
(1,081)
(27)
—
215
(52)
(108)
26
—
—
—
—
$ 3,250
$ 3.11
(1) Net income for the year ended December 31, 2023 includes a $35 million favorable tax impact related to a reversal of an uncertain tax position associated
with the 2019 sale of Gulf Power. Net Income for the year ended December 31, 2022 includes impairment charges totaling $131 million pre tax ($99 million
after tax) and other disposition impacts associated with the sales of two Southern Company Gas natural gas storage facilities. Net income for the year ended
December 31, 2022 also includes a $14 million pre-tax ($11 million after-tax) gain as a result of the early termination of the transition services agreement related
to the 2019 sale of Gulf Power. Net income for the year ended December 31, 2021 includes: (i) a $93 million pre-tax ($99 million after-tax) gain associated with
the termination of a leasehold interest in assets associated with two leveraged lease projects; (ii) $16 million of income tax benefits recognized as the result
of another leveraged lease investment disposition; and (iii) a $121 million pre-tax ($92 million after-tax) gain on the sale of Sequent, as well as $85 million of
additional tax expense due to the resulting changes in state apportionment rates. Net income for the year ended December 31, 2020 includes: (i) $39 million
pre-tax ($23 million after-tax) gain on the sale of Plant Mankato and (ii) a $22 million pre-tax ($16 million after-tax) gain on the sale of a natural gas storage
facility. Net income for the year ended December 31, 2019 includes: (i) a $2.6 billion pre-tax ($1.4 billion after-tax) gain on the sale of Gulf Power; (ii) a $23 million
pre-tax ($88 million after-tax) gain on the sale of Plant Nacagdoches; and (iii) $18 million pre tax ($11 million after tax) of other acquisition and disposition
impacts, partially offset by: (i) a $58 million pre-tax ($52 million after-tax) net loss, including impairment charges, associated with the sales of PowerSecure’s
utility infrastructure services and lighting businesses and (ii) a $24 million pre-tax ($17 million after-tax) impairment charge in contemplation of the sale of Pivotal
LNG and Atlantic Coast Pipeline.
(2) Net income for the year ended December 31, 2023 includes a net credit of $68 million pre tax ($50 million after tax) and for the years ended December 31,
2022, 2021, and 2020 includes aggregate net charges of $183 million pre tax ($137 million after tax), $1.7 billion pre tax ($1.3 billion after tax), and $325 million
pre tax ($242 million after tax), respectively, for estimated probable losses associated with Georgia Power’s construction of Plant Vogtle Units 3 and 4.
Further charges may occur; however, the amounts and timing of any such charges are uncertain. Net income for all periods presented also includes charges (net
of salvage proceeds), associated legal expenses (net of insurance recoveries), and tax impacts related to Mississippi Power’s Kemper IGCC. Mississippi Power
expects to incur additional pre-tax period costs to complete dismantlement of the abandoned gasifier-related assets and site restoration activities, including
related costs for compliance and safety, asset retirement obligation accretion, and property taxes, net of salvage, totaling approximately $15 million annually
through 2025.
(3) Net income for the years ended December 31, 2021, 2020, and 2019 includes the Wholesale Gas Services business, which was sold on July 1, 2021.
Presenting net income and earnings per share excluding Wholesale Gas Services provided an additional measure of operating performance that excluded the
volatility resulting from mark-to-market and lower of weighted average cost or current market price accounting adjustments.
(4) Net income for the year ended December 31, 2022 includes an impairment charge associated with goodwill at PowerSecure. Net income for the years ended
December 31, 2021, 2020, and 2019 includes impairment charges associated with two leveraged leases. Net income for the year ended December 31, 2021 also
includes impairment charges totaling $84 million pre tax ($67 million after tax) related to Southern Company Gas’ investment in the PennEast Pipeline project.
Net income for the year ended December 31, 2019 also includes impairment charges associated with a natural gas storage facility. Impairment charges may
occur in the future; however, the amounts and timing of any such charges are uncertain.
(5) Net income for the years ended December 31, 2023, 2021 and 2020 includes costs associated with the extinguishment of debt at Southern Company.
Further debt extinguishment charges may occur at Southern Company or its non-regulated subsidiaries; however, the amounts and timing of any such costs
are uncertain.
(6) Net income for the year ended December 31, 2023 includes charges totaling $96 million pre tax ($72 million after tax) for estimated losses at Southern
Company Gas associated with the Illinois Commission disallowances related to (i) its review of the Qualifying Infrastructure Plant (QIP) capital investments by
Nicor Gas under the QIP rider, or Investing in Illinois program, and (ii) Nicor Gas’ general base rate case proceeding. Further charges may occur; however, the
amount and timing of any such charges are uncertain.
11
Southern Company 2023 Annual Report Cautionary Statement Regarding Forward-Looking Statements
Southern Company’s Annual Report contains forward-looking statements. Forward-looking statements include, among other things,
statements concerning regulated rates, the strategic goals for the business, customer and sales growth, economic conditions, including
inflation, cost recovery and other rate actions, projected equity ratios, current and proposed environmental regulations and related
compliance plans and estimated expenditures, GHG emissions reduction goals, pending or potential litigation matters, access to sources of
capital, projections for the qualified pension plans, postretirement benefit plans, and nuclear decommissioning trust fund contributions,
financing activities, completion dates and costs of construction projects, matters related to the abandonment of the Kemper IGCC, filings
with state and federal regulatory authorities, federal and state income tax benefits, estimated sales and purchases under power sale and
purchase agreements, 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:
O the impact of recent and future federal and state regulatory changes, including tax, environmental, and other laws and regulations to
which Southern Company and its subsidiaries are subject, as well as changes in application of existing laws and regulations;
O the extent and timing of costs and legal requirements related to CCR;
O current and future litigation or regulatory investigations, proceedings, or inquiries, including litigation and other disputes related to the
Kemper County energy facility and Plant Vogtle Units 3 and 4;
O 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;
O variations in demand for electricity and natural gas;
O available sources and costs of natural gas and other fuels and commodities;
O the ability to complete necessary or desirable pipeline expansion or infrastructure projects, limits on pipeline capacity, public and
policymaker support for such projects, and operational interruptions to natural gas distribution and transmission activities;
O transmission constraints;
O the ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of facilities or
other projects, including Plant Vogtle Unit 4 (which includes components based on new technology that only within the last several
years began initial operation in the global nuclear industry at this scale), due to current and/or future challenges which include, but
are not limited to, changes in labor costs, availability, and productivity; challenges with the management of contractors or vendors;
subcontractor performance; adverse weather conditions; shortages, delays, increased costs, or inconsistent quality of equipment,
materials, and labor; contractor or supplier delay; the impacts of inflation; delays due to judicial or regulatory action; nonperformance
under construction, operating, or other agreements; operational readiness, including specialized operator training and required site
safety programs; engineering or design problems or any remediation related thereto; design and other licensing-based compliance
matters; challenges with start-up activities, including major equipment failure, or system integration; and/or operational performance;
challenges related to pandemic health events; continued public and policymaker support for projects; environmental and geological
conditions; delays or increased costs to interconnect facilities to transmission grids; and increased financing costs as a result of changes
in interest rates or as a result of project delays;
O the ability to overcome or mitigate the current challenges, or challenges yet to be identified, at Plant Vogtle Unit 4, as described in
Note 2 to the financial statements under “Georgia Power – Nuclear Construction,” that could further impact the cost and schedule for
the project;
O legal proceedings and regulatory approvals and actions related to past and ongoing construction projects, including PSC approvals and
FERC actions;
O under certain specified circumstances, a decision by holders of more than 10% of the ownership interests of Plant Vogtle Unit 4 not to
proceed with construction;
O in the event Georgia Power becomes obligated to provide funding to MEAG Power with respect to the portion of MEAG Power’s
ownership interest in Plant Vogtle Units 3 and 4 involving JEA, any inability of Georgia Power to receive repayment of such funding;
O 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;
O investment performance of the employee and retiree benefit plans and nuclear decommissioning trust funds;
O advances in technology, including the pace and extent of development of low- to no-carbon energy and battery energy storage
technologies and negative carbon concepts;
O performance of counterparties under ongoing renewable energy partnerships and development agreements;
12
Southern Company 2023 Annual Report Cautionary Statement Regarding Forward-Looking Statements
O state and federal rate regulations and the impact of pending and future rate cases and negotiations, including rate actions relating to
ROE, equity ratios, additional generating capacity, and fuel and other cost recovery mechanisms;
O the ability to successfully operate the traditional electric operating companies’ and SEGCO’s generation, transmission, and distribution
facilities, Southern Power’s generation facilities, and Southern Company Gas’ natural gas distribution and storage facilities and the
successful performance of necessary corporate functions;
O the inherent risks involved in operating and constructing nuclear generating facilities;
O the inherent risks involved in transporting and storing natural gas;
O the performance of projects undertaken by the non-utility businesses and the success of efforts to invest in and develop
new opportunities;
O internal restructuring or other restructuring options that may be pursued;
O potential business strategies, including acquisitions or dispositions of assets or businesses, which cannot be assured to be completed or
beneficial to Southern Company or its subsidiaries;
O the ability of counterparties of Southern Company and its subsidiaries to make payments as and when due and to perform as required;
O the ability to obtain new short- and long-term contracts with wholesale customers;
O the direct or indirect effect on the Southern Company system’s business resulting from cyber intrusion or physical attack and the threat
of cyber and physical attacks;
O global and U.S. economic conditions, including impacts from geopolitical conflicts, recession, inflation, interest rate fluctuations, and
financial market conditions, and the results of financing efforts;
O access to capital markets and other financing sources;
O changes in Southern Company’s and any of its subsidiaries’ credit ratings;
O the ability of the traditional electric operating companies to obtain additional generating capacity (or sell excess generating capacity)
at competitive prices;
O catastrophic events such as fires, earthquakes, explosions, floods, tornadoes, hurricanes and other storms, droughts, pandemic health
events, political unrest, wars, or other similar occurrences;
O 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;
O impairments of goodwill or long-lived assets;
O the effect of accounting pronouncements issued periodically by standard-setting bodies; and
O other factors discussed elsewhere herein and in other reports filed by the Registrants from time to time with the SEC.
Southern Company expressly disclaims any obligation to update any forward-looking statements.
13
Southern Company 2023 Annual Report Southern Company Business
Southern Company is a holding company that owns all of the outstanding common stock of three traditional electric operating companies,
Southern Power Company, and Southern Company Gas. The traditional electric operating companies – Alabama Power, Georgia Power,
and Mississippi Power – are each operating public utility companies providing electric service to retail customers in three Southeastern
states in addition to wholesale customers in the Southeast. Southern Power Company is also an operating public utility company. The term
“Southern Power” when used herein refers to Southern Power Company and its subsidiaries, while the term “Southern Power Company”
when used herein refers only to the Southern Power parent company. 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 is an energy services holding company whose primary business is the distribution of natural gas in four states –
Illinois, Georgia, Virginia, and Tennessee – through the natural gas distribution utilities. Southern Company Gas is also involved in several
other businesses that are complementary to the distribution of natural gas.
Southern Company also owns SCS, Southern Linc, Southern Holdings, Southern Nuclear, PowerSecure, and other direct and indirect
subsidiaries. SCS, the system service company, has contracted with Southern Company, each of the Subsidiary Registrants, Southern
Nuclear, SEGCO, and other subsidiaries to furnish, at direct or allocated cost and upon request, the following services: general executive
and advisory, general and design engineering, operations, purchasing, accounting, finance, treasury, legal, tax, information technology,
marketing, auditing, insurance and pension administration, human resources, systems and procedures, digital wireless communications,
cellular tower space, and other services with respect to business and operations, construction management, and Southern Company power
pool transactions. Southern Linc provides digital wireless communications for use by Southern Company and its subsidiary companies and
also markets these services to the public and provides fiber optics services through its subsidiary, Southern Telecom, Inc. Southern Linc’s
system covers approximately 122,000 square miles in the Southeast. Southern Holdings is an intermediate holding company subsidiary,
which invests in various projects. Southern Nuclear operates and provides services to the Southern Company system’s nuclear power plants
and is currently managing construction and start-up of Plant Vogtle Unit 4, which is co-owned by Georgia Power. PowerSecure develops
distributed energy and resilience solutions and deploys microgrids for commercial, industrial, governmental, and utility customers.
14
Southern Company 2023 Annual Report Five-Year Cumulative Performance Graph
This performance graph compares the cumulative total shareholder return on Southern Company’s common stock with
the Standard & Poor’s 500 index and the Philadelphia Utility Index for the past five years. The graph assumes that $100 was
invested on December 31, 2018 in Southern Company’s common stock and each of the indices and that all dividends were reinvested.
The stockholder return shown for the five-year historical period may not be indicative of future performance.
$220
$200
$180
$160
$140
$120
$100
$80
2018
2019
2020
2021
2022
2023
Southern Company
Philadelphia Utilities Index
S&P 500
2018
100
100
100
2019
152
127
131
2020
153
130
156
2021
178
154
200
2022
192
155
164
2023
196
141
207
Available Information
Southern Company’s Annual Report on Form 10-K for the year ended December 31, 2023 (Form 10-K), as well as other documents filed
by Southern Company pursuant to the Securities Exchange Act of 1934, as amended, are available electronically at http://www.sec.gov.
A copy of the Form 10-K as filed with the SEC will be provided without charge upon written request to the office of the Corporate
Secretary. Requests for copies should be directed to the Corporate Secretary, 30 Ivan Allen Jr. Blvd., N.W., Atlanta, GA 30308.
The “Management’s Discussion and Analysis of Financial Condition and Results of Operations” herein generally discusses 2023 and 2022
items and year-to-year comparisons between 2023 and 2022. Discussions of 2021 items and year-to-year comparisons between 2022
and 2021 that are not included in this Annual Report can be found in Item 7 of Southern Company’s Annual Report on Form 10-K for the
year ended December 31, 2022, which was filed with the SEC on February 15, 2023.
15
Southern Company 2023 Annual Report Management’s Report on Internal Control Over Financial Reporting
The management of Southern Company is responsible for establishing and maintaining an adequate system of internal control over
financial reporting as required by the Sarbanes-Oxley Act of 2002 and as defined in Exchange Act Rule 13a-15(f). A control system can
provide only reasonable, not absolute, assurance that the objectives of the control system are met.
Under management’s supervision, an evaluation of the design and effectiveness of Southern Company’s internal control over financial
reporting was conducted based on the framework in Internal Control—Integrated Framework (2013) issued by the Committee of
Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management concluded that Southern Company’s
internal control over financial reporting was effective as of December 31, 2023.
Deloitte & Touche LLP, as auditors of Southern Company’s financial statements, has issued an attestation report on the effectiveness of
Southern Company’s internal control over financial reporting as of December 31, 2023, which is included herein.
Christopher C. Womack
Chairman, President, and Chief Executive Officer
Daniel S. Tucker
Executive Vice President and Chief Financial Officer
February 14, 2024
16
Southern Company 2023 Annual Report
Report of Independent Registered Public Accounting Firm
To the stockholders and the Board of Directors of The Southern Company and Subsidiary Companies
Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of The Southern Company and Subsidiary Companies (Southern Company)
as of December 31, 2023 and 2022, the related consolidated statements of income, comprehensive income, stockholders’ equity, and
cash flows for each of the three years in the period ended December 31, 2023, and the related notes (collectively referred to as the
“financial statements”). We also have audited Southern Company’s internal control over financial reporting as of December 31, 2023, based
on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the
Treadway Commission (COSO).
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Southern Company
as of December 31, 2023 and 2022, and the results of its operations and its cash flows for each of the three years in the period ended
December 31, 2023, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion,
Southern Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2023, based
on criteria established in Internal Control – Integrated Framework (2013) issued by COSO.
Basis for Opinions
Southern Company’s management is responsible for these financial statements, for maintaining effective internal control over financial
reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying
Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on these financial statements
and an opinion on Southern Company’s internal control over financial reporting based on our audits. We are a public accounting firm
registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect
to Southern Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and
Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to
obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud, and
whether effective internal control over financial reporting was maintained in all material respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the
financial statements, whether due to error or fraud, and performing procedures to respond to those risks. Such procedures included
examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating
the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the
financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over
financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of
internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the
circumstances. We believe that our audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed 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. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance
of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide
reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally
accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations
of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of
unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections
of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in
conditions, or that the degree of compliance with the policies or procedures may deteriorate.
17
Southern Company 2023 Annual Report Report of Independent Registered Public Accounting Firm
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was
communicated or required to be communicated to the Audit Committee of Southern Company’s Board of Directors and that (1) relates
to accounts or disclosures that are material to the financial statements and (2) involved especially challenging, subjective, or complex
judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a
whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on
the accounts or disclosures to which it relates.
Impact of Rate Regulation on the Financial Statements – Refer to Note 1 (Summary of Significant Accounting
Policies – Regulatory Assets and Liabilities) and Note 2 (Regulatory Matters) to the financial statements
Critical Audit Matter Description
Southern Company’s traditional electric operating companies and natural gas distribution utilities (the “regulated utility subsidiaries”) are
subject to rate regulation by their respective state Public Service Commissions or other applicable state regulatory agencies and wholesale
regulation by the Federal Energy Regulatory Commission (collectively, the “Commissions”). Management has determined that the regulated
utility subsidiaries meet the requirements under accounting principles generally accepted in the United States of America to utilize
specialized rules to account for the effects of rate regulation in the preparation of its financial statements. Accounting for the economics of
rate regulation may impact multiple financial statement line items and disclosures.
The Commissions set the rates the regulated utility subsidiaries are permitted to charge customers. Rates are determined and approved
in regulatory proceedings based on an analysis of the applicable regulated utility subsidiary’s costs to provide utility service and a return
on, and recovery of, its investment in the utility business. Current and future regulatory decisions can have an impact on the recovery of
costs, the rate of return earned on investments, and the timing and amount of assets to be recovered through rates. The Commissions’
regulation of rates is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital.
While Southern Company’s regulated utility subsidiaries expect to recover costs from customers through regulated rates, there is a risk that
the Commissions will not approve: (1) full recovery of the costs of providing utility service, or (2) full recovery of all amounts invested in
the utility business and a reasonable return on those investments.
We identified the impact of rate regulation related to certain assets and liabilities as a critical audit matter due to the significant judgments
made by management to support its assertions about impacted account balances and disclosures and/or the high degree of subjectivity
involved in assessing the potential impact of future regulatory orders on incurred costs. Management judgments include assessing the likelihood
of (1) recovery in future rates of incurred costs, (2) a disallowance of part of the cost of recently completed plant or plant under construction,
and/or (3) a refund to customers. Auditing these judgments, which include assumptions about the outcome of future decisions by the
Commissions, required specialized knowledge of accounting for rate regulations and the rate setting process due to its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the impact of rate regulation on certain assets and liabilities included the following, among others:
O We tested the effectiveness of management’s controls over the evaluation of the likelihood of (1) the recovery in future rates of certain
incurred costs and (2) refunds or future reductions in rates that should be reported as regulatory liabilities; and the monitoring and
evaluation of regulatory developments that may affect the likelihood of recovering certain costs in future rates or of a future reduction
in rates. We also tested the effectiveness of management’s controls over the initial recognition of regulatory assets or liabilities.
O We read and evaluated relevant regulatory orders and/or other relevant publicly available information to assess the likelihood of
recovery of certain incurred costs in future rates or of a future reduction in rates based on precedents of the treatment of similar costs
under similar circumstances.
O We tested certain incurred costs recorded as regulatory assets or liabilities during the period for completeness and accuracy.
O We obtained representation from management regarding the likelihood of recoverability of incurred costs and potential refund or future
reduction in rates to assess management’s assertions about the likelihood of recovery, refund, or a future reduction in rates.
O We evaluated Southern Company’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory
developments, including where there is a high degree of subjectivity involved in assessing the potential impact of future regulatory
orders on incurred costs.
Atlanta, Georgia
February 14, 2024
We have served as Southern Company’s auditor since 2002.
18
Southern Company 2023 Annual Report Management's Discussion and Analysis of Financial Condition and Results of Operations
OVERVIEW
Business Activities
Southern Company is a holding company that owns all of the common stock of three traditional electric operating companies, Southern
Power, and Southern Company Gas and owns other direct and indirect subsidiaries. The primary businesses of the Southern Company
system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by
Southern Company Gas. Southern Company’s reportable segments are the sale of electricity by the traditional electric operating companies,
the sale of electricity in the competitive wholesale market by Southern Power, and the sale of natural gas and other complementary
products and services by Southern Company Gas. See Note 16 to the financial statements for additional information.
O The traditional electric operating companies – Alabama Power, Georgia Power, and Mississippi Power – are vertically integrated utilities
providing electric service to retail customers in three Southeastern states in addition to wholesale customers in the Southeast.
O 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, IPPs, 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.
O Southern Company Gas is an energy services holding company whose primary business is the distribution of natural gas.
Southern Company Gas owns natural gas distribution utilities in four states – Illinois, Georgia, Virginia, and Tennessee – and is also
involved in several other complementary businesses. Southern Company Gas manages its business through three reportable segments –
gas distribution operations, gas pipeline investments, and gas marketing services, which includes SouthStar, a Marketer and provider of
energy-related products and services to natural gas markets – and one non-reportable segment, all other. Prior to the sale of Sequent
on July 1, 2021, Southern Company Gas’ reportable segments also included wholesale gas services. See Notes 7, 15, and 16 to the
financial statements for additional information.
Southern Company’s other business activities include providing distributed energy and resilience solutions and deploying microgrids for
commercial, industrial, governmental, and utility customers, as well as investments in telecommunications. Management continues to
evaluate the contribution of each of these activities to total shareholder return and may pursue acquisitions, dispositions, and other
strategic ventures or investments accordingly.
See FUTURE EARNINGS POTENTIAL herein for a discussion of many factors that could impact the Registrants’ future results of operations,
financial condition, and liquidity.
Recent Developments
Alabama Power
On March 24, 2023, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover costs associated with the acquisition of
the Central Alabama Generating Station. The filing reflected an annual increase in retail revenues of $78 million, or 1.1%, effective with
June 2023 billings. Through May 2023, Alabama Power recovered substantially all costs associated with the Central Alabama Generating
Station through Rate RSE, offset by revenues from a power sales agreement. On May 24, 2023, the Central Alabama Generating Station
was placed into retail service. On November 1, 2023, Alabama Power placed Plant Barry Unit 8 in service. On December 1, 2023, Alabama
Power filed Rate CNP New Plant with the Alabama PSC to recover costs associated with Plant Barry Unit 8. The filing reflected an annual
increase in retail revenues of $91 million, or 1.4%, effective with January 2024 billings.
On June 14, 2023, the Alabama PSC issued an order approving modifications to Alabama Power’s Renewable Generation Certificate.
The modifications authorized Alabama Power to procure an additional 2,400 MWs of renewable capacity and energy by June 14, 2029 and
to market the related energy and environmental attributes to customers and other third parties. The modifications also increased the size
of allowable renewable projects from 80 MWs to 200 MWs and increased the annual approval limit from 160 MWs to 400 MWs.
On July 11, 2023, the Alabama PSC issued an order authorizing Alabama Power to expand the existing authority of its reliability reserve to
include certain production-related expenses that are intended to maintain reliability in between scheduled generating unit maintenance outages.
On August 18, 2023, Alabama Power notified the Alabama PSC of its intent to use a portion of its reliability reserve balance in 2023. During the
fourth quarter 2023, Alabama Power used $75 million of the reliability reserve for reliability-related transmission, distribution, and generation
expenses and nuclear production-related expenses. At December 31, 2023, Alabama Power accrued $52 million to its reliability reserve.
19
Southern Company 2023 Annual Report Management's Discussion and Analysis of Financial Condition and Results of Operations
On October 3, 2023, the Alabama PSC issued an order modifying its December 2022 order related to excess federal accumulated deferred
income taxes and authorizing Alabama Power to (i) flow back in 2023 approximately $24 million of certain federal excess accumulated
deferred income taxes resulting from the Tax Cuts and Jobs Act of 2017 and (ii) make available any remaining balance of excess
accumulated deferred income taxes at the end of 2023 for the benefit of customers in 2024 and/or 2025. At December 31, 2023, the
remaining balance was $81 million, of which approximately $67 million and $14 million will flow back in 2024 and 2025, respectively, for
the benefit of customers.
On November 9, 2023, the Alabama PSC approved a decrease to Rate ECR of approximately $126 million annually, effective with
December 2023 billings.
On December 1, 2023, Alabama Power submitted calculations to the Alabama PSC for Rate CNP Compliance for 2024, which resulted in an
annual revenue decrease of approximately $23 million, or 0.3%, effective with January 2024 billings.
For the year ended December 31, 2023, Alabama Power’s weighted common equity return exceeded 6.15%, resulting in Alabama Power
establishing a current regulatory liability of $15 million for Rate RSE refunds, which will be refunded to customers through bill credits
in April 2024.
See Note 2 to the financial statements under “Alabama Power” for additional information.
Georgia Power
Plant Vogtle Units 3 and 4 Construction and Start-Up Status
Georgia Power placed Plant Vogtle Unit 3 in service on July 31, 2023 and continues construction on Plant Vogtle Unit 4 (each with electric
generating capacity of approximately 1,100 MWs), in which it holds a 45.7% ownership interest. Georgia Power’s share of the total project
capital cost forecast to complete Plant Vogtle Units 3 and 4, including contingency, through the second quarter 2024 is $10.8 billion.
Hot functional testing for Unit 4 was completed on May 1, 2023. On July 20, 2023, Southern Nuclear announced that all Unit 4 ITAACs
had been submitted to the NRC, and, on July 28, 2023, the NRC published its 103(g) finding that the accepted criteria in the combined
license for Unit 4 had been met, which allowed nuclear fuel to be loaded and start-up testing to begin. Fuel load for Unit 4 was completed
on August 19, 2023. On October 6, 2023, Georgia Power announced that during start-up and pre-operational testing for Unit 4,
Southern Nuclear identified a motor fault in one of four reactor coolant pumps (RCPs). This RCP was replaced with an on-site spare RCP
from inventory.
On February 1, 2024, Georgia Power announced that during start-up and pre-operational testing for Unit 4, Southern Nuclear identified,
and has remediated, vibrations associated with certain piping within the cooling system. Considering the remaining pre-operational testing,
Unit 4 is projected to be placed in service during the second quarter 2024. On February 14, 2024, Unit 4 achieved self-sustaining nuclear
fission, commonly referred to as initial criticality. The projected schedule for Unit 4 significantly depends on the progression of start-up
and pre-operational testing, which may be impacted by equipment or other operational failures. In addition, any findings related to the
root cause of the motor fault on the single Unit 4 RCP could require engineering changes or remediation related to the other seven Unit 3
and Unit 4 RCPs. Any further delays could result in a later in-service date and cost increases.
As of December 31, 2023, based on completion of construction work and the assessment of start-up and pre-operational testing
remaining, Southern Nuclear has an estimated $36 million for construction contingency remaining in the estimate to complete.
This contingency is projected to be allocated in the future to address any further Unit 4 schedule extensions or remediation of other
issues discovered during start-up testing.
In September 2022, Georgia Power and MEAG Power reached an agreement to resolve a dispute regarding the cost-sharing and tender
provisions of the Global Amendments (as defined in Note 2 to the financial statements under “Georgia Power – Nuclear Construction –
Joint Owner Contracts”). Under the terms of the agreement, among other items, (i) MEAG Power will not exercise its tender option and
will retain its full ownership interest in Plant Vogtle Units 3 and 4; (ii) Georgia Power will reimburse a portion of MEAG Power’s costs
of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs, which
payments will total approximately $92 million based on the current project capital cost forecast; and (iii) Georgia Power will reimburse
20% of MEAG Power’s costs of construction with respect to any amounts over the current project capital cost forecast, with no further
adjustment for force majeure costs.
On October 5, 2023 and October 17, 2023, Georgia Power reached agreements with OPC and Dalton, respectively, to resolve its respective
dispute with each of OPC and Dalton regarding the cost-sharing and tender provisions of the Global Amendments. Under the terms of the
agreements with OPC and Dalton, among other items, (i) each of OPC and Dalton retracted its exercise of the tender option and will retain
its full ownership interest in Plant Vogtle Units 3 and 4, (ii) Georgia Power made payments immediately after execution of the agreements
20
Southern Company 2023 Annual Report Management's Discussion and Analysis of Financial Condition and Results of Operations
of $308 million and $17 million to OPC and Dalton, respectively, representing payment for a portion of each of OPC’s and Dalton’s costs of
construction for Plant Vogtle Units 3 and 4 previously incurred, (iii) Georgia Power will pay a portion of each of OPC’s and Dalton’s further
costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs,
which payments will be in an aggregate amount of approximately $105 million and $6 million for OPC and Dalton, respectively, based
on the current project capital cost forecast, and (iv) Georgia Power will pay 66% of each of OPC’s and Dalton’s costs of construction with
respect to any amounts above the current project capital cost forecast, with no further adjustment for force majeure costs.
Georgia Power recorded pre-tax charges to income through the fourth quarter 2022 of $407 million ($304 million after tax) associated
with the cost-sharing provisions of the Global Amendments, including the settlement with MEAG Power. Based on the current project
capital cost forecast and the settlements with OPC and Dalton described above, Georgia Power recorded a pre-tax charge to income of
approximately $160 million ($120 million after tax) in the third quarter 2023. These charges are included in the total project capital cost
forecast and will not be recovered from retail customers.
The ultimate impact of these matters on the construction schedule for Plant Vogtle Unit 4 and project capital cost forecast for Plant Vogtle
Units 3 and 4 cannot be determined at this time. See Note 2 to the financial statements under “Georgia Power – Nuclear Construction”
for additional information.
Plant Vogtle Units 3 and 4 Rate and Prudency Proceedings
In compliance with a Georgia PSC order approved in 2021, Georgia Power increased annual retail base rates by $318 million effective
August 1, 2023 based on the in-service date of July 31, 2023 for Unit 3.
On December 19, 2023, the Georgia PSC voted to approve the application to adjust rates to include reasonable and prudent Plant Vogtle
Units 3 and 4 costs (Application) as modified by the related stipulated agreement (Prudency Stipulation) among Georgia Power, the staff of
the Georgia PSC, and certain intervenors.
Under the terms of the approved Prudency Stipulation, Georgia Power will recover $7.562 billion in total construction and capital costs
and associated retail rate base items of $1.02 billion, which includes AFUDC financing costs above $4.418 billion (the Georgia PSC-certified
amount) up to $7.562 billion. Georgia Power will also recover projected operations and maintenance expenses, depreciation expense,
nuclear decommissioning accruals, and property taxes, net of projected PTCs. After considering construction and capital costs already in
retail base rates of $2.1 billion and $362 million of associated retail rate base items (approved by the Georgia PSC in 2021) and upon
achieving commercial operation of Unit 4, Georgia Power will include in retail rate base the remaining $5.462 billion of construction and
capital costs as well as $656 million of associated retail rate base items.
Under the Prudency Stipulation, if commercial operation for Unit 4 is not achieved by March 31, 2024, Georgia Power’s ROE used to
determine the NCCR tariff and calculate AFUDC will be reduced to zero, which will result in an estimated negative impact to earnings
of approximately $30 million per month until the month following the date commercial operation for Unit 4 is achieved. The ultimate
outcome of this matter cannot be determined at this time.
Annual retail base revenues will increase approximately $729 million and the average retail base rates will be adjusted by approximately 5%
(net of the elimination of the NCCR tariff described above) effective the first day of the month after Unit 4 achieves commercial operation.
The approval of the Application and the Prudency Stipulation resolves all issues for determination by the Georgia PSC regarding the
reasonableness, prudence, and cost recovery for the remaining Plant Vogtle Units 3 and 4 construction and capital costs not already in retail
base rates.
As a result of the Georgia PSC’s approval of the Prudency Stipulation, Georgia Power recorded a pre-tax credit to income of approximately
$228 million ($170 million after tax) in the fourth quarter 2023 to recognize CWIP costs previously charged to income, which are now
recoverable through retail rates. Associated AFUDC on these costs was also recognized.
See Note 2 to the financial statements under “Georgia Power – Nuclear Construction – Regulatory Matters” for additional information.
Rate Plans
On November 16, 2023, in accordance with the terms of the 2022 ARP, the Georgia PSC approved tariff adjustments effective January 1, 2024
that resulted in a net increase in rates of $191 million.
Georgia Power expects to submit a compliance filing in the fourth quarter 2024 to request tariff adjustments approved pursuant to
the 2022 ARP effective January 1, 2025. The ultimate outcome of this matter cannot be determined at this time.
See Note 2 to the financial statements under “Georgia Power – Rate Plans – 2022 ARP” for additional information.
21
Southern Company 2023 Annual Report Management's Discussion and Analysis of Financial Condition and Results of Operations
Fuel Cost Recovery
On May 16, 2023, the Georgia PSC approved a stipulation agreement between Georgia Power and the staff of the Georgia PSC to increase
annual fuel billings by 54%, or approximately $1.1 billion, effective June 1, 2023. The increase reflects a three-year recovery period for
$2.2 billion of Georgia Power’s under recovered fuel balance at May 31, 2023. Changes in fuel rates have no significant effect on Southern
Company’s or Georgia Power’s net income but do impact the related operating cash flows. See Note 2 to the financial statements under
“Georgia Power – Fuel Cost Recovery” for additional information.
Integrated Resource Plans
On October 27, 2023, Georgia Power filed an updated IRP (2023 IRP Update) with the Georgia PSC, which sets forth a plan to support the
recent increase in the state of Georgia’s projected energy needs since the 2022 IRP. Georgia Power expects the Georgia PSC to render a final
decision on the 2023 IRP Update on April 16, 2024. The ultimate outcome of this matter cannot be determined at this time. See Note 2 to
the financial statements under “Georgia Power – Integrated Resource Plans” for additional information.
Mississippi Power
On October 27, 2023, the FERC approved a settlement agreement filed by Mississippi Power and Cooperative Energy on July 31, 2023
related to Mississippi Power’s July 2022 request for a $23 million increase in annual wholesale base revenues under the MRA tariff.
The settlement agreement provides for a $16 million increase in annual wholesale base revenues, effective September 14, 2022, and a
refund to customers of approximately $6 million primarily related to the difference between the approved rates and interim rates.
In October 2023, Mississippi Power signed an affiliate PPA with Georgia Power for 750 MWs of capacity, which began January 1, 2024
and will continue through December 2028. In order to fulfill this PPA and serve the interests of customers, Mississippi Power now expects
electric generating units identified in its 2021 IRP to remain in service beyond the previously indicated dates. Mississippi Power is expected
to file its next IRP in April 2024 in accordance with the rules and orders of the Mississippi PSC. The ultimate outcome of this matter cannot
be determined at this time.
On February 6, 2024, the Mississippi PSC approved Mississippi Power’s request to increase retail fuel revenues by $18 million annually
effective with the first billing cycle of March 2024.
On February 12, 2024, Mississippi Power submitted its annual ECO Plan filing to the Mississippi PSC, which requested a $9 million annual
increase in revenues. The ultimate outcome of this matter cannot be determined at this time.
See Note 2 to the financial statements under “Mississippi Power” for additional information.
Southern Power
On September 20, 2023, Southern Power acquired 100% of the membership interests in the 200-MW Millers Branch solar project located
in Haskell County, Texas from EDF Renewables Development, Inc. and is continuing construction. The facility’s output is contracted under a
20-year PPA and commercial operation is expected to occur in the fourth quarter 2025. The project includes an option to expand capacity
up to an additional 300 MWs. Subsequent to December 31, 2023, Southern Power committed to expand the construction of the facility
through a second phase adding up to 205 MWs, with commercial operation expected to occur in the second quarter 2026.
On September 22, 2023, Southern Power acquired 100% of the membership interests in the 150-MW South Cheyenne solar project located
in Laramie County, Wyoming from Hanwha Q Cells USA Corp. and is continuing construction. The facility’s output is contracted under a
20-year PPA and commercial operation is expected to occur in the second quarter 2024.
The ultimate outcome of these matters cannot be determined at this time.
Southern Power calculates an investment coverage ratio for its generating assets, including those owned with various partners, based on
the ratio of investment under contract to total investment using the respective facilities’ net book value (or expected in-service value for
facilities under construction) as the investment amount. With the inclusion of investments associated with facilities under construction, as
well as other capacity and energy contracts, Southern Power’s average investment coverage ratio at December 31, 2023 was 97% through
2028 and 89% through 2033, with an average remaining contract duration of approximately 12 years.
See Note 15 to the financial statements under “Southern Power” for additional information.
22
Southern Company 2023 Annual Report Southern Company Gas
On June 15, 2023, the Illinois Commission concluded its review of the Qualifying Infrastructure Plant (QIP) capital investments by Nicor Gas
for calendar year 2019 under the QIP rider, also referred to as Investing in Illinois program. The Illinois Commission disallowed $32 million
of the $415 million of capital investments commissioned in 2019, together with the related return on investment. Nicor Gas recorded a
pre-tax charge to income in the second quarter 2023 of $38 million ($28 million after tax) associated with the disallowance of capital
investments placed in service in 2019. The disallowance is reflected on the statement of income as an $8 million reduction to revenues and
$30 million in estimated loss on regulatory disallowance. On August 3, 2023, the Illinois Commission denied a rehearing request filed by
Nicor Gas. On August 24, 2023, Nicor Gas filed a notice of appeal with the Illinois Appellate Court. Nicor Gas defends these investments in
infrastructure as prudently incurred.
On November 16, 2023, the Illinois Commission approved a $223 million annual base rate increase for Nicor Gas, which became effective
December 1, 2023. The base rate increase was based on a return on equity of 9.51% and an equity ratio of 50.00%.
In connection with Nicor Gas’ general base rate case proceeding, the Illinois Commission disallowed $126.8 million of capital investments
that have been completed or planned to be completed through December 31, 2024. This includes $31 million for capital investments
placed in service in 2022 and 2023 under the Investing in Illinois program and $95.9 million for other transmission and distribution capital
investments. Nicor Gas recorded a pre-tax charge to income in the fourth quarter 2023 of $58 million ($44 million after tax) associated
with the disallowances, with the remaining $69 million related to prospective projects that will be postponed and/or reevaluated.
The disallowance is reflected on the statement of income in estimated loss on regulatory disallowance. On January 3, 2024, the Illinois
Commission denied a request by Nicor Gas for rehearing on the base rate case disallowances associated with capital investment, as well as
on other issues determined in the Illinois Commission’s November 16, 2023 base rate case decision. On February 6, 2024, Nicor Gas filed a
notice of appeal with the Illinois Appellate Court related to the Illinois Commission’s rate case ruling.
Any further cost disallowances by the Illinois Commission in the pending cases could be material to the financial statements of Southern
Company Gas. The ultimate outcome of these matters cannot be determined at this time. See Note 2 to the financial statements under
“Southern Company Gas – Infrastructure Replacement Programs and Capital Projects – Nicor Gas” for additional information.
On December 19, 2023, the Georgia PSC approved Atlanta Gas Light’s annual GRAM filing, which resulted in an annual base rate increase of
$53 million effective January 1, 2024.
On February 1, 2024, Atlanta Gas Light filed its triennial Integrated Capacity and Delivery Plan (i-CDP) with the Georgia PSC, which
included a series of ongoing and proposed pipeline safety, reliability, and growth programs for the next 10 years (2025 through 2034), as
well as the required capital investments and related costs to implement the programs. The i-CDP reflected capital investments totaling
approximately $0.7 billion to $1.0 billion annually. Atlanta Gas Light expects the Georgia PSC to issue a final order on this matter in the
third quarter 2024. The ultimate outcome of this matter cannot be determined at this time.
On August 28, 2023, the Virginia Commission approved a stipulation agreement related to Virginia Natural Gas’ August 2022 general base
rate case filing, which allowed for a $48 million increase in annual base rate revenues based on a ROE of 9.70% and an equity ratio of
49.06%. Interim rates became effective as of January 1, 2023, subject to refund, based on Virginia Natural Gas’ original requested increase
of approximately $69 million. Refunds to customers related to the difference between the approved rates effective September 1, 2023 and
the interim rates were completed during the fourth quarter 2023.
On February 9, 2024, Virginia Natural Gas filed with the Virginia Commission a request to extend the existing SAVE program through
2029. The request includes investments of $70 million in each year from 2025 through 2029, with a potential variance of up to
$5 million allowed for the program, for a maximum total investment over the five-year extension (2025 through 2029) of $355 million.
Virginia Natural Gas expects the Virginia Commission to issue a final order on this matter in the second quarter 2024. The ultimate
outcome of this matter cannot be determined at this time.
Key Performance Indicators
In striving to achieve attractive risk-adjusted returns while providing cost-effective energy to approximately 8.9 million electric and gas
utility customers collectively, the traditional electric operating companies and Southern Company Gas continue 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, and execution of major construction projects. In addition, Southern Company and the Subsidiary Registrants focus on
earnings per share (EPS) and net income, respectively, as a key performance indicator. See RESULTS OF OPERATIONS herein for information
on the Registrants’ financial performance.
23
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report The financial success of the traditional electric operating companies and Southern Company Gas is directly tied to customer satisfaction.
Key elements of ensuring customer satisfaction include outstanding service, high reliability, and competitive prices. The traditional electric
operating companies use customer satisfaction surveys to evaluate their results and generally target the top quartile of these surveys in
measuring performance. Reliability indicators are also used to evaluate results. See Note 2 to the financial statements under “Alabama
Power – Rate RSE” and “Mississippi Power – Performance Evaluation Plan” for additional information on Alabama Power’s Rate RSE and
Mississippi Power’s PEP rate plan, respectively, both of which contain mechanisms that directly tie customer service indicators to the
allowed equity return.
Southern Company Gas also 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.
See RESULTS OF OPERATIONS – “Southern Company Gas” for additional information on Southern Company Gas’ operating metrics.
Southern Power continues to focus on several key performance indicators, including, but not limited to, the equivalent forced outage rate
and contract availability to evaluate operating results and help ensure its ability to meet its contractual commitments to customers.
RESULTS OF OPERATIONS
Southern Company
Consolidated net income attributable to Southern Company was $4.0 billion in 2023, an increase of $452 million, or 12.8%, from 2022.
The increase was primarily due to lower non-fuel operations and maintenance costs, an increase in retail electric revenues associated
with rates and pricing, a decrease in income tax expense, a decrease in after-tax charges related to the construction of Plant Vogtle
Units 3 and 4, an increase in other revenues, an increase in natural gas revenues from rate increases and continued infrastructure
replacement, and a goodwill impairment charge in 2022 at PowerSecure, partially offset by higher depreciation and amortization, higher
interest expense, and a decrease in retail electric revenues associated with milder weather in 2023 compared to 2022. See Notes 1 and
2 to the financial statements under “Goodwill and Other Intangible Assets” and “Georgia Power – Nuclear Construction,” respectively, for
additional information.
Basic EPS was $3.64 in 2023 and $3.28 in 2022. Diluted EPS, which factors in additional shares related to stock-based compensation,
was $3.62 in 2023 and $3.26 in 2022. EPS for 2023 and 2022 was negatively impacted by $0.06 and $0.04 per share, respectively, as a
result of increases in the average shares outstanding. See Note 8 to the financial statements under “Outstanding Classes of Capital Stock –
Southern Company” for additional information.
Dividends paid per share of common stock were $2.78 in 2023 and $2.70 in 2022. In January 2024, Southern Company declared a
quarterly dividend of 70 cents per share. For 2023, the dividend payout ratio was 76% compared to 82% for 2022.
Discussion of Southern Company’s results of operations is divided into three parts – the Southern Company system’s primary business of
electricity sales, its gas business, and its other business activities.
2023
2022
(in millions)
$3,994
615
(633)
$3,976
$ 3,672
572
(720)
$ 3,524
Electricity business
Gas business
Other business activities
Net Income
24
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Electricity Business
Southern Company’s electric utilities generate and sell electricity to retail and wholesale customers. A condensed statement of income for
the electricity business follows:
Electric operating revenues
Fuel
Purchased power
Cost of other sales
Other operations and maintenance
Depreciation and amortization
Taxes other than income taxes
Estimated loss on Plant Vogtle Units 3 and 4
Total electric operating expenses
Operating income
Allowance for equity funds used during construction
Interest expense, net of amounts capitalized
Other income (expense), net
Income taxes
Net income
Less:
Dividends on preferred stock of subsidiaries
Net loss attributable to noncontrolling interests
Net Income Attributable to Southern Company
Electric Operating Revenues
Increase
(Decrease)
from 2022
2023
(in millions)
$19,998
4,365
883
171
4,679
3,865
1,159
(68)
15,054
4,944
247
1,274
533
583
3,867
—
(127)
$ 3,994
$ (2,875)
(2,470)
(710)
57
(550)
836
34
(251)
(3,054)
179
37
207
17
(265)
291
(11)
(20)
322
$
Electric operating revenues for 2023 were $20.0 billion, reflecting a $2.9 billion, or 12.6%, decrease from 2022. Details of electric operating
revenues were as follows:
Retail electric — prior year
Estimated change resulting from —
Rates and pricing
Sales decline
Weather
Fuel and other cost recovery
Retail electric — current year
Wholesale electric revenues
Other electric revenues
Other revenues
Electric operating revenues
2023
2022
(in millions)
$ 18,197
437
(33)
(229)
(2,029)
$ 16,343
2,467
792
396
$ 19,998
$ 18,197
3,641
747
288
$ 22,873
Retail electric revenues decreased $1.9 billion, or 10.2%, in 2023 as compared to 2022. The significant factors driving this change are
shown in the preceding table. The increase in rates and pricing in 2023 was primarily due to base tariff increases in accordance with
Georgia Power’s 2022 ARP, revenue reductions in 2022 resulting from Georgia Power’s retail ROE exceeding the allowed retail ROE range, an
increase in Rate CNP Compliance revenues at Alabama Power, and a lower Rate RSE customer refund accrual in 2023 compared to 2022 at
Alabama Power, partially offset by lower contributions from commercial and industrial customers with variable demand-driven pricing and
a decrease in the revenues recognized under the NCCR tariff, both at Georgia Power.
Electric rates for the traditional electric operating companies include provisions to adjust billings for fluctuations in fuel costs, including the
energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy
component of PPA costs, and do not affect net income. The traditional electric operating companies each have one or more regulatory
mechanisms to recover other costs such as environmental and other compliance costs, storm damage, new plants, and PPA capacity costs.
25
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report See Note 2 to the financial statements under “Alabama Power” and “Georgia Power” for additional information. Also see “Energy Sales”
herein for a discussion of changes in the volume of energy sold, including estimated changes related to sales and weather.
Wholesale electric revenues from power sales were as follows:
Capacity and other
Energy
Total
2023
2022
(in millions)
$ 630
1,837
$2,467
$ 625
3,016
$ 3,641
In 2023, wholesale electric revenues decreased $1.2 billion, or 32.2%, as compared to 2022 primarily due to a decrease in energy revenues.
Energy revenues decreased $884 million at Southern Power and $295 million at the traditional electric operating companies primarily due
to fuel and purchased power price decreases compared to 2022. Also contributing to the Southern Power decrease was a net decrease in
the volume of KWHs sold primarily associated with natural gas PPAs.
Wholesale electric revenues consist of revenues from PPAs and short-term opportunity sales. Wholesale electric revenues from PPAs (other
than solar and wind PPAs) have both capacity and energy components. Capacity revenues generally represent the greatest contribution to net
income and are designed to provide recovery of fixed costs plus a return on investment. Energy revenues will vary depending on fuel prices,
the market prices of wholesale energy compared to the Southern Company system’s generation, demand for energy within the Southern
Company system’s electric service territory, and the availability of the Southern Company system’s generation. Increases and decreases in
energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact
on net income. Energy sales from solar and wind PPAs do not have a capacity charge and customers either purchase the energy output of
a dedicated renewable facility through an energy charge or through a fixed price related to the energy. As a result, the ability to recover
fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can
be impacted by weather conditions, equipment performance, transmission constraints, and other factors. Wholesale electric revenues at
Mississippi Power include FERC-regulated MRA sales under cost-based tariffs as well as market-based sales. Short-term opportunity sales are
made at market-based rates that generally provide a margin above the Southern Company system’s variable cost to produce the energy.
Other Electric Revenues
Other electric revenues increased $45 million, or 6.0%, in 2023 as compared to 2022. The increase was primarily due to increases of
$23 million in outdoor lighting sales at Georgia Power, $18 million resulting from receipts of liquidated damages associated with generation
facility production guarantees and an arbitration award at Southern Power, $17 million in realized gains associated with price stability
products for retail customers on variable demand-driven pricing tariffs at Georgia Power, and $17 million in retail solar program fees at
Georgia Power, partially offset by decreases of $25 million in cogeneration steam revenues associated with lower natural gas prices at
Alabama Power and $14 million in rent revenues primarily at Alabama Power.
Energy Sales
Changes in revenues are influenced heavily by the change in the volume of energy sold from year to year. KWH sales for 2023 and
the percent change from 2022 were as follows:
Residential
Commercial
Industrial
Other
Total retail
Wholesale
Total energy sales
Total
KWHs
(in billions)
47.1
48.3
48.6
0.5
144.5
51.0
195.5
2023
Total KWH
Percent
Change
Weather-
Adjusted Percent
Change(*)
(5.1) %
0.1
(1.9)
(7.2)
(2.3)
(9.4)
(4.3) %
(0.5) %
1.3
(1.9)
(6.8)
(0.4) %
(*) Weather-adjusted KWH sales are estimated using statistical models of the historical relationship between temperatures and energy sales, and then
removing the estimated effect of deviations from normal temperature conditions. Normal temperature conditions are defined as those experienced in the
applicable service territory over a specified historical period. This metric is useful because it allows trends in historical operations to be evaluated apart
from the influence of weather conditions. Management also considers this metric in developing long-term capital and financial plans.
26
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Changes in retail energy sales are generally the result of changes in electricity usage by customers, weather, and the number of customers.
Weather-adjusted retail energy sales decreased 587 million KWHs in 2023 as compared to 2022. Weather-adjusted residential KWH sales
decreased 0.5% primarily due to decreased customer usage, partially offset by customer growth. Weather-adjusted commercial KWH sales
increased 1.3% primarily due to increased customer usage and customer growth. Industrial KWH sales decreased 1.9% primarily due to
decreases in the chemicals, forest products, and textiles sectors.
See “Electric Operating Revenues” above for a discussion of significant changes in wholesale revenues related to changes in price and KWH sales.
Other Revenues
Other revenues increased $108 million, or 37.5%, in 2023 as compared to 2022. The increase was primarily due to increases of $54 million
in power delivery construction and maintenance projects at Georgia Power, $34 million in unregulated sales of products and services at
Alabama Power, and $25 million associated with energy conservation projects at Georgia Power.
Fuel and Purchased Power Expenses
The mix of fuel sources for the generation of electricity is determined primarily by demand, the unit cost of fuel consumed, and the
availability of generating units. Additionally, the electric utilities purchase a portion of their electricity needs from the wholesale market.
Details of the Southern Company system’s generation and purchased power were as follows:
Total generation (in billions of KWHs)(a)(b)
Total purchased power (in billions of KWHs)
Sources of generation (percent)(a) —
Gas
Nuclear(b)
Coal
Hydro
Wind, Solar, and Other
Cost of fuel, generated (in cents per net KWH) —
Gas(a)
Nuclear(b)
Coal
Average cost of fuel, generated (in cents per net KWH)(a)(b)
Average cost of purchased power (in cents per net KWH)(c)
2023
184
18
54
18
17
3
8
2.77
0.76
4.33
2.68
5.17
2022
186
25
51
16
22
3
8
5.29
0.72
3.67
4.05
7.66
(a) Excludes Central Alabama Generating Station KWHs and associated cost of fuel through July 12, 2022 as its fuel was previously provided by the purchaser
under a power sales agreement. See Note 15 to the financial statements under "Alabama Power" for additional information.
(b) Excludes KWHs generated from test period energy at Plant Vogtle Unit 3 prior to its in-service date. The related fuel costs are charged to CWIP in
accordance with FERC guidance. See Note 2 to the financial statements under "Georgia Power – Nuclear Construction" for additional information on Plant
Vogtle Units 3 and 4.
(c) Average cost of purchased power includes fuel purchased by the Southern Company system for tolling agreements where power is generated by the provider.
In 2023, total fuel and purchased power expenses were $5.2 billion, a decrease of $3.2 billion, or 37.7%, as compared to 2022.
The decrease was primarily the result of a $2.7 billion decrease in the average cost of fuel generated and purchased and a $513 million
net decrease in the volume of KWHs generated and purchased.
Fuel and purchased power energy transactions at the traditional electric operating companies are generally offset by fuel revenues and
do not have a significant impact on net income. See Note 2 to the financial statements 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.
Fuel
In 2023, fuel expense was $4.4 billion, a decrease of $2.5 billion, or 36.1%, as compared to 2022. The decrease was primarily due to a
47.6% decrease in the average cost of natural gas per KWH generated and a 22.5% decrease in the volume of KWHs generated by coal, partially
offset by an 18.2% decrease in the volume of KWHs generated by hydro, an 18.0% increase in the average cost of coal per KWH generated, a
10.8% increase in the volume of KWHs generated by nuclear, and a 6.9% increase in the volume of KWHs generated by natural gas.
27
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Purchased Power
In 2023, purchased power expense was $883 million, a decrease of $710 million, or 44.6%, as compared to 2022. The decrease was
primarily due to a 32.5% decrease in the average cost per KWH purchased primarily due to lower natural gas prices and a 27.5% decrease
in the volume of KWHs purchased.
Energy purchases will vary depending on demand for energy within the Southern Company system’s electric service territory, the market
prices of wholesale energy as compared to the cost of the Southern Company system’s generation, and the availability of the Southern
Company system’s generation.
Cost of Other Sales
Cost of other sales increased $57 million, or 50.0%, in 2023 as compared to 2022. The increase was primarily due to increases of
$40 million from unregulated power delivery construction and maintenance projects at Georgia Power and $20 million in expenses related
to unregulated products and services at Alabama Power.
Other Operations and Maintenance Expenses
Other operations and maintenance expenses decreased $550 million, or 10.5%, in 2023 as compared to 2022. The decrease reflects
a decrease of $189 million associated with the reliability reserve accruals and reliability-related expenditures incurred at Alabama
Power. Excluding this decrease, there were decreases of $223 million in transmission and distribution expenses primarily related
to line maintenance, $182 million in storm damage recovery as authorized in Georgia Power’s 2022 ARP, $91 million in generation
non-outage maintenance expenses and planned outages, and $50 million in employee compensation and benefit expenses, partially
offset by an $86 million increase in technology infrastructure and application production costs and a $73 million increase in generation
environmental projects primarily at Georgia Power. See Note 1 to the financial statements under “Storm Damage and Reliability
Reserves” for additional information.
Depreciation and Amortization
Depreciation and amortization increased $836 million, or 27.6%, in 2023 as compared to 2022. The increase was primarily due to
increases of $541 million and $190 million resulting from higher depreciation rates at Alabama Power and Georgia Power, respectively, and
$79 million from additional plant in service. See Note 2 to the financial statements under “Alabama Power – Rate CNP Depreciation” for
additional information.
Taxes Other Than Income Taxes
Taxes other than income taxes increased $34 million, or 3.0%, in 2023 as compared to 2022. The increase was primarily due to increases
of $62 million in property taxes primarily at Georgia Power resulting from an increase in the assessed value of property and $14 million in
utility license taxes at Alabama Power, partially offset by a decrease of $40 million in municipal franchise fees resulting from lower retail
revenues at Georgia Power.
Estimated Loss on Plant Vogtle Units 3 and 4
Georgia Power recorded pre-tax charges (credits) to income for the estimated probable loss on Plant Vogtle Units 3 and 4 totaling
$(68) million and $183 million in 2023 and 2022, respectively. The charges (credits) to income in each year were recorded to reflect Georgia
Power’s revisions to the total project capital cost forecast to complete construction and start-up of Plant Vogtle Units 3 and 4 and the
related cost recovery. See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” for additional information.
Allowance for Equity Funds Used During Construction
Allowance for equity funds used during construction increased $37 million, or 17.6%, in 2023 as compared to 2022. The increase was
primarily associated with an increase in capital expenditures subject to AFUDC at Georgia Power and an increase in capital expenditures
related to hydro production and Plant Barry Unit 8 construction at Alabama Power. See Note 2 to the financial statements under “Alabama
Power – Rate CNP New Plant” for additional information.
Interest Expense, Net of Amounts Capitalized
Interest expense, net of amounts capitalized increased $207 million, or 19.4%, in 2023 as compared to 2022. The increase reflects
approximately $120 million related to higher interest rates and $96 million related to higher average outstanding borrowings. See Note 8 to
the financial statements for additional information.
Other Income (Expense), Net
Other income (expense), net increased $17 million, or 3.3%, in 2023 as compared to 2022 primarily due to a $48 million decrease in
charitable donations primarily at Georgia Power, a $15 million increase in interest income, and a $14 million decrease in non-operating
28
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report benefit-related expenses at Alabama Power, partially offset by a $42 million decrease in non-service cost-related retirement benefits
income and a $13 million decrease in customer charges related to contributions in aid of construction at Georgia Power. See Note 11 to the
financial statements for additional information.
Income Taxes
Income taxes decreased $265 million, or 31.3%, in 2023 as compared to 2022. The decrease was primarily due to a $252 million increase
in the flowback of certain excess deferred income taxes at Alabama Power, an $85 million decrease in charges to a valuation allowance
on certain state tax credit carryforwards at Georgia Power, generation of $35 million of advanced nuclear PTCs at Georgia Power, and
a $32 million adjustment in 2022 related to a prior year state tax credit carryforward at Georgia Power, partially offset by a $145 million
decrease in the flowback of certain excess deferred income taxes at Georgia Power that ended in 2022. See Note 10 to the financial
statements for additional information.
Net Loss Attributable to Noncontrolling Interests
Substantially all noncontrolling interests relate to renewable projects at Southern Power. Net loss attributable to noncontrolling interests
increased $20 million, or 18.7%, in 2023 as compared to 2022. The increased loss was primarily due to $25 million in higher HLBV loss
allocations to Southern Power’s wind tax equity partners and $5 million in lower income allocations to Southern Power’s equity partners,
partially offset by $10 million in lower HLBV loss allocations to Southern Power’s battery energy storage partners.
Gas Business
Southern Company Gas distributes natural gas through utilities in four states and is involved in several other complementary businesses
including gas pipeline investments and gas marketing services.
A condensed statement of income for the gas business follows:
Operating revenues
Cost of natural gas
Other operations and maintenance
Depreciation and amortization
Taxes other than income taxes
Impairment charges
Estimated loss on regulatory disallowance
Gain on dispositions, net
Total operating expenses
Operating income
Earnings from equity method investments
Interest expense, net of amounts capitalized
Other income (expense), net
Income taxes
Net income
Increase
(Decrease)
from 2022
2023
(in millions)
$4,702
1,644
1,194
582
262
—
88
(7)
$(1,260)
(1,360)
18
23
(20)
(131)
88
(3)
3,763
(1,385)
939
140
310
57
211
$ 615
$
125
(8)
47
4
31
43
During the period from November through March when natural gas usage and operating revenues are generally higher (Heating Season),
more customers are connected to Southern Company Gas’ distribution systems and natural gas usage is higher in periods of colder weather.
Southern Company Gas’ base operating expenses, excluding cost of natural gas, bad debt expense, and certain incentive compensation
costs, are incurred relatively equally over any given year. Thus, operating results can vary significantly from quarter to quarter as a result of
seasonality. For 2023, the percentage of operating revenues and net income generated during the Heating Season (January through March
and November through December) were 67% and 73%, respectively. For 2022, the percentage of operating revenues and net income
generated during the Heating Season were 67% and 66%, respectively.
29
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report
Operating Revenues
Operating revenues in 2023 were $4.7 billion, reflecting a $1.3 billion, or 21.1%, decrease compared to 2022. Details of operating revenues
were as follows:
Operating revenues – prior year
Estimated change resulting from –
Infrastructure replacement programs and base rate changes
Gas costs and other cost recovery
Gas marketing services
Other
Operating revenues – current year
2023
(in millions)
$ 5,962
194
(1,323)
(93)
(38)
$ 4,702
Revenues from infrastructure replacement programs and base rate changes increased in 2023 primarily due to rate increases at the natural
gas distribution utilities and continued investment in infrastructure replacement, partially offset by lower volumes sold and regulatory
disallowances at Nicor Gas. See Note 2 to the financial statements under “Southern Company Gas” for additional information.
Revenues associated with gas costs and other cost recovery decreased in 2023 primarily due to lower natural gas cost recovery associated
with lower natural gas prices, the timing of natural gas purchases, and the recovery of those costs from customers. The natural gas
distribution utilities have weather or revenue normalization mechanisms that mitigate revenue fluctuations from customer consumption
changes. 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. See “Cost of Natural Gas” herein for additional information.
Revenues from gas marketing services decreased in 2023 primarily due to lower natural gas prices and the timing of unrealized hedge losses.
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 were immaterial.
Cost of Natural Gas
Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, the natural gas distribution utilities rates include
provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally
equal the amount expensed in cost of natural gas and do not affect net income from the natural gas distribution utilities. See Note 2 to
the financial statements under “Southern Company Gas – Natural Gas Cost Recovery” for additional information. Cost of natural gas at the
natural gas distribution utilities represented 83.5% of the total cost of natural gas for 2023.
Gas marketing services customers are charged for actual and estimated natural gas consumed. Cost of natural gas includes the cost of fuel
and associated transportation costs, lost and unaccounted for gas, and gains and losses associated with certain derivatives.
Cost of natural gas was $1.6 billion, a decrease of $1.4 billion, or 45.3%, in 2023 compared to 2022, which reflects lower gas cost recovery
in 2023 as a result of a 58.8% decrease in natural gas prices compared to 2022.
Other Operations and Maintenance Expenses
Other operations and maintenance expenses increased $18 million, or 1.5%, in 2023 compared to 2022. The increase was primarily due to
increases of $70 million in compensation and benefits and $20 million related to energy service contracts, partially offset by a decrease
of $60 million in expenses passed through to customers primarily related to bad debt and energy efficiency programs at the natural gas
distribution utilities. See Note 2 to the financial statements under “Southern Company Gas” for additional information.
Depreciation and Amortization
Depreciation and amortization increased $23 million, or 4.1%, in 2023 compared to 2022. The increase was primarily due to continued
infrastructure investments at the natural gas distribution utilities. See Note 2 to the financial statements under “Southern Company
Gas – Infrastructure Replacement Programs and Capital Projects” for additional information.
Taxes Other Than Income Taxes
Taxes other than income taxes decreased $20 million, or 7.1%, in 2023 compared to 2022. The decrease was primarily due to a $29 million
decrease in revenue taxes, partially offset by increases in payroll and property taxes.
30
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Impairment Charges
In 2022, Southern Company Gas recorded pre-tax impairment charges totaling approximately $131 million ($99 million after tax) as a
result of an agreement to sell two natural gas storage facilities. See Note 15 to the financial statements under “Southern Company Gas” for
additional information.
Estimated Loss on Regulatory Disallowance
In 2023, Southern Company Gas recorded pre-tax charges related to the disallowance of certain capital investments at Nicor Gas,
$88 million of which was recorded in estimated loss on regulatory disallowance. See Note 2 under “Southern Company Gas – Infrastructure
Replacement Programs and Capital Projects – Nicor Gas” for additional information.
Interest Expense, Net of Amounts Capitalized
Interest expense, net of amounts capitalized increased $47 million, or 17.9%, in 2023 compared to 2022. The increase reflects
approximately $43 million related to higher interest rates and $8 million related to higher average outstanding borrowings. See Note 8 to
the financial statements for additional information.
Income Taxes
Income taxes increased $31 million, or 17.2%, in 2023 compared to 2022. The increase was primarily due to $33 million of tax benefit in
2022 related to the impairment charges associated with the sale of two natural gas storage facilities and higher taxes related to increased
earnings, partially offset by approximately $24 million related to the regulatory disallowances at Nicor Gas. See Notes 2 and 15 to the
financial statements under “Southern Company Gas” and Note 10 to the financial statements for additional information.
Other Business Activities
Southern Company’s other business activities primarily include the parent company (which does not allocate operating expenses to
business units); PowerSecure, which provides distributed energy and resilience solutions and deploys microgrids for commercial, industrial,
governmental, and utility customers; Southern Holdings, which invests in various projects; and Southern Linc, which provides digital
wireless communications for use by the Southern Company system and also markets these services to the public and provides fiber optics
services within the Southeast.
A condensed statement of operations for Southern Company’s other business activities follows:
Operating revenues
Cost of other sales
Other operations and maintenance
Depreciation and amortization
Taxes other than income taxes
Impairment charges
Gain on dispositions, net
Total operating expenses
Operating income (loss)
Earnings from equity method investments
Interest expense
Other income (expense), net
Income taxes (benefit)
Net loss
Operating Revenues
Increase
(Decrease)
from 2022
2023
(in millions)
$ 554
355
175
77
4
—
—
611
(57)
5
863
(16)
(298)
$ (633)
$ 110
87
(26)
2
—
(119)
14
(42)
152
2
171
39
(65)
$ 87
Operating revenues for these other business activities increased $110 million, or 24.8%, in 2023 as compared to 2022 primarily due to
increases of $92 million related to distributed infrastructure projects at PowerSecure and $24 million primarily related to sales associated
with commercial customers at Southern Linc.
Cost of Other Sales
Cost of other sales for these other business activities increased $87 million, or 32.5%, in 2023 as compared to 2022 primarily due to
increases of $58 million related to distributed infrastructure projects at PowerSecure and $23 million primarily related to sales associated
with commercial customers at Southern Linc.
31
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Other Operations and Maintenance
Other operations and maintenance expenses for these other business activities decreased $26 million, or 12.9%, in 2023 as compared to
2022 primarily due to a decrease at the parent company related to cost containment efforts and lower director compensation expenses.
Impairment Charges
In 2022, a goodwill impairment charge of $119 million was recorded at PowerSecure. See Note 1 to the financial statements under
“Goodwill and Other Intangible Assets” for additional information.
Gain on Dispositions, Net
In 2022, a $14 million gain was recorded at the parent company as a result of the early termination of the transition services agreement
related to the 2019 sale of Gulf Power.
Interest Expense
Interest expense for these other business activities increased $171 million, or 24.7%, in 2023 as compared to 2022. The increase primarily
results from parent company financing activities and includes approximately $112 million related to higher interest rates and $73 million
related to higher average outstanding borrowings. See Note 8 to the financial statements for additional information.
Other Income (Expense), Net
Other income (expense), net for these other business activities increased $39 million, or 70.9%, in 2023 as compared to 2022 primarily
due to a $29 million decrease in charitable donations and a $12 million increase in interest income, both primarily at the parent company.
See Note 15 to the financial statements under “Southern Company” for additional information.
Income Taxes (Benefit)
The income tax benefit for these other business activities increased $65 million, or 27.9%, in 2023 as compared to 2022. The increase was
primarily due to a $35 million tax benefit in 2023 related to a reversal of an uncertain tax position associated with the 2019 sale of Gulf
Power and higher pre-tax losses, both at the parent company.
FUTURE EARNINGS POTENTIAL
General
Prices for electric service provided by the traditional electric operating companies and natural gas distribution service provided by the
natural gas distribution utilities to retail customers are set by state PSCs or other applicable state regulatory agencies under cost-based
regulatory principles. Retail rates and earnings are reviewed through various regulatory mechanisms and/or processes and may be
adjusted periodically within certain limitations. Effectively operating pursuant to these regulatory mechanisms and/or processes and
appropriately balancing required costs and capital expenditures with customer prices will continue to challenge the traditional electric
operating companies and natural gas distribution utilities for the foreseeable future. Prices for wholesale electricity sales, interconnecting
transmission lines, and the exchange of electric power are regulated by the FERC. Southern Power continues to focus on long-term PPAs.
See ACCOUNTING POLICIES – “Application of Critical Accounting Policies and Estimates – Utility Regulation” herein and Note 2 to the
financial statements for additional information about regulatory matters.
Each Registrant’s results of operations are not necessarily indicative of its future earnings potential. The level of the Registrants’ future
earnings depends on numerous factors that affect the opportunities, challenges, and risks of the Registrants’ primary businesses of selling
electricity and/or distributing natural gas, as described further herein.
For the traditional electric operating companies, these factors include the ability to maintain constructive regulatory environments
that allow for the timely recovery of prudently-incurred costs during a time of increasing costs, including those related to projected
long-term demand growth, stringent environmental standards, including CCR rules, safety, system reliability and resiliency, fuel, restoration
following major storms, and capital expenditures, including constructing new electric generating plants and expanding and improving the
transmission and distribution systems; continued customer growth; and the trends of higher inflation and reduced electricity usage per
customer, especially in residential and commercial markets. For Georgia Power, other major factors are completing construction and start-up
of Plant Vogtle Unit 4 and meeting the related cost and schedule projections.
Earnings in the electricity business will also depend upon maintaining and growing sales, considering, among other things, the adoption
and/or penetration rates of increasingly energy-efficient technologies and increasing volumes of electronic commerce transactions, which
could contribute to a net reduction in customer usage.
32
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Global and U.S. economic conditions continue to be affected by higher-than-expected inflation that arose from the COVID-19 pandemic
and associated policy responses of governments and central banks. In response to elevated inflation levels, the U.S. Federal Reserve raised
interest rates faster than any rate increase cycle in the last 40 years. The actions by the U.S. Federal Reserve have helped to slow the rate
of inflation and curtail economic activity. Although target levels of inflation have yet to be achieved, the U.S. Federal Reserve has indicated
its current intention to pause future rate increases and evaluate rate cuts in the near term. The shifting economic policy variables and
weakening of historic relationships among economic activity, prices, and employment have increased the uncertainty of future levels of
economic activity, which will directly impact future energy demand and operating costs. Weakening economic activity increases the risk of
slowing or declining energy sales. See RESULTS OF OPERATIONS herein for information on energy sales in the Southern Company system’s
service territory during 2023.
The level of future earnings for Southern Power’s competitive wholesale electric business depends on numerous factors including the
parameters of the wholesale market and the efficient operation of its wholesale generating assets; Southern Power’s ability to execute its
growth strategy through the development, construction, or acquisition of renewable facilities and other energy projects while containing
costs; regulatory matters; customer creditworthiness; total electric generating capacity available in Southern Power’s market areas;
Southern Power’s ability to successfully remarket capacity as current contracts expire; renewable portfolio standards; continued availability
of federal and state ITCs and PTCs, which could be impacted by future tax legislation; transmission constraints; cost of generation from
units within the Southern Company power pool; and operational limitations. See “Income Tax Matters” herein for information regarding the
IRA’s expansion of the availability of federal ITCs and PTCs. Also see Notes 10 and 15 to the financial statements for additional information.
The level of future earnings for Southern Company Gas’ primary business of distributing natural gas and its complementary businesses
in the gas pipeline investments and gas marketing services sectors depends on numerous factors. These factors include the natural gas
distribution utilities’ ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred
costs, including those related to projected long-term demand growth, safety, system reliability and resiliency, natural gas, and capital
expenditures, including expanding and improving the natural gas distribution systems; the completion and subsequent operation of
ongoing infrastructure and other construction projects; customer creditworthiness; and certain policies to limit the use of natural gas, such
as the potential in Illinois and across certain other parts of the U.S. for state or municipal bans on the use of natural gas or policies designed
to promote electrification. The volatility of natural gas prices has an impact on Southern Company Gas’ customer rates, its long-term
competitive position against other energy sources, and the ability of Southern Company Gas’ gas marketing services business to capture
value from locational and seasonal spreads. Additionally, changes in commodity prices, primarily driven by tight gas supplies, geopolitical
events, and diminished gas production, subject a portion of Southern Company Gas’ operations to earnings variability and may result in
higher natural gas prices. Additional economic factors may contribute to this environment. The demand for natural gas may increase, which
may cause natural gas prices to rise and drive higher volatility in the natural gas markets on a longer-term basis. Alternatively, a significant
drop in oil and natural gas prices could lead to a consolidation of natural gas producers or reduced levels of natural gas production.
Earnings for both the electricity and natural gas businesses are subject to a variety of other factors. These factors include weather;
competition; developing new and maintaining existing energy contracts and associated load requirements with wholesale customers;
customer energy conservation practices; the use of alternative energy sources by customers; government incentives to reduce overall energy
usage; fuel, labor, and material prices in an environment of heightened inflation and material and labor supply chain disruptions; and the
price elasticity of demand. Demand for electricity and natural gas in the Registrants’ service territories is primarily driven by the pace of
economic growth or decline that may be affected by changes in regional and global economic conditions, which may impact future earnings.
Mississippi Power provides service under long-term contracts with rural electric cooperative associations and a municipality located in
southeastern Mississippi under requirements cost-based electric tariffs which are subject to regulation by the FERC. The contracts with
these wholesale customers represented 14.0% of Mississippi Power’s total operating revenues in 2023.
As part of its ongoing effort to adapt to changing market conditions, Southern Company continues to evaluate and consider a wide array
of potential business strategies. These strategies may include business combinations, partnerships, and acquisitions involving other utility
or non-utility businesses or properties, disposition of, or the sale of interests in, certain assets or businesses, internal restructuring, or some
combination thereof. Furthermore, Southern Company may engage in new business ventures that arise from competitive and regulatory
changes in the utility industry. Pursuit of any of the above strategies, or any combination thereof, may significantly affect the business
operations, risks, and financial condition of Southern Company. In addition, Southern Power and Southern Company Gas regularly consider
and evaluate joint development arrangements as well as acquisitions and dispositions of businesses and assets as part of their business
strategies. See Note 15 to the financial statements for additional information.
33
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report 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, avian and other wildlife and habitat protection, and other natural resources. The Southern Company
system maintains comprehensive environmental compliance and GHG strategies to assess both current and upcoming requirements
and compliance costs associated with these environmental laws and regulations. New or revised environmental laws and regulations
could further affect many areas of operations for the Subsidiary Registrants. The costs required to comply with environmental laws and
regulations and to achieve stated goals, including capital expenditures, operations and maintenance costs, and costs reflected in ARO
liabilities, may impact future electric generating unit retirement and replacement decisions (which are generally subject to approval
from the traditional electric operating companies’ respective state PSCs), 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, including existing ratemaking and billing provisions. The ultimate impact of environmental laws and regulations and the GHG goals
discussed herein cannot be determined at this time and will depend on various factors, such as state adoption and implementation of
requirements, the availability and cost of any deployed technology, fuel prices, the outcome of pending and/or future legal challenges and
regulatory matters, and the ability to continue recovering the related costs, through rates for the traditional electric operating companies
and the natural gas distribution utilities and/or through long-term wholesale agreements for the traditional electric operating companies
and Southern Power.
Alabama Power and Mississippi Power recover environmental compliance costs through separate mechanisms, Rate CNP Compliance and
the ECO Plan, respectively. Georgia Power’s base rates include an ECCR tariff that allows for the recovery of environmental compliance
costs. The natural gas distribution utilities of Southern Company Gas generally recover environmental remediation expenditures
through rate mechanisms approved by their applicable state regulatory agencies. See Notes 2 and 3 to the financial statements for
additional information.
Southern Power’s PPAs generally contain provisions that permit charging the counterparty for some of the new costs incurred as a
result of changes in environmental laws and regulations. Since Southern Power’s units are generally newer natural gas and renewable
generating facilities, costs associated with environmental compliance for these facilities have been less significant than for similarly
situated coal or older natural gas generating facilities. Environmental, natural resource, and land use concerns, including the applicability
of air quality limitations, the potential presence of wetlands or threatened and endangered species, the availability of water withdrawal
rights, uncertainties regarding impacts such as increased light or noise, and concerns about potential adverse health impacts can, however,
increase the cost of siting and/or operating any type of existing or future facility. The impact of such laws, regulations, and other
considerations on Southern Power and subsequent recovery through PPA provisions cannot be determined at this time.
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 may have the potential to affect their demand
for electricity and natural gas.
Although the timing, requirements, and estimated costs could change as environmental laws and regulations are adopted or modified, as
compliance plans are revised or updated, and as legal challenges to rules are initiated or completed, estimated capital expenditures through
2028 based on the current environmental compliance strategy for the Southern Company system and the traditional electric operating
companies are as follows:
Southern Company
Alabama Power
Georgia Power
Mississippi Power
2024
2025
2026
(in millions)
2027
2028
Total
$150
45
92
13
$141
47
80
13
$112
40
60
12
$92
35
32
26
$30
19
10
1
$ 525
186
274
65
These estimates do not include compliance costs associated with potential regulation of GHG emissions or the proposed ELG Supplemental
Rule. See “Environmental Laws and Regulations – Greenhouse Gases” and “ – Water Quality” herein for additional information.
The Southern Company system also anticipates substantial expenditures associated with ash pond closure and groundwater monitoring
under the CCR Rule and related state rules, which are reflected in the applicable Registrants’ ARO liabilities. See FINANCIAL CONDITION
AND LIQUIDITY – “Cash Requirements” herein and Note 6 to the financial statements for additional information.
34
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Environmental Laws and Regulations
Air Quality
Since 1990, the Southern Company system reduced SO2 and NOX air emissions by 99% and 92%, respectively, through 2022. Since 2005,
the Southern Company system reduced mercury air emissions by 97% through 2022.
On February 13, 2023, the EPA published a final rule disapproving 19 state implementation plans (SIPs), including the States of Alabama
and Mississippi, under the interstate transport (good neighbor) provisions of the Clean Air Act for the 2015 Ozone National Ambient
Air Quality Standards (NAAQS). On March 14, 2023 and March 15, 2023, the State of Mississippi and Mississippi Power, respectively,
challenged the EPA’s disapproval of the Mississippi SIP in the U.S. Court of Appeals for the Fifth Circuit. On June 8, 2023, the U.S. Court
of Appeals for the Fifth Circuit stayed the EPA’s disapproval of the Mississippi SIP, pending appeal. On April 13, 2023 and April 14, 2023,
the State of Alabama, Alabama Power, and PowerSouth Energy Cooperative challenged the EPA’s disapproval of the Alabama SIP in the
U.S. Court of Appeals for the Eleventh Circuit. On August 17, 2023, the U.S. Court of Appeals for the Eleventh Circuit stayed the EPA’s
disapproval of the Alabama SIP, pending appeal.
On June 5, 2023, the EPA published the 2015 Ozone NAAQS Good Neighbor federal implementation plan (FIP), which requires reductions in
NOX emissions from sources in 23 states, including Alabama and Mississippi, to assure those states satisfy their Clean Air Act good neighbor
obligations for the 2015 Ozone NAAQS. Georgia and North Carolina have approved interstate transport SIPs addressing the 2015 Ozone
NAAQS and are not subject to this rule. On June 16, 2023 and June 27, 2023, the State of Mississippi and Mississippi Power, respectively,
challenged the FIP for Mississippi in the U.S. Court of Appeals for the Fifth Circuit. On August 4, 2023, the State of Alabama, Alabama
Power, and PowerSouth Energy Cooperative challenged the FIP for Alabama in the U.S. Court of Appeals for the Eleventh Circuit. Both cases
are being held in abeyance pending resolution of the Mississippi SIP disapproval and Alabama SIP disapproval cases, respectively.
In July and September 2023, the EPA published an Interim Final Rule and an updated Interim Final Rule that stays the implementation of
the FIPs for states with judicially stayed SIP disapprovals, including Mississippi and Alabama, respectively. The Interim Final Rule revises the
existing regulations to maintain currently applicable trading programs for those states.
The ultimate impact of the rule and associated legal matters cannot be determined at this time; however, implementation of the FIPs will
likely result in increased compliance costs for the traditional electric operating companies.
Water Quality
In 2020, the EPA published the final steam electric ELG reconsideration rule (ELG Reconsideration Rule), a reconsideration of the 2015
ELG rule’s limits on bottom ash transport water and flue gas desulfurization wastewater that extended the latest applicability date for
both discharges to December 31, 2025. The ELG Reconsideration Rule also updated the voluntary incentive program and provided new
subcategories for low utilization electric generating units and electric generating units that will permanently cease coal combustion by
2028. On March 29, 2023, the EPA published a proposed ELG Supplemental Rule revising certain effluent limits of the 2020 and 2015
ELG rules. The proposal imposes more stringent requirements for flue gas desulfurization wastewater, bottom ash transport water, and
combustion residual leachate to be met no later than December 31, 2029. The EPA is also proposing that a limited number of facilities
already achieving compliance with the 2020 ELG Reconsideration Rule be allowed to elect retirement or repowering by December 31, 2032
as opposed to meeting the new more stringent requirements. The proposal maintains the 2020 ELG Reconsideration Rule’s permanent
cessation of coal combustion subcategory allowing units to continue to operate until the end of 2028 without having to install additional
technologies. The proposal also maintains the Voluntary Incentive Program (VIP) subcategory, which allows units to comply with VIP limits
by December 31, 2028. A final rule is anticipated in 2024. The ultimate impact of this proposal cannot be determined at this time; however,
it may result in significant compliance costs.
As required by the ELG Reconsideration Rule, in 2021, Alabama Power and Georgia Power each submitted initial notices of planned
participation (NOPP) for applicable units seeking to qualify for these cessation of coal combustion or VIP subcategories that require
compliance by December 31, 2028.
Alabama Power submitted its NOPP to the Alabama Department of Environmental Management (ADEM) indicating plans to retire Plant
Barry Unit 5 (700 MWs) and to cease using coal and begin operating solely on natural gas at Plant Barry Unit 4 (350 MWs) and Plant
Gaston Unit 5 (880 MWs). Alabama Power, as agent for SEGCO, indicated plans to retire Plant Gaston Units 1 through 4 (1,000 MWs).
However, Alabama Power, in conjunction with Georgia Power, is evaluating extending the operation of Plant Gaston Units 1 through 4
beyond the indicated retirement date. The NOPP submittals are subject to the review of the ADEM. Plant Barry Unit 4 ceased using
coal and began to operate solely on natural gas in December 2022. See Notes 2 and 7 to the financial statements under “Georgia
Power – Integrated Resource Plans” and “SEGCO,” respectively, for additional information.
35
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report The remaining assets for which Alabama Power has indicated retirement, due to early closure or repowering of the unit to natural gas,
have net book values totaling approximately $1.2 billion (excluding capitalized asset retirement costs which are recovered through Rate
CNP Compliance) at December 31, 2023. Based on an Alabama PSC order, Alabama Power is authorized to establish a regulatory asset
to record the unrecovered investment costs, including the plant asset balance and the site removal and closure costs, associated with
unit retirements caused by environmental regulations (Environmental Accounting Order). Under the Environmental Accounting Order,
the regulatory asset would be amortized and recovered over an affected unit’s remaining useful life, as established prior to the decision
regarding early retirement, through Rate CNP Compliance. See Note 2 to the financial statements under “Alabama Power – Rate CNP
Compliance” and “ – Environmental Accounting Order” for additional information.
Georgia Power submitted its NOPP to the Georgia Environmental Protection Division (EPD) indicating plans to retire Plant Wansley
Units 1 and 2 (926 MWs based on 53.5% ownership), which occurred in August 2022, Plant Bowen Units 1 and 2 (1,400 MWs), and
Plant Scherer Unit 3 (614 MWs based on 75% ownership) on or before the compliance date of December 31, 2028. Georgia Power also
submitted a NOPP indicating plans to pursue compliance with the ELG Reconsideration Rule for Plant Scherer Units 1 and 2 (137 MWs
based on 8.4% ownership) through the voluntary incentive program by no later than December 31, 2028. Georgia Power intends to comply
with the ELG Rules for Plant Bowen Units 3 and 4 through the generally applicable requirements by December 31, 2025; therefore, no
NOPP submission was required for these units. The NOPP submittals and generally applicable requirements are subject to the review of
the Georgia EPD and decisions related to retirement or continued operation of units are subject to Georgia PSC approval. See Note 2 to the
financial statements under “Georgia Power – Integrated Resource Plans” for additional information.
Coal Combustion Residuals
In 2015, the EPA finalized non-hazardous solid waste regulations for the management and disposal of CCR, including coal ash and gypsum,
in landfills and surface impoundments (ash ponds) at active electric generating power plants. The CCR Rule requires landfills and ash ponds
to be evaluated against a set of performance criteria and potentially closed if certain criteria are not met. Closure of existing landfills and
ash ponds requires installation of equipment and infrastructure to manage CCR in accordance with the CCR Rule. In addition to the federal
CCR Rule, the States of Alabama and Georgia finalized state regulations regarding the management and disposal of CCR within their
respective states. In 2019, the State of Georgia received partial approval from the EPA for its state CCR permitting program, which has
broader applicability than the federal rule. The State of Mississippi has not developed a state CCR permit program.
On August 14, 2023, the EPA published a proposal to deny the ADEM’s CCR permit program application. Alabama Power’s permits to close
its CCR facilities remain valid under state law. In the absence of an EPA-approved state permit program, CCR facilities in Alabama will
remain subject to both the federal and state CCR rules.
The Holistic Approach to Closure: Part A rule, finalized in 2020, revised the deadline to stop sending CCR and non-CCR wastes to unlined
surface impoundments to April 11, 2021 and established a process for the EPA to approve extensions to the deadline. The traditional
electric operating companies stopped sending CCR and non-CCR wastes to their unlined impoundments prior to April 11, 2021 and,
therefore, did not submit requests for extensions. Beginning in January 2022, the EPA issued numerous Part A determinations that state its
current positions on a variety of CCR Rule compliance requirements, such as criteria for groundwater corrective action and CCR unit closure.
The traditional electric operating companies are working with state regulatory agencies to determine whether the EPA’s current positions
may impact closure and groundwater monitoring plans.
In April 2022, the Utilities Solid Waste Activities Group and a group of generating facility operators filed petitions for review in the U.S.
Court of Appeals for the D.C. Circuit challenging whether the EPA’s January 2022 actions establish new legislative rules that should have
gone through notice-and-comment rulemaking. A decision by the court is expected in 2024. The ultimate impacts of the EPA’s current
positions are subject to the outcome of the pending litigation and any potential future rulemaking and cannot be determined at this time.
On May 18, 2023, the EPA published a proposed rule to establish two new categories of federally regulated CCR, legacy surface
impoundments and CCR management units (CCRMUs). The proposal establishes accelerated compliance deadlines for legacy surface
impoundments to meet regulatory requirements, including a requirement to initiate closure within 12 months after the effective date of
the final rule. The EPA is also proposing a definition for CCRMUs. The EPA’s proposal would also require facility evaluations to be completed
at both active facilities and inactive facilities with one or more legacy surface impoundment to determine the presence or absence of
CCRMUs. CCRMUs must comply with the CCR Rule’s provisions for groundwater monitoring, corrective action, closure, and post-closure
activities. On November 14, 2023, the EPA published a Notice of Data Availability supplementing the proposed rule, which sought
comment on new data and a supplemental risk assessment that could be used to support final rulemaking. A final rule is anticipated
in 2024. The ultimate impact of this proposal cannot be determined at this time; however, it may result in significant compliance costs.
Based on requirements for closure and monitoring of landfills and ash ponds pursuant to the CCR Rule and applicable state rules, the
traditional electric operating companies have periodically updated, and expect to continue periodically updating, their related cost
estimates and ARO liabilities for each CCR unit as additional information related to closure methodologies, schedules, and/or costs becomes
36
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report available. Some of these updates have been, and future updates may be, material. Additionally, the closure designs and plans in the States
of Alabama and Georgia are subject to approval by environmental regulatory agencies. Absent continued recovery of ARO costs through
regulated rates, results of operations, cash flows, and financial condition for Southern Company and the traditional electric operating
companies could be materially impacted. See FINANCIAL CONDITION AND LIQUIDITY – “Cash Requirements,” Notes 2 and 3 to the financial
statements under “Georgia Power – Rate Plans” and “General Litigation Matters – Alabama Power,” respectively, and Note 6 to the financial
statements for additional information.
Greenhouse Gases
On May 23, 2023, the EPA published proposed GHG standards and state plan guidelines for fossil fuel-fired power plants, which would
require GHG limits for subcategories of both new and existing units based on technologies such as carbon capture and sequestration,
low-GHG hydrogen co-firing, and natural gas co-firing. The proposed standards for new combustion turbines include subcategories for
different operational uses including peaking, intermediate, and base load. Compliance with new source standards, once finalized, begins
when the unit comes online. The proposed state plan guidelines for existing units include subcategories based on unit type, retirement
date, size, and capacity factor. The EPA is proposing a 24-month state plan submission deadline for the existing unit implementation and
may allow states to implement some limited form of trading and averaging for the state plans. Existing source compliance is proposed
to begin as early as January 1, 2030, depending on the unit type and subcategory. The EPA also proposes to simultaneously repeal the
Affordable Clean Energy rule. On November 17, 2023, the EPA published a final rule updating the regulations governing the processes and
timelines for state and federal plans to implement existing source GHG performance standards. While this rule establishes the general
requirements and timelines for states to follow in implementing the EPA’s emissions guidelines, the pending final rule for GHG emissions
from fossil fuel-fired power plants is expected to include schedules and other implementation requirements that will supersede these
general provisions. On November 20, 2023, the EPA published a Supplemental Notice of Proposed Rulemaking for the pending rules for
fossil fuel-fired power plants requesting additional input on how the EPA should address reliability concerns in the final rules. A final
rule is anticipated in 2024. The ultimate impact of this proposal cannot be determined at this time; however, it may result in significant
compliance costs.
In 2021, the United States officially rejoined the Paris Agreement. The Paris Agreement establishes a non-binding universal framework
for addressing GHG emissions based on nationally determined emissions reduction contributions and sets in place a process for tracking
progress towards the goals every five years. In 2021, President Biden announced a new target for the United States to achieve a 50% to
52% reduction in economy-wide GHG emissions from 2005 levels by 2030. The target was accepted by the United Nations as the United
States’ nationally determined emissions reduction contribution under the Paris Agreement.
Additional GHG policies, including legislation, may emerge in the future requiring the United States to accelerate its transition to a lower
GHG emitting economy; however, associated impacts are currently unknown. The Southern Company system has transitioned from an
electric generating mix of 70% coal and 15% natural gas in 2007 to a mix of 17% coal and 54% natural gas in 2023. This transition has
been supported in part by the Southern Company system retiring over 6,700 MWs of coal-fired generating capacity since 2010 and
converting 3,700 MWs of generating capacity from coal to natural gas since 2015. In addition, the Southern Company system’s capacity
mix consists of over 11,600 MWs of renewable and storage facilities through ownership and long-term PPAs. See “Environmental Laws and
Regulations – Water Quality” herein for information on plans to retire or convert to natural gas additional coal-fired generating capacity.
In addition, Southern Company Gas has replaced over 6,000 miles of pipe material that was more prone to fugitive emissions (unprotected
steel and cast-iron pipe), resulting in mitigation of more than 3.3 million metric tons of CO2 equivalents from its natural gas distribution
system since 1998.
The following table provides the Registrants’ 2022 and preliminary 2023 Scope 1 GHG emissions based on equity share of facilities:
2022
Preliminary 2023
(in million metric tons of CO2 equivalent)
Southern Company(*)
Alabama Power(*)
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas(*)
85
35
23
9
13
2
(*) Includes GHG emissions attributable to disposed assets through the date of the applicable disposition and to acquired assets beginning with the date of
the applicable acquisition. See Note 15 to the financial statements for additional information.
80
28
24
9
13
2
37
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Southern Company system management has established an intermediate goal of a 50% reduction in GHG emissions from 2007 levels by
2030 and a long-term goal of net zero GHG emissions by 2050. Based on the preliminary 2023 emissions, the Southern Company system
has achieved an estimated GHG emission reduction of 49% since 2007. GHG emissions decreased in 2023 when compared to 2022 as
coal generation was displaced by lower carbon generation, including from Plant Vogtle Unit 3, as discussed further under RESULTS OF
OPERATIONS – “Southern Company – Electricity Business” herein. Southern Company system management expects to achieve GHG
reductions of greater than 50% as early as 2025, five years earlier than the established interim goal, and remain close to 50% through the
late 2020s, followed thereafter by continued reductions. While none of Southern Company’s subsidiaries are currently subject to renewable
portfolio standards or similar requirements, management of the traditional electric operating companies is working with applicable
regulators through their IRP processes to continue the generating fleet transition in a manner responsible to customers, communities,
employees, and other stakeholders. Achievement of these goals is dependent on many factors, including natural gas prices and the pace
and extent of development and deployment of low- to no-GHG energy technologies and negative carbon concepts. Southern Company
system management plans to continue to pursue a diverse portfolio including low-carbon and carbon-free resources and energy efficiency
resources; continue to transition the Southern Company system’s generating fleet and make the necessary related investments in
transmission and distribution systems; implement initiatives to reduce natural gas distribution operational emissions; continue its research
and development with a particular focus on technologies that lower GHG emissions, including methods of removing carbon from the
atmosphere; and constructively engage with policymakers, regulators, investors, customers, and other stakeholders to support outcomes
leading to a net zero future.
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 Southern Company Gas conduct studies to determine the
extent of any required cleanup and have recognized the estimated costs to clean up known impacted sites in their financial statements.
Amounts for cleanup and ongoing monitoring costs were not material for any year presented. The traditional electric operating companies
and the natural gas distribution utilities in Illinois and Georgia (which represent substantially all of Southern Company Gas’ accrued
remediation costs) have all received authority from their respective state PSCs or other applicable state regulatory agencies to recover
approved environmental remediation costs through regulatory mechanisms. These regulatory mechanisms are adjusted annually or
as necessary within limits approved by the state PSCs or other applicable state regulatory agencies. The traditional electric operating
companies and Southern Company Gas may be liable for some or all required cleanup costs for additional sites that may require
environmental remediation. See Note 3 to the financial statements under “Environmental Remediation” for additional information.
Regulatory Matters
See OVERVIEW – “Recent Developments” herein and Note 2 to the financial statements for a discussion of regulatory matters related
to Alabama Power, Georgia Power, Mississippi Power, and Southern Company Gas, including items that could impact the applicable
Registrants’ future earnings, cash flows, and/or financial condition.
Alabama Power
On July 14, 2023, Alabama Power issued a request for proposals of between 100 MWs and 1,200 MWs of capacity beginning no later than
December 1, 2028, with consideration for commencement as early as 2025. Any purchases will depend upon the cost competitiveness of
the respective offers, as well as other options available to Alabama Power, and would ultimately require approval by the Alabama PSC.
The ultimate outcome of this matter cannot be determined at this time.
Construction Programs
The Subsidiary Registrants are engaged in continuous construction programs to accommodate existing and estimated future loads on their
respective systems. The Southern Company system strategy continues to include developing and constructing new electric generating
facilities, expanding and improving the electric transmission and electric and natural gas distribution systems, and undertaking projects to
comply with environmental laws and regulations.
For the traditional electric operating companies, major generation construction projects are subject to state PSC approval in order to
be included in retail rates. The largest construction project currently underway in the Southern Company system is Plant Vogtle Unit 4.
See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” for additional information. Also see Note 2 to the
financial statements under “Georgia Power – Integrated Resource Plans” for information regarding Georgia Power’s request with the
Georgia PSC to develop, own, and operate three simple cycle combustion turbines at Plant Yates.
38
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report See Note 15 to the financial statements under “Southern Power” for information relating to Southern Power’s construction of renewable
energy facilities.
Southern Company Gas is engaged in various infrastructure improvement programs designed to update or expand the natural gas
distribution systems of the natural gas distribution utilities to improve reliability and resiliency, reduce emissions, and meet operational
flexibility and growth. The natural gas distribution utilities recover their investment and a return associated with these infrastructure
programs through their regulated rates. See Note 2 to the financial statements under “Southern Company Gas – Infrastructure
Replacement Programs and Capital Projects” for additional information on Southern Company Gas’ construction program.
See FINANCIAL CONDITION AND LIQUIDITY – “Cash Requirements” herein for additional information regarding the Registrants’ capital
requirements for their construction programs, including estimated totals for each of the next five years.
Southern Power’s Power Sales Agreements
General
Southern Power has PPAs with some of the traditional electric operating companies, other investor-owned utilities, IPPs, municipalities, and
other load-serving entities, as well as commercial and industrial customers. The PPAs are expected to provide Southern Power with a stable
source of revenue during their respective terms.
Many of Southern Power’s PPAs have provisions that require Southern Power or the counterparty to post collateral or an acceptable
substitute guarantee if (i) S&P or Moody’s downgrades the credit ratings of the respective company to an unacceptable credit rating,
(ii) the counterparty is not rated, or (iii) the counterparty fails to maintain a minimum coverage ratio. See FINANCIAL CONDITION AND
LIQUIDITY – “Credit Rating Risk” herein for additional information.
Southern Power works to maintain and expand its share of the wholesale market. During 2023, Southern Power continued to be successful
in remarketing up to 438 MWs of annual natural gas generation capacity to load-serving entities through several PPAs extending over the
next 16 years. Market demand is being driven by load-serving entities replacing expired purchase contracts and/or retired generation, as
well as planning for future growth.
Natural Gas
Southern Power’s electricity sales from natural gas facilities are primarily through long-term PPAs that consist of two types of agreements.
The first type, referred to as a unit or block sale, is a customer purchase from a dedicated generating unit where all or a portion of the
generation from that unit is reserved for that customer. Southern Power typically has the ability to serve the unit or block sale customer
from an alternate resource. The second type, referred to as requirements service, provides that Southern Power serve the customer’s
capacity and energy requirements from a combination of the customer’s own generating units and from Southern Power resources not
dedicated to serve unit or block sales. Southern Power has rights to purchase power provided by the requirements customers’ resources
when economically viable.
As a general matter, substantially all of the PPAs 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 or purchased power relating to the energy delivered
under such PPAs. To the extent a particular generating facility does not meet the operational requirements contemplated in the PPAs,
Southern Power may be responsible for excess fuel costs. With respect to fuel transportation risk, most of Southern Power’s PPAs provide
that the counterparties are responsible for the availability of fuel transportation to the particular generating facility.
Capacity charges that form part of the PPA payments are designed to recover fixed and variable operation and maintenance costs based
on dollars-per-kilowatt year. In general, to reduce Southern Power’s exposure to certain operation and maintenance costs, Southern Power
has LTSAs. See Note 1 to the financial statements under “Long-Term Service Agreements” for additional information.
Solar and Wind
Southern Power’s electricity sales from solar and wind generating facilities are also primarily through long-term PPAs; however, these PPAs
do not have a capacity charge and customers either purchase the energy output of a dedicated renewable facility through an energy
charge or provide Southern Power a certain fixed price for the electricity 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. Generally, under the renewable
generation PPAs, the purchasing party retains the right to keep or resell the associated renewable energy credits.
39
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Income Tax Matters
Consolidated Income Taxes
The impact of certain tax events at Southern Company and/or its other subsidiaries can, and does, affect each Registrant’s ability to utilize
certain tax credits. See “Tax Credits” and ACCOUNTING POLICIES – “Application of Critical Accounting Policies and Estimates – Accounting
for Income Taxes” herein and Note 10 to the financial statements for additional information.
Tax Credits
Southern Company has received ITCs and PTCs in connection with investments in solar, wind, fuel cell, advanced nuclear, and battery
energy storage facilities (co-located with existing solar facilities) primarily at Southern Power and Georgia Power.
Southern Power’s ITCs relate to its investment in new solar facilities and battery energy storage facilities (co-located with existing solar
facilities) that are acquired or constructed and its PTCs relate to the first 10 years of energy production from its wind facilities, which
have had, and may continue to have, a material impact on Southern Power’s cash flows and net income. At December 31, 2023, Southern
Company and Southern Power had approximately $0.8 billion and $0.5 billion, respectively, of unutilized federal ITCs and PTCs, which are
currently expected to be fully utilized by 2029, but could be further delayed. Since 2018, Southern Power has been utilizing tax equity
partnerships for wind, solar, and battery energy storage projects, where the tax equity partner takes significantly all of the respective
federal tax benefits. These tax equity partnerships are consolidated in Southern Company’s and Southern Power’s financial statements
using the HLBV methodology to allocate partnership gains and losses.
In the third quarter 2023, Georgia Power started generating advanced nuclear PTCs for Plant Vogtle Unit 3 beginning on the in-service
date of July 31, 2023. PTCs are recognized as an income tax benefit based on KWH production. In addition, pursuant to the Global
Amendments to the Vogtle Joint Ownership Agreements (as defined in Note 2 to the financial statements under “Georgia Power – Nuclear
Construction – Joint Owner Contracts”), Georgia Power is purchasing advanced nuclear PTCs for Plant Vogtle Unit 3 from the other Vogtle
Owners. The gain recognized on the purchase of the joint owner PTCs is recognized as an income tax benefit. See Note 2 to the financial
statements under “Georgia Power – Nuclear Construction” for additional information regarding Plant Vogtle Units 3 and 4.
See Note 1 to the financial statements under “General” for additional information on the HLBV methodology and Note 1 to the financial
statements under “Income Taxes” and Note 10 to the financial statements under “Deferred Tax Assets and Liabilities – Tax Credit
Carryforwards” and “Effective Tax Rate” for additional information regarding utilization and amortization of credits and the tax benefit
related to associated basis differences.
Inflation Reduction Act
In August 2022, the IRA was signed into law. The IRA extends, expands, and increases ITCs and PTCs for clean energy projects, allows PTCs
for solar projects, adds ITCs for stand-alone energy storage projects with an option to elect out of the tax normalization requirement,
and allows for the transferability of the tax credits. The IRA extends and increases the tax credits for carbon capture and sequestration
projects and adds tax credits for clean hydrogen and nuclear projects. Additional ITC and PTC amounts are available if the projects meet
domestic content requirements or are located in low-income or energy communities. The IRA also enacted a 15% corporate minimum tax
on book income, with material adjustments for pension costs and tax depreciation. The 15% corporate minimum tax on book income can
be reduced by energy tax credits.
For solar projects placed in service in 2022 through 2032, the IRA provides for a 30% ITC and an option to claim a PTC instead of an ITC.
Starting in 2023 and through 2032, the IRA provides for a 30% ITC for stand-alone energy storage projects. For wind projects placed
in service in 2022 through 2032, the IRA provides for a 100% PTC, adjusted for inflation annually. For projects placed in service before
2022, the 2023 PTC rate is 2.8 cents per KWH. For projects placed in service in 2022 and later, the 2023 PTC rate is 2.75 cents per KWH.
The same PTC rate applies for solar projects for which the PTC option has been elected. To realize the full value of ITCs and PTCs, the IRA
requires satisfaction of prevailing wage and apprenticeship requirements.
In June 2023, the IRS issued temporary regulations related to the transferability of tax credits. During the fourth quarter 2023, Southern
Power executed an agreement to transfer certain PTCs generated in 2023. The discount recognized was booked through income tax
expense and was immaterial. Southern Company and certain subsidiaries are considering the sale of additional tax credits that are eligible
to be transferred.
Implementation of the IRA provisions is subject to the issuance of additional guidance by the U.S. Treasury Department and the IRS.
The Registrants are still evaluating the impacts and the ultimate outcome of this matter cannot be determined at this time.
40
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Natural Gas Safe Harbor Method
In April 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor tax method of accounting that taxpayers may use
to determine whether certain expenditures to maintain, repair, replace, or improve natural gas transmission and distribution property must
be capitalized or allowed as repair deductions. The revenue procedure allows multiple alternatives for implementation which will result
in a tax accounting method change for Southern Company Gas’ eligible expenditures. Due to the complexity of analysis needed and the
various implementation options allowed under the revenue procedure, Southern Company and Southern Company Gas are still evaluating
the impacts and the ultimate outcome of this matter cannot be determined at this time. See Note 10 to the financial statements under
“Deferred Tax Assets and Liabilities – Tax Credit Carryforwards” for additional information.
General Litigation and Other Matters
The Registrants are involved in various matters being litigated and/or regulatory and other matters that could affect future earnings, cash
flows, and/or financial condition. The ultimate outcome of such pending or potential litigation against each Registrant and any subsidiaries
or regulatory and other matters cannot be determined at this time; however, for current proceedings and/or matters not specifically
reported herein or in Notes 2 and 3 to the financial statements, management does not anticipate that the ultimate liabilities, if any, arising
from such current proceedings and/or matters would have a material effect on such Registrant’s financial statements. See Notes 2 and 3 to
the financial statements for a discussion of various contingencies, including matters being litigated, regulatory matters, and other matters
which may affect future earnings potential.
ACCOUNTING POLICIES
Application of Critical Accounting Policies and Estimates
The Registrants prepare their financial statements in accordance with GAAP, which requires the use of estimates, judgments, and
assumptions. Significant accounting policies are described in the notes to the financial statements. Detailed further herein are certain
estimates made in the application of these policies that may have a material impact on the results of operations, financial condition, and
related disclosures of the applicable Registrants (as indicated in the section descriptions herein). Different assumptions and measurements
could produce estimates that are significantly different from those recorded in the financial statements. Senior management has reviewed
and discussed these critical accounting policies and estimates with the Audit Committee of Southern Company’s Board of Directors.
The following critical accounting policies and estimates include only those that are applicable to Southern Company.
Utility Regulation (Southern Company, Alabama Power, Georgia Power, Mississippi Power, and Southern Company Gas)
The traditional electric operating companies and the natural gas distribution utilities are subject to retail regulation by their respective
state PSCs or other applicable state regulatory agencies and wholesale regulation by the FERC. These regulatory agencies set the rates the
traditional electric operating companies and the natural gas distribution utilities are permitted to charge customers based on allowable
costs, including a reasonable ROE. As a result, the traditional electric operating companies and the natural gas distribution utilities apply
accounting standards which require the financial statements to reflect the effects of rate regulation. Through the ratemaking process, the
regulators may require the inclusion of costs or revenues in periods different than when they would be recognized by a non-regulated
company. This treatment may result in the deferral of expenses and the recording of related regulatory assets based on anticipated future
recovery through rates or the deferral of gains or creation of liabilities and the recording of related regulatory liabilities. The application of
the accounting standards for rate regulated entities also impacts their financial statements as a result of the estimates of allowable costs
used in the ratemaking process. These estimates may differ from those actually incurred by the traditional electric operating companies
and the natural gas distribution utilities; therefore, the accounting estimates inherent in specific costs such as depreciation, AROs, and
pension and other postretirement benefits have less of a direct impact on the results of operations and financial condition of the applicable
Registrants than they would on a non-regulated company. Additionally, a regulatory agency may disallow recovery of all or a portion of
certain assets. See Note 2 to the financial statements under “Southern Company Gas – Infrastructure Replacement Programs and Capital
Projects – Nicor Gas” for information regarding the disallowance of certain capital investments at Nicor Gas and “Estimated Cost, Schedule,
and Rate Recovery for the Construction of Plant Vogtle Units 3 and 4” herein for information regarding the Prudency Stipulation related to
Georgia Power’s construction of Plant Vogtle Units 3 and 4.
Revenues related to regulated utility operations as a percentage of total operating revenues in 2023 for the applicable Registrants
were as follows: 89% for Southern Company, 98% for Alabama Power, 96% for Georgia Power, 99% for Mississippi Power, and 87% for
Southern Company Gas.
As reflected in Note 2 to the financial statements, significant regulatory assets and liabilities have been recorded. Management reviews the
ultimate recoverability of these regulatory assets and any requirement to refund these regulatory liabilities based on applicable regulatory
guidelines and GAAP. However, adverse legislative, judicial, or regulatory actions could materially impact the amounts of such regulatory
assets and liabilities and could adversely impact the financial statements of the applicable Registrants.
41
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Estimated Cost, Schedule, and Rate Recovery for the Construction of Plant Vogtle Units 3 and 4
(Southern Company and Georgia Power)
In 2016, the Georgia PSC approved a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in
connection with Georgia Power’s fifteenth VCM report. In January 2018, the Georgia PSC issued an order approving Georgia Power’s
seventeenth VCM report, which included a modification of the Vogtle Cost Settlement Agreement. The January 2018 order and the
modified Vogtle Cost Settlement Agreement resolved certain regulatory matters related to Plant Vogtle Units 3 and 4 including, but not
limited to: (i) Georgia Power’s total project capital cost forecast of $7.3 billion (net of $1.7 billion received under the Guarantee Settlement
Agreement and approximately $188 million in related customer refunds) was found reasonable and (ii) a prudence proceeding on cost
recovery would occur subsequent to achieving fuel load for Unit 4. On December 19, 2023, the Georgia PSC voted to approve Georgia
Power’s Application as modified by the Prudency Stipulation. Under the terms of the approved Prudency Stipulation, Georgia Power will
recover $7.562 billion in total construction and capital costs and associated retail rate base items of $1.02 billion, which includes AFUDC
financing costs above $4.418 billion (the Georgia PSC-certified amount) up to $7.562 billion. The approval of the Application and the
Prudency Stipulation resolves all issues for determination by the Georgia PSC regarding the reasonableness, prudence, and cost recovery
for the remaining Plant Vogtle Units 3 and 4 construction and capital costs not already in retail base rates.
As of December 31, 2023, Georgia Power revised its total project capital cost forecast to $10.8 billion (net of $1.7 billion received under
the Guarantee Settlement Agreement and approximately $188 million in related customer refunds). This forecast includes construction
contingency of $36 million and is based on the actual in-service date of July 2023 for Unit 3 and a projected in-service date during the
second quarter 2024 for Unit 4. Since 2018, established construction contingency and additional costs totaling $2.7 billion have been
assigned to the base capital cost forecast. Georgia Power did not seek rate recovery for the $0.7 billion increase to the base capital cost
forecast included in the nineteenth VCM report and charged to income by Georgia Power in the second quarter 2018 and, until the
prudency proceeding described above, did not seek rate recovery for subsequent construction and additional contingency costs assigned
to the base capital cost forecast. After considering the significant level of uncertainty that existed regarding the future recoverability of
these costs since the ultimate outcome of these matters was subject to the outcome of assessments by management, as well as Georgia
PSC decisions in the related regulatory proceedings, Georgia Power recorded total pre-tax charges to income of $1.1 billion ($0.8 billion
after tax) in 2018; $149 million ($111 million after tax) and $176 million ($131 million after tax) in the second quarter and the fourth
quarter 2020, respectively; $48 million ($36 million after tax), $460 million ($343 million after tax), $264 million ($197 million after tax),
and $480 million ($358 million after tax) in the first quarter 2021, the second quarter 2021, the third quarter 2021, and the fourth quarter
2021, respectively; and $36 million ($27 million after tax), $32 million ($24 million after tax), and $148 million ($110 million after tax)
in the second quarter 2022, the third quarter 2022, and the fourth quarter 2022, respectively. As a result of the Georgia PSC’s approval
of the Prudency Stipulation, Georgia Power recorded a pre-tax credit to income of approximately $228 million ($170 million after tax) in
the fourth quarter 2023 to recognize CWIP costs previously charged to income, which are now recoverable through retail rates. Associated
AFUDC on these costs was also recognized.
In September 2022, Georgia Power and MEAG Power reached an agreement to resolve a dispute regarding the cost-sharing and tender
provisions of the Global Amendments (as defined in Note 2 to the financial statements under “Georgia Power – Nuclear Construction –
Joint Owner Contracts”). Under the terms of the agreement, among other items, (i) MEAG Power will not exercise its tender option
and will retain its full ownership interest in Plant Vogtle Units 3 and 4; (ii) Georgia Power will reimburse a portion of MEAG Power’s
costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs,
which payments will total approximately $92 million based on the current project capital cost forecast; and (iii) Georgia Power will
reimburse 20% of MEAG Power’s costs of construction with respect to any amounts over the current project capital cost forecast,
with no further adjustment for force majeure costs.
On October 5, 2023 and October 17, 2023, Georgia Power reached agreements with OPC and Dalton, respectively, to resolve its respective
dispute with each of OPC and Dalton regarding the cost-sharing and tender provisions of the Global Amendments. Under the terms of the
agreements with OPC and Dalton, among other items, (i) each of OPC and Dalton retracted its exercise of the tender option and will retain
its full ownership interest in Plant Vogtle Units 3 and 4, (ii) Georgia Power made payments immediately after execution of the agreements
of $308 million and $17 million to OPC and Dalton, respectively, representing payment for a portion of each of OPC’s and Dalton’s costs of
construction for Plant Vogtle Units 3 and 4 previously incurred, (iii) Georgia Power will pay a portion of each of OPC’s and Dalton’s further
costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs,
which payments will be in an aggregate amount of approximately $105 million and $6 million for OPC and Dalton, respectively, based
on the current project capital cost forecast, and (iv) Georgia Power will pay 66% of each of OPC’s and Dalton’s costs of construction with
respect to any amounts above the current project capital cost forecast, with no further adjustment for force majeure costs.
42
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Georgia Power recorded pre-tax charges to income through the fourth quarter 2022 of $407 million ($304 million after tax) associated
with the cost-sharing provisions of the Global Amendments, including the settlement with MEAG Power. Based on the current project
capital cost forecast and the settlements with OPC and Dalton described above, Georgia Power recorded a pre-tax charge to income of
approximately $160 million ($120 million after tax) in the third quarter 2023. These charges are included in the total project capital cost
forecast and will not be recovered from retail customers.
As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts for Unit 4 on a regular basis to
incorporate current information available, particularly in the areas of start-up testing and related test results and engineering support.
The projected schedule for Unit 4 significantly depends on the progression of start-up and pre-operational testing, which may be impacted
by equipment or other operational failures. Any further delays could result in a later in-service date and cost increases.
Various design and other licensing-based compliance matters may result in additional license amendment requests 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 Unit 4 project schedule that could result in increased costs.
The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond June 2024
for Unit 4, including the current level of cost sharing described in Note 2, is estimated to result in additional base capital costs for Georgia
Power of up to $25 million per month as well as any additional related construction, support resources, or testing costs. Pursuant to the
Prudency Stipulation, any further changes to the capital cost forecast will not be recoverable through regulated rates and will be required to
be charged to income, and such charges could be material.
Given the significant complexity involved in estimating the future costs to complete construction and start-up of Plant Vogtle Unit 4, as well
as the potential impact on results of operations and cash flows, Southern Company and Georgia Power consider these items to be critical
accounting estimates. See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” for additional information.
Accounting for Income Taxes (Southern Company, Georgia Power, Mississippi Power, Southern Power, and
Southern Company Gas)
The consolidated income tax provision and deferred income tax assets and liabilities, as well as any unrecognized tax benefits and
valuation allowances, require significant judgment and estimates. These estimates are supported by historical tax return data, reasonable
projections of taxable income, the ability and intent to implement tax planning strategies if necessary, and interpretations of applicable
tax laws and regulations across multiple taxing jurisdictions. The effective tax rate reflects the statutory tax rates and calculated
apportionments for the various states in which the Southern Company system operates.
Southern Company files a consolidated federal income tax return and the Registrants file various state income tax returns, some of which
are combined or unitary. Under a joint consolidated income tax allocation agreement, each Southern Company subsidiary’s current and
deferred tax expense is computed on a stand-alone basis and each subsidiary is allocated an amount of tax similar to that which would be
paid if it filed a separate income tax return. In accordance with IRS regulations, each company is jointly and severally liable for the federal
tax liability. Certain deductions and credits can be limited or utilized at the consolidated or combined level resulting in tax credit and/or
state NOL carryforwards that would not otherwise result on a stand-alone basis. Utilization of these carryforwards and the assessment of
valuation allowances are based on significant judgment and extensive analysis of Southern Company’s and its subsidiaries’ current financial
position and results of operations, including currently available information about future years, to estimate when future taxable income
will be realized. See Note 10 to the financial statements under “Deferred Tax Assets and Liabilities – Tax Credit Carryforwards” and “ –
Net Operating Loss Carryforwards” for additional information.
Current and deferred state income tax liabilities and assets are estimated based on laws of multiple states that determine the income to
be apportioned to their jurisdictions. States have various filing methodologies and utilize specific formulas to calculate the apportionment
of taxable income. The calculation of deferred state taxes considers apportionment factors and filing methodologies that are expected
to apply in future years. Any apportionments and/or filing methodologies ultimately finalized in a manner inconsistent with expectations
could have a material effect on the financial statements of the applicable Registrants.
Asset Retirement Obligations (Southern Company, Alabama Power, Georgia Power, Mississippi Power, and Southern Company Gas)
Estimating AROs requires significant judgment. AROs are computed as the present value of the estimated costs for an asset’s future
retirement and are recorded in the period in which the liability is incurred. The estimated costs are capitalized as part of the related
long-lived asset and depreciated over the asset’s useful life. In the absence of quoted market prices, AROs are estimated using present
value techniques in which estimates of future cash outlays associated with the asset retirements are discounted using a credit-adjusted
risk-free rate. Estimates of the timing and amounts of future cash outlays are based on projections of when and how the assets will be
retired and the cost of future removal activities.
43
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report The ARO liabilities for the traditional electric operating companies primarily relate to facilities that are subject to the CCR Rule and the
related state rules, principally ash ponds. In addition, Alabama Power and Georgia Power have retirement obligations related to the
decommissioning of nuclear facilities (Alabama Power’s Plant Farley and Georgia Power’s ownership interests in Plant Hatch and Plant
Vogtle Units 1 through 3). Other significant AROs include various landfill sites and asbestos removal for Alabama Power, Georgia Power,
and Mississippi Power and gypsum cells and mine reclamation for Mississippi Power.
The traditional electric operating companies and Southern Company Gas also have identified other retirement obligations, such as
obligations related to certain electric transmission and distribution facilities, certain asbestos-containing material within long-term assets
not subject to ongoing repair and maintenance activities, certain wireless communication towers, the disposal of polychlorinated biphenyls
in certain transformers, leasehold improvements, equipment on customer property, and property associated with the Southern Company
system’s rail lines and natural gas pipelines. However, liabilities for the removal of these assets have not been recorded because the
settlement timing for certain retirement obligations related to these assets is indeterminable and, therefore, the fair value of the retirement
obligations cannot be reasonably estimated. A liability for these retirement obligations will be recognized when sufficient information
becomes available to support a reasonable estimation of the ARO.
The cost estimates for AROs related to the disposal of CCR are based on information using various assumptions related to closure and
post-closure costs, timing of future cash outlays, inflation and discount rates, and the potential methods for complying with the CCR Rule
and the related state rules. The traditional electric operating companies have periodically updated, and expect to continue periodically
updating, their related cost estimates and ARO liabilities for each CCR unit as additional information related to these assumptions
becomes available. Some of these updates have been, and future updates may be, material. The cost estimates for Alabama Power are
based on closure-in-place for all ash ponds. The cost estimates for Georgia Power and Mississippi Power are based on a combination of
closure-in-place for some ash ponds and closure by removal for others. Additionally, the closure designs and plans in the States of Alabama
and Georgia are subject to approval by environmental regulatory agencies. See Note 6 to the financial statements and FUTURE EARNINGS
POTENTIAL – “Environmental Matters – Environmental Laws and Regulations – Coal Combustion Residuals” herein for additional
information, including updates to AROs related to ash ponds recorded during 2023 by certain Registrants.
Pension and Other Postretirement Benefits (Southern Company, Alabama Power, Georgia Power, Mississippi Power, and
Southern Company Gas)
The applicable Registrants’ calculations of pension and other postretirement benefits expense are dependent on a number of assumptions.
These assumptions include discount rates, healthcare cost trend rates, expected long-term rate of return (LRR) on plan assets, mortality
rates, expected salary and wage increases, and other factors. Components of pension and other postretirement benefits expense include
interest and service cost on the pension and other postretirement benefit plans, expected return on plan assets, and amortization of certain
unrecognized costs and obligations. Actual results that differ from the assumptions utilized are accumulated and amortized over future
periods and, therefore, generally affect recognized expense and the recorded obligation in future periods. While the applicable Registrants
believe the assumptions used are appropriate, differences in actual experience or significant changes in assumptions would affect their
pension and other postretirement benefit costs and obligations.
Key elements in determining the applicable Registrants’ pension and other postretirement benefit expense are the LRR and the discount
rate used to measure the benefit plan obligations and the periodic benefit plan expense for future periods. For purposes of determining
the applicable Registrants’ liabilities related to the pension and other postretirement benefit plans, Southern Company discounts the future
related cash flows using a single-point discount rate for each plan developed from the weighted average of market-observed yields for
high quality fixed income securities with maturities that correspond to expected benefit payments. The discount rate assumption impacts
both the service cost and non-service costs components of net periodic benefit costs as well as the projected benefit obligations.
The LRR on pension and other postretirement benefit plan assets is based on Southern Company’s investment strategy, as described
in Note 11 to the financial statements, historical experience, and expectations that consider external actuarial advice, and represents
the average rate of earnings expected over the long term on the assets invested to provide for anticipated future benefit payments.
Southern Company determines the amount of the expected return on plan assets component of non-service costs by applying the LRR of
various asset classes to Southern Company’s target asset allocation. The LRR only impacts the non-service costs component of net periodic
benefit costs for the following year and is set annually at the beginning of the year.
44
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report The following table illustrates the sensitivity to changes in the applicable Registrants’ long-term assumptions with respect to the discount
rate, salary increases, and the long-term rate of return on plan assets:
25 Basis Point Change in:
Discount rate:
Southern Company
Alabama Power
Georgia Power
Mississippi Power
Southern Company Gas
Salaries:
Southern Company
Alabama Power
Georgia Power
Mississippi Power
Southern Company Gas
Long-term return on plan assets:
Southern Company
Alabama Power
Georgia Power
Mississippi Power
Southern Company Gas
Total Benefit
Expense for 2024
Increase/(Decrease) in
Projected Obligation
for Pension Plan at
December 31, 2023
(in millions)
Projected Obligation for
Other Postretirement
Benefit Plans at
December 31, 2023
$35/$(32)
$9/$(9)
$9/$(9)
$2/$(1)
$2/$(2)
$18/$(17)
$5/(5)
$5/(5)
$1/$(1)
$1/$(1)
$41/$(41)
$10/$(10)
$13/$(13)
$2/$(2)
$3/$(3)
$419/$(397)
$101/$(96)
$122/$(116)
$18/$(18)
$27/$(25)
$87/$(84)
$24/$(23)
$23/$(23)
$4/$(4)
$3/$(3)
N/A
N/A
N/A
N/A
N/A
$34/$(32)
$9/$(8)
$11/$(11)
$1/$(1)
$4/$(4)
$–/$–
$–/$–
$–/$–
$–/$–
$–/$–
N/A
N/A
N/A
N/A
N/A
See Note 11 to the financial statements for additional information regarding pension and other postretirement benefits.
Impairment (Southern Company, Southern Power, and Southern Company Gas)
Goodwill (Southern Company and Southern Company Gas)
The acquisition method of accounting for business combinations requires the assets acquired and liabilities assumed to be recorded at
the date of acquisition at their respective estimated fair values. The applicable Registrants have recognized goodwill as of the date of
their acquisitions, as a residual over the fair values of the identifiable net assets acquired. Goodwill is recorded at the reporting unit level,
which is the operating segment or a business one level below the operating segment (a component), if discrete financial information is
prepared and regularly reviewed by management. Components are aggregated if they have similar economic characteristics. Goodwill is
tested for impairment at the reporting unit level on an annual basis in the fourth quarter of the year and on an interim basis if events and
circumstances occur that indicate goodwill may be impaired.
Goodwill is evaluated for impairment either under the qualitative assessment option or the quantitative option to determine the fair value
of the reporting unit. If goodwill is determined to be impaired, an impairment loss measured at the amount by which the reporting unit’s
carrying amount exceeds its fair value, not to exceed the carrying amount of goodwill, is recorded.
Goodwill for Southern Company and Southern Company Gas was $5.2 billion and $5.0 billion, respectively, at December 31, 2023.
During 2022, Southern Company recorded a $119 million impairment loss as a result of its annual goodwill impairment test for PowerSecure.
The judgments made in determining the estimated fair value assigned to each class of assets acquired and liabilities assumed, as well as
asset lives, can significantly impact the applicable Registrant’s results of operations. Fair values and useful lives are determined based on,
among other factors, the expected future period of benefit of the asset, the various characteristics of the asset, and projected cash flows.
As the determination of an asset’s fair value and useful life involves management making certain estimates and because these estimates
form the basis for the determination of whether or not an impairment charge should be recorded, the applicable Registrants consider these
estimates to be critical accounting estimates.
See Note 1 to the financial statements under “Goodwill and Other Intangible Assets” for additional information regarding the applicable
Registrants’ goodwill.
45
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Long-Lived Assets (Southern Company, Southern Power, and Southern Company Gas)
The applicable Registrants assess their other long-lived assets for impairment whenever events or changes in circumstances indicate that
an asset’s carrying amount may not be recoverable. If an impairment indicator exists, the asset is tested for recoverability by comparing
the asset carrying amount to the sum of the undiscounted expected future cash flows directly attributable to the asset’s use and
eventual disposition. If the estimate of undiscounted future cash flows is less than the carrying amount of the asset, the fair value of the
asset is determined and a loss is recorded equal to the difference between the carrying amount and the fair value of the asset. In addition,
when assets are identified as held for sale, an impairment loss is recognized to the extent the carrying amount of the assets or asset group
exceeds their fair value less cost to sell. A high degree of judgment is required in developing estimates related to these evaluations, which
are based on projections of various factors, some of which have been quite volatile in recent years.
Southern Power’s investments in long-lived assets are primarily generation assets. Excluding the natural gas distribution utilities, Southern
Company Gas’ investments in long-lived assets are primarily natural gas transportation assets.
For Southern Power, examples of impairment indicators could include, but are not limited to, significant changes in construction schedules,
current period losses combined with a history of losses or a projection of continuing losses, a significant decrease in market prices, changes
in tax legislation, the inability to remarket generating capacity for an extended period, the unplanned termination of a customer contract,
or the inability of a customer to perform under the terms of the contract. For Southern Company Gas, examples of impairment indicators
could include, but are not limited to, significant changes in the U.S. natural gas storage market, construction schedules, current period
losses combined with a history of losses or a projection of continuing losses, a significant decrease in market prices, the inability to renew
or extend customer contracts or the inability of a customer to perform under the terms of the contract, attrition rates, or the inability to
deploy a development project.
As the determination of the expected future cash flows generated from an asset, an asset’s fair value, and useful life involves management
making certain estimates and because these estimates form the basis for the determination of whether or not an impairment charge
should be recorded, the applicable Registrants consider these estimates to be critical accounting estimates.
During 2021, Southern Company recorded impairment charges totaling $7 million ($6 million after tax) related to its leveraged
lease investments. During 2022, Southern Company Gas recorded pre-tax impairment charges totaling $131 million ($99 million
after tax) related to natural gas storage facilities. During 2021, Southern Company Gas recorded total pre-tax impairment charges of
$84 million ($67 million after tax) related to its equity method investment in the PennEast Pipeline project. See Notes 7 and 9 to the
financial statements under “Southern Company Gas” and “Southern Company Leveraged Lease,” respectively, and Note 15 to the financial
statements for additional information on recent asset impairments.
Contingent Obligations (All Registrants)
The Registrants are subject to a number of federal and state laws and regulations, as well as other factors and conditions that subject them
to environmental, litigation, and other risks. See FUTURE EARNINGS POTENTIAL herein and Notes 2 and 3 to the financial statements for
more information regarding certain of these contingencies. The Registrants periodically evaluate their exposure to such risks and record
reserves for those matters where a non-tax-related loss is considered probable and reasonably estimable. The adequacy of reserves can
be significantly affected by external events or conditions that can be unpredictable; thus, the ultimate outcome of such matters could
materially affect the results of operations, cash flows, or financial condition of the Registrants.
Recently Issued Accounting Standards
See Note 1 to the financial statements under “Recently Adopted Accounting Standards” for additional information.
46
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report FINANCIAL CONDITION AND LIQUIDITY
Overview
The financial condition of each Registrant remained stable at December 31, 2023. The Registrants’ cash requirements primarily consist
of funding ongoing operations, including unconsolidated subsidiaries, as well as common stock dividends, capital expenditures, and debt
maturities. Southern Power’s cash requirements also include distributions to noncontrolling interests. Capital expenditures and other
investing activities for the traditional electric operating companies include investments to build new generation facilities to meet projected
long-term demand requirements and to replace units being retired as part of the generation fleet transition, 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.
Southern Power’s capital expenditures and other investing activities may include acquisitions or new construction associated with its
overall growth strategy and to maintain its existing generation fleet’s performance. Southern Company Gas’ capital expenditures and other
investing activities include investments to meet projected long-term demand requirements, to maintain existing natural gas distribution
systems as well as to update and expand these systems, and to comply with environmental regulations. See “Cash Requirements” herein
for additional information.
Operating cash flows provide a substantial portion of the Registrants’ cash needs. During 2023, Southern Power utilized tax credits, which
provided $332 million in operating cash flows. For the three-year period from 2024 through 2026, projected stock dividends, capital
expenditures, and debt maturities are expected to exceed operating cash flows for each of Southern Company, the traditional electric
operating companies, and Southern Company Gas. Southern Company plans to finance future cash needs in excess of its operating cash
flows through one or more of the following: accessing borrowings from financial institutions, issuing debt and hybrid securities in the
capital markets, and/or through its stock plans. Each Subsidiary Registrant plans to finance its future cash needs in excess of its operating
cash flows primarily through external securities issuances, borrowings from financial institutions, and equity contributions from Southern
Company. In addition, Southern Power may utilize tax equity partnership contributions. The Registrants plan to use commercial paper to
manage seasonal variations in operating cash flows and for other working capital needs and continue to monitor their access to short-term
and long-term capital markets as well as their bank credit arrangements to meet future capital and liquidity needs. See “Sources of Capital”
and “Financing Activities” herein for additional information.
The Registrants’ investments in their qualified pension plans and Alabama Power’s and Georgia Power’s investments in their nuclear
decommissioning trust funds increased in value at December 31, 2023 as compared to December 31, 2022. No contributions to the
qualified pension plan were made during 2023 and no mandatory contributions to the qualified pension plans are anticipated during 2024.
See Notes 6 and 11 to the financial statements under “Nuclear Decommissioning” and “Pension Plans,” respectively, for
additional information.
At the end of 2023, the market price of Southern Company’s common stock was $70.12 per share (based on the closing price as reported
on the NYSE) and the book value was $28.83 per share, representing a market-to-book value ratio of 243%, compared to $71.41, $27.93,
and 256%, respectively, at the end of 2022.
47
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Cash Requirements
Capital Expenditures
Total estimated capital expenditures, including LTSA and nuclear fuel commitments, for the Registrants through 2028 based on their current
construction programs are as follows:
Southern Company(a)(b)
Alabama Power
Georgia Power(a)
Mississippi Power
Southern Power(b)
Southern Company Gas
2024
2025
2026
(in billions)
2027
2028
$10.0
2.1
5.4
0.3
0.3
1.8
$9.4
2.0
5.0
0.3
0.2
1.8
$8.5
1.9
4.4
0.2
0.1
1.7
$8.6
2.0
4.5
0.3
0.1
1.7
$8.7
1.9
4.7
0.3
0.1
1.7
(a) Includes expenditures of approximately $0.2 billion in 2024 for the construction of Plant Vogtle Unit 4. See Note 2 to the financial statements under
"Georgia Power – Nuclear Construction" for additional information. Also includes certain expenditures related to the construction of Plant Yates
Units 8 through 10 as requested in Georgia Power's 2023 IRP Update filing, which is subject to the approval of the Georgia PSC. See Note 2 to the
financial statements under "Georgia Power – Integrated Resource Plans" for additional information.
(b) Includes $0.1 billion in both 2024 and 2025 related to the South Cheyenne and Millers Branch solar projects. Excludes approximately $0.8 billion annually
for Southern Power's planned acquisitions and placeholder growth, which may vary materially due to market opportunities and Southern Power's ability
to execute its growth strategy. Also excludes estimated capital expenditures associated with the phase two expansion of the Millers Branch solar project,
which was committed to subsequent to December 31, 2023. See Note 15 to the financial statements under "Southern Power" for additional information
regarding the South Cheyenne and Millers Branch solar projects.
These capital expenditures include estimates to comply with environmental laws and regulations, but do not include compliance costs
associated with potential regulation of GHG emissions or the proposed ELG Supplemental Rule. See FUTURE EARNINGS POTENTIAL –
“Environmental Matters” herein for additional information. At December 31, 2023, significant purchase commitments were outstanding in
connection with the Registrants’ construction programs.
The traditional electric operating companies also anticipate continued expenditures associated with closure and monitoring of ash ponds
and landfills in accordance with the CCR Rule and the related state rules, which are reflected in the applicable Registrants’ ARO liabilities.
The cost estimates for Alabama Power are based on closure-in-place for all ash ponds. The cost estimates for Georgia Power and Mississippi
Power are based on a combination of closure-in-place for some ash ponds and closure by removal for others. These estimated costs
are likely to change, and could change materially, as assumptions and details pertaining to closure are refined and compliance activities
continue. Current estimates of these costs through 2028 are provided in the table below. Material expenditures in future years for ARO
settlements will also be required for ash ponds, nuclear decommissioning (for Alabama Power and Georgia Power), and other liabilities
reflected in the applicable Registrants’ AROs, as discussed further in Note 6 to the financial statements. Also see FUTURE EARNINGS
POTENTIAL – “Environmental Matters – Environmental Laws and Regulations – Coal Combustion Residuals” herein.
Southern Company
Alabama Power
Georgia Power
Mississippi Power
2024
2025
2026
2027
2028
$728
346
338
24
(in millions)
$762
299
429
17
$767
364
347
30
$725
237
450
2
$669
216
450
2
The construction programs are subject to periodic review and revision, and actual construction costs may vary from these estimates because
of numerous factors. These factors include: changes in business conditions; changes in load projections; changes in environmental laws and
regulations; the outcome of any legal challenges to environmental rules; changes in electric generating plants, including unit retirements and
replacements and adding or changing fuel sources at existing electric generating units, to meet regulatory requirements; changes in FERC
rules and regulations; state regulatory agency approvals; changes in the expected environmental compliance program; changes in legislation
and/or regulation; the cost, availability, and efficiency of construction labor, equipment, and materials; project scope and design changes;
abnormal weather; delays in construction due to judicial or regulatory action; storm impacts; and the cost of capital. In addition, there can be
no assurance that costs related to capital expenditures and AROs will be fully recovered. Additionally, expenditures associated with Southern
Power’s planned acquisitions may vary due to market opportunities and the execution of its growth strategy. See Note 15 to the financial
statements under “Southern Power” for additional information regarding Southern Power’s plant acquisitions and construction projects.
48
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report The construction program of Georgia Power includes Plant Vogtle Unit 4, which includes components based on new technology that only
within the last several years began initial operation in the global nuclear industry at this scale and which may be subject to additional
revised cost estimates during construction. See Note 2 to the financial statements under “Georgia Power – Nuclear Construction” for
information regarding Plant Vogtle Unit 4 and additional factors that may impact construction expenditures.
See FUTURE EARNINGS POTENTIAL – “Construction Programs” herein for additional information.
Other Significant Cash Requirements
Long-term debt maturities and the interest payable on long-term debt each represent a significant cash requirement for the Registrants.
See Note 8 to the financial statements for information regarding the Registrants’ long-term debt at December 31, 2023, the weighted
average interest rate applicable to each long-term debt category, and a schedule of long-term debt maturities over the next five years.
The Registrants plan to continue, when economically feasible, to retire higher-cost securities and replace these obligations with lower-cost
capital if market conditions permit.
Fuel and purchased power costs represent a significant component of funding ongoing operations for the traditional electric operating
companies and Southern Power. See Note 3 to the financial statements under “Commitments” for information on Southern Company Gas’
commitments for pipeline charges, storage capacity, and gas supply. Total estimated costs for fuel and purchased power commitments at
December 31, 2023 for the applicable Registrants are provided in the table below. Fuel costs include purchases of coal (for the traditional
electric operating companies) and natural gas (for the traditional electric operating companies and Southern Power), as well as the related
transportation and storage. In most cases, these contracts contain provisions for price escalation, minimum purchase levels, and other
financial commitments. Natural gas purchase commitments are based on various indices at the time of delivery; the amounts reflected
below have been estimated based on the NYMEX future prices at December 31, 2023. As discussed under “Capital Expenditures” herein,
estimated expenditures for nuclear fuel are included in the applicable Registrants’ construction programs for the years 2024 through 2028.
Nuclear fuel commitments at December 31, 2023 that extend beyond 2028 are included in the table below. Purchased power costs
represent estimated minimum obligations for various PPAs for the purchase of capacity and energy, except for those accounted for as
leases, which are discussed in Note 9 to the financial statements.
Southern Company(*)
Alabama Power
Georgia Power(*)
Mississippi Power
Southern Power
2024
2025
2026
2027
2028
Thereafter
$3,347
1,210
1,262
377
558
$3,151
1,181
1,111
420
502
(in millions)
$2,201
819
696
338
414
$1,738
619
579
263
346
$1,171
328
471
213
232
$4,820
1,136
2,008
1,002
674
(*) Excludes capacity payments related to Plant Vogtle Units 1 and 2, which are discussed in Note 3 to the financial statements under "Commitments."
In connection with Georgia Power’s 2022 IRP, the Georgia PSC approved five affiliate PPAs with Southern Power, which are expected to
be accounted for as leases, and are contingent upon approval by the FERC. The expected capacity payments associated with the PPAs
total $5 million in 2024, $68 million in 2025, $75 million in 2026, $76 million in 2027, $86 million in 2028, and $584 million thereafter.
In connection with Georgia Power’s 2023 IRP Update, Georgia Power has requested certification of a non-affiliate PPA, which is expected
to be accounted for as a lease and is contingent upon approval by the Georgia PSC. The expected capacity payments associated with
the PPA are $10 million in 2024, $17 million in 2025, $18 million in 2026, $19 million in 2027, and $19 million in 2028. See Note 2 to the
financial statements under “Georgia Power – Integrated Resource Plans” for additional information.
The traditional electric operating companies and Southern Power have entered into LTSAs for the purpose of securing maintenance
support for certain of their generating facilities. See Note 1 to the financial statements under “Long-term Service Agreements” for
additional information. As discussed under “Capital Expenditures” herein, estimated expenditures related to LTSAs are included in the
applicable Registrants’ construction programs for the years 2024 through 2028. Total estimated payments for LTSA commitments at
December 31, 2023 that extend beyond 2028 are provided in the following table and include price escalation based on inflation indices:
49
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
LTSA commitments (after 2028)
$1,594
$262
$252
$152
$928
In addition, Southern Power has certain other operations and maintenance agreements. Total estimated costs for these commitments at
December 31, 2023 are provided in the table below.
Southern Power’s operations and maintenance agreements
$74
$45
$33
$30
$30
$226
2024
2025
2026
2027
2028
Thereafter
(in millions)
See Note 9 to the financial statements for information on the Registrants’ operating lease obligations, including a maturity analysis of the
lease liabilities over the next five years and thereafter.
Sources of Capital
Southern Company intends to meet its future capital needs through operating cash flows, borrowings from financial institutions, and
debt, hybrid, and/or equity issuances. Equity capital can be provided from any combination of Southern Company’s stock plans, private
placements, or public offerings.
The Subsidiary Registrants plan to obtain the funds to meet their future capital needs from sources similar to those they used in the
past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity
contributions from Southern Company. Operating cash flows provide a substantial portion of the Registrants’ cash needs. Georgia Power
intends to utilize a mix of senior note issuances, short-term floating rate bank loans, and commercial paper issuances to continue funding
operating cash flows related to fuel cost under recovery.
The amount, type, and timing of any financings in 2024, as well as in subsequent years, will be contingent on investment opportunities
and the Registrants’ capital requirements and will depend upon prevailing market conditions, regulatory approvals (for certain of the
Subsidiary Registrants), and other factors. See “Cash Requirements” herein for additional information.
Southern Power utilizes tax equity partnerships as one of its financing sources, where the tax partner takes significantly all of the federal
tax benefits. These tax equity partnerships are consolidated in Southern Power’s financial statements and are accounted for using HLBV
methodology to allocate partnership gains and losses. During 2023, Southern Power obtained tax equity funding for existing tax equity
partnerships totaling $21 million. See Notes 1 and 15 to the financial statements under “General” and “Southern Power,” respectively, for
additional information.
The issuance of securities by the traditional electric operating companies and Nicor Gas is generally subject to the approval of the
applicable state PSC or other applicable state regulatory agency. The issuance of all securities by Mississippi Power and short-term securities
by Georgia Power is generally subject to regulatory approval by the FERC. Additionally, with respect to the public offering of securities,
Southern Company, the traditional electric operating companies, and Southern Power (excluding its subsidiaries), Southern Company Gas
Capital, and Southern Company Gas (excluding its other subsidiaries) file registration statements with the SEC under the Securities Act
of 1933, as amended (1933 Act). The amounts of securities authorized by the appropriate regulatory authorities, as well as the securities
registered under the 1933 Act, are closely monitored and appropriate filings are made to ensure flexibility in the capital markets.
The Registrants generally obtain financing separately without credit support from any affiliate. See Note 8 to the financial statements
under “Bank Credit Arrangements” for additional information. The Southern Company system does not maintain a centralized cash or
money pool. Therefore, funds of each company are not commingled with funds of any other company in the Southern Company system,
except in the case of Southern Company Gas, as described below.
The traditional electric operating companies and SEGCO may utilize a Southern Company subsidiary organized to issue and sell commercial
paper at their request and for their benefit. Proceeds from such issuances for the benefit of an individual company are loaned directly to
that company. The obligations of each traditional electric operating company and SEGCO under these arrangements are several and there is
no cross-affiliate credit support. Alabama Power also maintains its own separate commercial paper program.
Southern Company Gas Capital obtains external financing for Southern Company Gas and its subsidiaries, other than Nicor Gas, which
obtains financing separately without credit support from any affiliates. Southern Company Gas maintains commercial paper programs at
Southern Company Gas Capital and Nicor Gas. Nicor Gas’ commercial paper program supports its working capital needs as Nicor Gas is not
permitted to make money pool loans to affiliates. All of the other Southern Company Gas subsidiaries benefit from Southern Company Gas
Capital’s commercial paper program.
50
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report By regulation, Nicor Gas is restricted, up to its retained earnings balance, in the amount it can dividend or loan to affiliates and is not
permitted to make money pool loans to affiliates. At December 31, 2023, the amount of subsidiary retained earnings restricted to dividend
totaled $1.7 billion. This restriction did not impact Southern Company Gas’ ability to meet its cash obligations, nor does management
expect such restriction to materially impact Southern Company Gas’ ability to meet its currently anticipated cash obligations.
Certain Registrants’ current liabilities frequently exceed their current assets because of long-term debt maturities and the periodic use of
short-term debt as a funding source, as well as significant seasonal fluctuations in cash needs. The Registrants generally plan to refinance
long-term debt as it matures. See Note 8 to the financial statements for additional information. Also see “Financing Activities” herein for
information on financing activities that occurred subsequent to December 31, 2023. The following table shows the amount by which
current liabilities exceeded current assets at December 31, 2023 for the applicable Registrants:
At December 31, 2023
Southern
Company
Georgia
Power
Mississippi
Power
Southern
Company Gas
(in millions)
Current liabilities in excess of current assets
$3,035
$1,674
$314
$222
The Registrants believe the need for working capital can be adequately met by utilizing operating cash flows, as well as commercial paper,
lines of credit, and short-term bank notes, as market conditions permit. In addition, under certain circumstances, the Subsidiary Registrants
may utilize equity contributions and/or loans from Southern Company.
Bank Credit Arrangements
At December 31, 2023, the Registrants’ unused committed credit arrangements with banks were as follows:
At December 31, 2023
Southern
Company
parent
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power(a)
(in millions)
Southern
Company
Gas(b)
SEGCO
Southern
Company
Unused committed credit
$1,998
$1,350
$1,726
$275
$589
$1,598
$30
$7,566
(a) At December 31, 2023, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $15 million was unused.
Southern Power’s subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.
(b) Includes $798 million and $800 million at Southern Company Gas Capital and Nicor Gas, respectively.
Subject to applicable market conditions, the Registrants, Nicor Gas, and SEGCO expect to renew or replace their bank credit arrangements
as needed, prior to expiration. In connection therewith, the Registrants, Nicor Gas, and SEGCO may extend the maturity dates and/or
increase or decrease the lending commitments thereunder.
A portion of the unused credit with banks is allocated to provide liquidity support to certain revenue bonds of the traditional electric
operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. At December 31, 2023, outstanding
variable rate demand revenue bonds of the traditional electric operating companies with allocated liquidity support totaled approximately
$1.7 billion (comprised of approximately $818 million at Alabama Power, $819 million at Georgia Power, and $69 million at Mississippi
Power). In addition, at December 31, 2023, Georgia Power had approximately $325 million of fixed rate revenue bonds outstanding that
are required to be remarketed within the next 12 months. The variable rate demand revenue bonds and fixed rate revenue bonds required
to be remarketed within the next 12 months are classified as long-term debt on the balance sheets as a result of available long-term
committed credit.
See Note 8 to the financial statements under “Bank Credit Arrangements” for additional information.
51
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Short-term Borrowings
The Registrants, Nicor Gas, and SEGCO make short-term borrowings primarily through commercial paper programs that have the liquidity
support of the committed bank credit arrangements described above. Southern Power’s subsidiaries are not issuers or obligors under its
commercial paper program. Commercial paper and short-term bank term loans are included in notes payable in the balance sheets. Details
of the Registrants’ short-term borrowings were as follows:
Southern Company
Alabama Power
Georgia Power
Southern Power
Southern Company Gas:
Southern Company Gas Capital
Nicor Gas
Southern Company Gas Total
Average Amount
Outstanding
2023
2022
(in millions)
Short-term Debt at the End of the Period
Amount
Outstanding
December 31,
2023
2022
(in millions)
Weighted Average
Interest Rate
December 31,
2021
2023
2022
2021
$2,314
40
1,329
138
$
23
392
$ 415
$2,609
—
1,600
225
$ 1,440
—
—
211
$ 285
483
$ 768
$ 379
830
$ 1,209
5.7%
5.5
5.9
5.5
5.5%
5.5
5.5%
4.9%
—
5.0
4.7
4.8%
4.7
4.7%
0.4%
—
—
0.3
0.3%
0.4
0.4%
Short-term Debt During the Period(*)
Weighted Average
Interest Rate
Maximum Amount
Outstanding
2021
2023
2022
2021
2023
2022
2021
Southern Company
Alabama Power
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas:
Southern Company Gas Capital
Nicor Gas
Southern Company Gas Total
$2,191
44
1,440
56
158
$ 163
88
$ 251
$1,995
6
673
8
166
$ 279
349
$ 628
$1,141
27
95
15
133
$ 206
420
$ 626
5.6%
5.0
5.8
5.5
5.6
5.3%
5.1
5.2%
2.2%
2.1
3.1
1.6
2.3
1.8%
2.1
2.0%
0.3% $ 3,270
230
0.1
2,260
0.2
169
0.2
359
0.2
0.2% $ 440
483
0.4
0.4%
(in millions)
$ 2,894
200
1,710
71
350
$ 1,809
200
407
81
520
$ 547
830
$ 485
897
(*) Average and maximum amounts are based upon daily balances during the 12-month periods ended December 31, 2023, 2022, and 2021.
52
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Analysis of Cash Flows
Net cash flows provided from (used for) operating, investing, and financing activities in 2023 and 2022 are presented in the following table:
Net cash provided from (used for):
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
2023
Operating activities
Investing activities
Financing activities
2022
Operating activities
Investing activities
Financing activities
$ 7,553
(9,668)
999
$ 6,302
(8,430)
2,336
$ 2,079
(2,196)
(161)
$ 1,639
(2,263)
251
$ 2,752
(5,079)
1,922
$ 2,038
(3,954)
2,363
$ 369
(370)
(20)
$ 383
(317)
(68)
$1,096
(265)
(820)
$ 815
(194)
(623)
$ 1,762
(1,656)
(154)
$ 1,519
(1,580)
96
Fluctuations in cash flows from financing activities vary from year to year based on capital needs and the maturity or redemption of securities.
Southern Company
Net cash provided from operating activities increased $1.3 billion in 2023 as compared to 2022 primarily due to increased fuel cost
recovery and the timing of customer receivable collections, partially offset by the timing of vendor payments.
The net cash used for investing activities in 2023 and 2022 was primarily related to the Subsidiary Registrants’ construction programs.
The net cash provided from financing activities in 2023 was primarily related to net issuances of long-term debt and an increase in
commercial paper borrowings, partially offset by common stock dividend payments and net repayments of short-term bank loans. The net
cash provided from financing activities in 2022 was primarily related to net issuances of long-term debt, the issuance of common stock
to settle the purchase contracts entered into as part of the Equity Units (as discussed in Note 8 to the financial statements under “Equity
Units”), and an increase in short-term borrowings, partially offset by common stock dividend payments.
Significant Balance Sheet Changes
Southern Company
Significant balance sheet changes in 2023 for Southern Company included:
O an increase of $5.3 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants’ construction programs;
O an increase of $4.7 billion in long-term debt (including securities due within one year) related to new issuances;
O a decrease of $1.2 billion in cash and cash equivalents, as discussed further under “Analysis of Cash Flows – Southern Company” herein;
O an increase of $1.0 billion in total common stockholders’ equity primarily related to net income, partially offset by common stock
dividend payments;
O an increase of $1.0 billion in accumulated deferred income taxes primarily related to an increase in property-related timing differences
and the expected utilization of ITCs;
O a decrease of $0.6 billion in accounts payable primarily related to the timing of vendor payments;
O a decrease of $0.6 billion in deferred credits related to income taxes primarily due to the flowback of excess deferred income taxes; and
O a decrease of $0.5 billion in AROs primarily due to cost estimate updates at Georgia Power for ash pond closures.
See “Financing Activities” herein and Notes 2, 5, 6, 8, and 10 to the financial statements for additional information.
53
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Financing Activities
The following table outlines the Registrants’ long-term debt financing activities for the year ended December 31, 2023:
Company
Southern Company parent
Alabama Power
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas
Other
Elimination(b)
Southern Company
Issuances and Reofferings
Maturities and Redemptions
Senior
Notes
Revenue
Bonds
Other Long-
Term Debt
Senior
Notes
Revenue
Bonds
Other Long-
Term Debt(a)
$4,525
500
2,450
100
—
500
—
—
$8,075
$ —
326
229
—
—
—
—
—
$555
(in millions)
$ —
29
—
—
—
312
—
—
$341
$1,850
300
800
—
290
350
—
—
$3,590
$ —
—
—
—
—
—
—
—
$ —
$550
2
102
1
—
50
8
(9)
$704
(a) Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization
payments totaling $86 million for FFB borrowings. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" for
additional information.
(b) Represents reductions in affiliate finance lease obligations at Georgia Power, which are eliminated in Southern Company's consolidated financial statements.
Except as otherwise described herein, the Registrants used the proceeds of debt issuances for their redemptions and maturities shown
in the table above, to repay short-term indebtedness, and for general corporate purposes, including working capital. The Subsidiary
Registrants also used the proceeds for their construction programs.
In addition to any financings that may be necessary to meet capital requirements and contractual obligations, the Registrants plan to
continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if
market conditions permit.
Southern Company
During 2023, Southern Company issued approximately 2.1 million shares of common stock primarily through equity compensation plans
and received proceeds of approximately $36 million.
In January 2023, Southern Company redeemed all $550 million aggregate principal amount of its Series 2016B Junior Subordinated Notes
due March 15, 2057.
In February 2023, Southern Company issued $1.5 billion aggregate principal amount of its Series 2023A 3.875% Convertible Senior Notes
due December 15, 2025 (Series 2023A Convertible Senior Notes) in a private offering. In March 2023, Southern Company issued an
additional $225 million aggregate principal amount of the Series 2023A Convertible Senior Notes upon the exercise by the initial purchasers
of their over-allotment option. See Note 8 to the financial statements under “Convertible Senior Notes” for additional information.
In May 2023, Southern Company repaid at maturity $600 million aggregate principal amount of its 2021C Floating Rate Senior Notes.
Also in May 2023, Southern Company issued $750 million aggregate principal amount of Series 2023B 4.85% Senior Notes due June 15,
2028 and $750 million aggregate principal amount of Series 2023C 5.20% Senior Notes due June 15, 2033.
In July 2023, Southern Company repaid at maturity $1.25 billion aggregate principal amount of its 2.95% Senior Notes.
In September 2023, Southern Company issued $600 million aggregate principal amount of Series 2023D 5.50% Senior Notes due March 15,
2029 and $700 million aggregate principal amount of Series 2023E 5.70% Senior Notes due March 15, 2034.
54
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Alabama Power
During 2023, a subsidiary of Alabama Power borrowed $20 million under a $39 million long-term floating rate bank loan entered into in
December 2022 with a maturity date of December 12, 2029.
In May 2023, Alabama Power issued $200 million aggregate principal amount of Series 2023A Floating Rate Senior Notes due May 15, 2073.
In August 2023, the Walker County Economic and Industrial Development Authority issued for the benefit of Alabama Power $228
million aggregate principal amount of Solid Waste Disposal Revenue Bonds (Alabama Power Company Plant Gorgas Project), First Series
2023 ($140 million aggregate principal amount) and Second Series 2023 ($88 million aggregate principal amount) due August 1, 2063.
The proceeds from the revenue bonds are being used to finance certain solid waste disposal facilities at Plant Gorgas.
Also in August 2023, the Industrial Development Board of the Town of West Jefferson issued for the benefit of Alabama Power $98 million
aggregate principal amount of Solid Waste Disposal Revenue Bonds (Alabama Power Company Plant Miller Project), Series 2023 due
August 1, 2063. The proceeds from the revenue bonds are being used to finance certain solid waste disposal facilities at Plant Miller.
In September 2023, a subsidiary of Alabama Power assumed two fixed rate bank loans totaling $9 million, which it repaid in December
2023 using approximately $9 million of borrowings under a new $20 million fixed rate bank loan maturing December 2030.
In November 2023, Alabama Power issued $300 million aggregate principal amount of Series 2023B 5.85% Senior Notes due November 15, 2033.
In December 2023, Alabama Power repaid at maturity $300 million aggregate principal amount of its Series 2013A 3.55% Senior Notes.
Subsequent to December 31, 2023, Alabama Power received a capital contribution of $425 million from Southern Company and also repaid
at maturity approximately $21 million aggregate principal amount of Industrial Development Board of the Town of Wilsonville (Alabama)
Pollution Control Revenue Bonds (Alabama Power Company Gaston Plant Project), Series D.
Georgia Power
In March 2023, Georgia Power reoffered to the public the following pollution control revenue bonds that previously had been purchased
and were held by Georgia Power at December 31, 2022:
O approximately $28 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue
Bonds (Georgia Power Company Plant Scherer Project), Second Series 2006;
O approximately $89 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue
Bonds (Georgia Power Company Plant Scherer Project), Second Series 2009;
O approximately $49 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue
Bonds (Georgia Power Company Plant Scherer Project), First Series 2012;
O approximately $18 million aggregate principal amount of Development Authority of Monroe County (Georgia) Pollution Control Revenue
Bonds (Georgia Power Company Plant Scherer Project), First Series 2013; and
O $46 million aggregate principal amount of Development Authority of Burke County (Georgia) Pollution Control Revenue Bonds (Georgia
Power Company Plant Vogtle Project), First Series 1996.
Also in March 2023, Georgia Power borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest
at a mutually agreed upon rate and payable on demand. In April 2023, Georgia Power borrowed an additional $150 million under the
arrangement. In May 2023, Georgia Power repaid the aggregate $250 million outstanding.
Also in March 2023, Georgia Power repaid at maturity a $200 million short-term floating rate bank loan entered into in March 2022.
In April 2023, Georgia Power repaid at maturity $100 million aggregate principal amount of its Series N 5.750% Senior Notes.
Also in April 2023, Georgia Power repaid at maturity a $200 million short-term floating rate bank loan entered into in April 2022.
In May 2023, Georgia Power issued $750 million aggregate principal amount of Series 2023A 4.65% Senior Notes due May 16, 2028 and
$1.0 billion aggregate principal amount of Series 2023B 4.95% Senior Notes due May 17, 2033.
In July 2023, Georgia Power repaid at maturity $700 million aggregate principal amount of its Series 2020A 2.10% Senior Notes.
In November 2023, Georgia Power issued $700 million aggregate principal amount of Series 2023C Floating Rate Senior Notes due May 8, 2025.
Also in November 2023, Georgia Power repaid $780 million of a $1.2 billion short-term floating rate bank loan entered into in
November 2022 and extended the maturity of the remaining outstanding amount of $420 million to November 2024.
In December 2023 and subsequent to December 31, 2023, Georgia Power borrowed $100 million and $150 million, respectively, pursuant
to a short-term uncommitted bank credit arrangement bearing interest at a mutually agreed upon rate and payable on demand.
55
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Mississippi Power
In March 2023, Mississippi Power borrowed $50 million of short-term debt pursuant to its $125 million revolving credit arrangement,
which it repaid in June 2023.
In June 2023, Mississippi Power issued in a private placement $65 million aggregate principal amount of Series 2023A 5.64% Senior Notes
due July 15, 2026 and $35 million aggregate principal amount of Series 2023B 5.63% Senior Notes due July 15, 2033.
Southern Power
In January 2023, Southern Power borrowed $100 million pursuant to a short-term uncommitted bank credit arrangement bearing interest
at a mutually agreed upon rate and payable on demand. During the second quarter 2023, Southern Power made net repayments of
$50 million of the $100 million borrowed. In October 2023, Southern Power borrowed the remaining $50 million under the arrangement.
In December 2023, Southern Power repaid the $100 million outstanding amount.
In September 2023, Southern Power repaid at maturity $290 million aggregate principal amount of its Series 2016C 2.75% Senior Notes.
Southern Company Gas
In February 2023, Nicor Gas repaid its $150 million and $50 million short-term floating rate bank loans entered into in February 2022 and
March 2022, respectively.
In July 2023, Nicor Gas issued in a private placement $50 million aggregate principal amount of 5.28% Series First Mortgage Bonds due
July 31, 2030 and $75 million aggregate principal amount of 5.43% Series First Mortgage Bonds due July 31, 2035. In October 2023,
pursuant to the same agreement, Nicor Gas issued in a private placement $75 million aggregate principal amount of 5.67% Series
First Mortgage Bonds due October 31, 2053 and $75 million aggregate principal amount of 5.77% Series First Mortgage Bonds due
October 31, 2063.
In September 2023, Southern Company Gas Capital issued $500 million aggregate principal amount of Series 2023A 5.75% Senior Notes
due September 15, 2033, guaranteed by Southern Company Gas.
In October 2023, Southern Company Gas Capital repaid at maturity $350 million aggregate principal amount of its 2.450% Senior Notes.
In December 2023, Nicor Gas repaid at maturity $50 million aggregate principal amount of its 5.80% Series First Mortgage Bonds.
During 2023, Southern Company Gas received cash advances totaling $37 million under a long-term financing agreement related to a
construction contract.
Credit Rating Risk
At December 31, 2023, the Registrants did not have any credit arrangements that would require material changes in payment schedules or
terminations as a result of a credit rating downgrade.
There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change of certain
Registrants to BBB and/or Baa2 or below. These contracts are primarily for physical electricity and natural gas purchases and sales, fuel
purchases, fuel transportation and storage, energy price risk management, transmission, interest rate management, and, for Georgia Power,
services at Plant Vogtle Units 3 and 4.
The maximum potential collateral requirements under these contracts at December 31, 2023 were as follows:
Credit Ratings
At BBB and/or Baa2
At BBB- and/or Baa3
At BB+ and/or Ba1 or below
Southern
Company(*)
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power(*)
Southern
Company Gas
(in millions)
$
33
407
2,074
$
1
2
404
$ —
60
943
$ —
1
319
$
32
345
1,289
$ —
—
19
(*) Southern Power has PPAs that could require collateral, but not accelerated payment, in the event of a downgrade of Southern Power’s credit. The PPAs
require credit assurances without stating a specific credit rating. The amount of collateral required would depend upon actual losses resulting from a credit
downgrade. Southern Power had $106 million of cash collateral posted related to PPA requirements at December 31, 2023.
56
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report The amounts in the previous table for the traditional electric operating companies and Southern Power include certain agreements that
could require collateral if either Alabama Power or Georgia Power has a credit rating change to below investment grade. Generally, collateral
may be provided by a Southern Company guaranty, letter of credit, or cash. Additionally, a credit rating downgrade could impact the ability
of the Registrants to access capital markets and would be likely to impact the cost at which they do so.
Mississippi Power and its largest retail customer, Chevron Products Company (Chevron), have agreements under which Mississippi Power
provides retail service to the Chevron refinery in Pascagoula, Mississippi through at least 2038. The agreements grant Chevron a security
interest in the co-generation assets owned by Mississippi Power located at the refinery that is exercisable upon the occurrence of (i) certain
bankruptcy events or (ii) other events of default coupled with specific reductions in steam output at the facility and a downgrade of
Mississippi Power’s credit rating to below investment grade by two of the three rating agencies.
On August 2, 2023, S&P revised its credit rating outlook for Southern Company and its subsidiaries to positive from stable.
On September 1, 2023, Fitch upgraded the senior unsecured long-term debt rating of Georgia Power to A- from BBB+ and revised the
rating outlook to positive from stable.
Also on September 1, 2023, Fitch revised the ratings outlook of Southern Company, Alabama Power, Southern Power, Nicor Gas, and SEGCO
to stable from negative.
On September 26, 2023, Moody’s upgraded Mississippi Power’s senior unsecured long-term debt rating to A3 from Baa1 and revised its
rating outlook to stable from positive.
Also on September 26, 2023, Moody’s revised its ratings outlooks for Southern Company and Georgia Power to positive from stable.
Market Price Risk
The Registrants had no material change in market risk exposure for the year ended December 31, 2023 when compared to the year ended
December 31, 2022. See Note 14 to the financial statements for an in-depth discussion of the Registrants’ derivatives, as well as Note 1 to
the financial statements under “Financial Instruments” for additional information.
Due to cost-based rate regulation and other various cost recovery mechanisms, the traditional electric operating companies and the
natural gas distribution utilities that sell natural gas directly to end-use customers continue to have limited exposure to market volatility in
interest rates, foreign currency exchange rates, commodity fuel prices, and prices of electricity. The traditional electric operating companies
and certain of the natural gas distribution utilities manage fuel-hedging programs implemented per the guidelines of their respective
state PSCs or other applicable state regulatory agencies to hedge the impact of market fluctuations in natural gas prices for customers.
Mississippi Power also manages wholesale fuel-hedging programs under agreements with its wholesale customers. Because energy from
Southern Power’s facilities is primarily sold under long-term PPAs with tolling agreements and provisions shifting substantially all of the
responsibility for fuel cost to the counterparties, Southern Power’s exposure to market volatility in commodity fuel prices and prices of
electricity is generally limited. However, Southern Power has been and may continue to be exposed to market volatility in energy-related
commodity prices as a result of uncontracted generating capacity. To mitigate residual risks relative to movements in electricity prices, the
traditional electric operating companies and Southern Power may enter into physical fixed-price contracts for the purchase and sale of
electricity through the wholesale electricity market and, to a lesser extent, financial hedge contracts for natural gas purchases; however, a
significant portion of contracts are priced at market.
Certain of Southern Company Gas’ non-regulated operations routinely utilize various types of derivative instruments to economically
hedge certain commodity price and weather risks inherent in the natural gas industry. These instruments include a variety of
exchange-traded and OTC energy contracts, such as forward contracts, futures contracts, options contracts, and swap agreements.
Southern Company Gas’ gas marketing services business also actively manages storage positions through a variety of hedging transactions
for the purpose of managing exposures arising from changing natural gas prices. These hedging instruments are used to substantially
protect economic margins (as spreads between wholesale and retail natural gas prices widen between periods) and thereby minimize
exposure to declining earnings. Some of these economic hedge activities may not qualify, or may not be designated, for hedge
accounting treatment.
57
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report The following table provides information related to variable interest rate exposure on long-term debt (including amounts due within
one year) at December 31, 2023 for the applicable Registrants:
At December 31, 2023
Long-term variable interest rate exposure
Weighted average interest rate on long-term variable interest
Southern
Company(*)
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Company Gas
$5,290
$ 1,083
$ 1,939
$ 269
$500
(in millions, except percentages)
rate exposure
5.87%
4.75%
5.48%
5.39%
5.85%
Impact on annualized interest expense of 100 basis point
change in interest rates
$
53
$
11
$
19
$
3
$
5
(*) Includes $1.4 billion of long-term variable interest rate exposure at the Southern Company parent entity.
The Registrants may enter into interest rate derivatives designated as hedges, which are intended to mitigate interest rate volatility related
to forecasted debt financings and existing fixed and floating rate obligations. See Note 14 to the financial statements under “Interest Rate
Derivatives” for additional information.
Southern Company and Southern Power had foreign currency denominated debt at December 31, 2023 and have each mitigated exposure
to foreign currency exchange rate risk through the use of foreign currency swaps. See Note 14 to the financial statements under “Foreign
Currency Derivatives” for additional information.
Changes in fair value of energy-related derivative contracts for Southern Company and Southern Company Gas for the years ended
December 31, 2023 and 2022 are provided in the table below. At December 31, 2023 and 2022, substantially all of the traditional electric
operating companies’ and certain of the natural gas distribution utilities’ energy-related derivative contracts were designated as regulatory
hedges and were related to the applicable company’s fuel-hedging program.
Contracts outstanding at December 31, 2021, assets (liabilities), net
Contracts realized or settled
Current period changes(b)
Contracts outstanding at December 31, 2022, assets (liabilities), net
Contracts realized or settled
Current period changes(b)
Contracts outstanding at December 31, 2023, assets (liabilities), net
Southern
Company(a)
Southern
Company Gas(a)
(in millions)
$ 174
(327)
142
$ (11)
207
(500)
$ (304)
$
8
10
(55)
$ (37)
33
(45)
$ (49)
(a) Excludes cash collateral held on deposit in broker margin accounts of $62 million, $41 million, and $3 million at December 31, 2023, 2022, and 2021,
respectively, and immaterial premium and intrinsic value associated with weather derivatives for all periods presented.
(b) The changes in fair value of energy-related derivative contracts are substantially attributable to both the volume and the price of natural gas.
Current period changes also include the changes in fair value of new contracts entered into during the period, if any.
The net hedge volumes of energy-related derivative contracts for natural gas purchased (sold) at December 31, 2023 and 2022 for
Southern Company and Southern Company Gas were as follows:
At December 31, 2023:
Commodity – Natural gas swaps
Commodity – Natural gas options
Total hedge volume
At December 31, 2022:
Commodity – Natural gas swaps
Commodity – Natural gas options
Total hedge volume
58
Southern
Company
Southern
Company Gas
mmBtu Volume (in millions)
109
339
448
217
214
431
—
102
102
—
93
93
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Southern Company Gas’ derivative contracts are comprised of 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. The volumes presented above for Southern Company Gas represent
the net of long natural gas positions of 112 million mmBtu and short natural gas positions of 10 million mmBtu at December 31, 2023 and
the net of long natural gas positions of 98 million mmBtu and short natural gas positions of 5 million mmBtu at December 31, 2022.
For the Southern Company system, the weighted average swap contract cost per mmBtu was approximately $0.76 per mmBtu below market
prices at December 31, 2023 and was approximately $0.08 per mmBtu above market prices at December 31, 2022. The change in option
fair value is primarily attributable to the volatility of the market and the underlying change in the natural gas price. Substantially all of the
traditional electric operating companies’ natural gas hedge gains and losses are recovered through their respective fuel cost recovery clauses.
The Registrants use over-the-counter contracts that are not exchange traded but are fair valued using prices which are market observable, and
thus fall into Level 2 of the fair value hierarchy. In addition, Southern Company Gas uses exchange-traded market-observable contracts, which
are categorized as Level 1. See Note 13 to the financial statements for further discussion of fair value measurements. The maturities of the
energy-related derivative contracts for Southern Company and Southern Company Gas at December 31, 2023 were as follows:
Southern Company
Level 1(a)
Level 2(b)
Southern Company total(c)
Southern Company Gas
Level 1(a)
Level 2(b)
Southern Company Gas total(c)
Total
Fair Value
$ (40)
(264)
$ (304)
$ (40)
(9)
$ (49)
Fair Value Measurements of Contracts at
December 31, 2023
Maturity
2024
2025 – 2026
2027 – 2028
Thereafter
(in millions)
$ (36)
(180)
$ (216)
$ (36)
(8)
$ (44)
$ (4)
(87)
$(91)
$ (4)
(1)
$ (5)
$—
1
$ 1
$—
—
$—
$—
2
$ 2
$—
—
$—
(a) Valued using NYMEX futures prices.
(b) Level 2 amounts for Southern Company Gas are 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) Excludes cash collateral of $62 million as well as immaterial premium and associated intrinsic value associated with weather derivatives.
The Registrants are exposed to risk in the event of nonperformance by counterparties to energy-related and interest rate derivative
contracts, as applicable. 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.
Therefore, the Registrants do not anticipate market risk exposure from nonperformance by the counterparties. For additional information,
see Note 1 to the financial statements under “Financial Instruments” and Note 14 to the financial statements.
Credit Risk
Except as discussed herein, the Southern Company system is not exposed to any concentrations of credit risk.
Concentration of credit risk occurs at Atlanta Gas Light for amounts billed for services and other costs to its customers, which consist of the
13 Marketers in Georgia. For 2023, the four largest Marketers based on customer count, which includes SouthStar, accounted for 18% of
Southern Company Gas’ operating revenues.
59
Management’s Discussion and Analysis of Financial Condition and Results of OperationsSouthern Company 2023 Annual Report Consolidated Statements of Income
For the Years Ended December 31, 2023, 2022, and 2021
Operating Revenues:
Retail electric revenues
Wholesale electric revenues
Other electric revenues
Natural gas revenues
Other revenues
Total operating revenues
Operating Expenses:
Fuel
Purchased power
Cost of natural gas
Cost of other sales
Other operations and maintenance
Depreciation and amortization
Taxes other than income taxes
Estimated loss on Plant Vogtle Units 3 and 4
Impairment charges
Total operating expenses
Operating Income
Other Income and (Expense):
Allowance for equity funds used during construction
Earnings from equity method investments
Interest expense, net of amounts capitalized
Other income (expense), net
Total other income and (expense)
Earnings Before Income Taxes
Income taxes
Consolidated Net Income
Dividends on preferred stock of subsidiaries
Net loss attributable to noncontrolling interests
Consolidated Net Income Attributable to Southern Company
Common Stock Data:
Earnings per share —
Basic
Diluted
Average number of shares of common stock outstanding — (in millions)
Basic
Diluted
The accompanying notes are an integral part of these consolidated financial statements.
2023
2022
(in millions)
2021
$16,343
2,467
792
4,702
949
25,253
4,365
883
1,644
560
6,093
4,525
1,425
(68)
—
19,427
5,826
268
144
(2,446)
553
(1,481)
4,345
496
3,849
—
(127)
$ 3,976
$18,197
3,641
747
5,962
732
29,279
6,835
1,593
3,004
396
6,573
3,663
1,411
183
251
23,909
5,370
224
151
(2,022)
500
(1,147)
4,223
795
3,428
11
(107)
$ 3,524
$14,852
2,455
718
4,380
708
23,113
4,010
978
1,619
357
5,902
3,565
1,290
1,692
2
19,415
3,698
190
76
(1,837)
449
(1,122)
2,576
267
2,309
15
(99)
$ 2,393
$
3.64
3.62
$
3.28
3.26
$
2.26
2.24
1,092
1,098
1,075
1,081
1,061
1,068
60
Southern Company 2023 Annual Report Consolidated Statements of Comprehensive Income
For the Years Ended December 31, 2023, 2022, and 2021
Consolidated Net Income
Other comprehensive income (loss):
Qualifying hedges:
Changes in fair value, net of tax of $(17), $(19), and $(16), respectively
Reclassification adjustment for amounts included in net income,
net of tax of $27, $23, and $31, respectively
Pension and other postretirement benefit plans:
Benefit plan net gain (loss), net of tax of $(14), $18, and $37, respectively
Reclassification adjustment for amounts included in net income,
net of tax of $—, $3, and $5, respectively
Total other comprehensive income (loss)
Dividends on preferred stock of subsidiaries
Comprehensive loss attributable to noncontrolling interests
Consolidated Comprehensive Income Attributable to Southern Company
The accompanying notes are an integral part of these consolidated financial statements.
2023
2022
(in millions)
2021
$3,849
$3,428
$2,309
(41)
(60)
(49)
69
(39)
73
48
96
98
1
(10)
—
(127)
$3,966
10
71
11
(107)
$3,595
13
158
15
(99)
$2,551
61
Southern Company 2023 Annual Report 2023
2022
2021
(in millions)
$ 3,849
$ 3,428
$ 2,309
4,986
63
353
(268)
(527)
(617)
124
137
(68)
—
(206)
—
(138)
482
686
(368)
(345)
108
(106)
(863)
(157)
214
214
7,553
(9,095)
(1,142)
1,121
164
(592)
18
(99)
(43)
(9,668)
4,064
670
88
(224)
(436)
(455)
430
127
183
251
(2,166)
207
(25)
(771)
(100)
(125)
(160)
158
(186)
1,021
119
—
204
6,302
(7,923)
(1,125)
1,112
275
(649)
203
(190)
(133)
(8,430)
3,973
(49)
288
(190)
(305)
(456)
288
144
1,692
91
(536)
(207)
(89)
(77)
(4)
99
(130)
(266)
(270)
(8)
130
—
(258)
6,169
(7,586)
(1,598)
1,593
917
(442)
(124)
(188)
75
(7,353)
Consolidated Statements of Cash Flows
For the Years Ended December 31, 2023, 2022, and 2021
Operating Activities:
Consolidated net income
Adjustments to reconcile consolidated net income
to net cash provided from operating activities —
Depreciation and amortization, total
Deferred income taxes
Utilization of federal investment tax credits
Allowance for equity funds used during construction
Pension, postretirement, and other employee benefits
Settlement of asset retirement obligations
Storm damage and reliability reserve accruals
Stock based compensation expense
Estimated loss on Plant Vogtle Units 3 and 4
Impairment charges
Retail fuel cost under recovery – long-term
Natural gas cost under recovery – long-term
Other, net
Changes in certain current assets and liabilities —
–Receivables
–Retail fuel cost under recovery
–Fossil fuel for generation
–Materials and supplies
–Natural gas cost under recovery
–Other current assets
–Accounts payable
–Customer refunds
–Natural gas cost over recovery
–Other current liabilities
Net cash provided from operating activities
Investing Activities:
Property additions
Nuclear decommissioning trust fund purchases
Nuclear decommissioning trust fund sales
Proceeds from dispositions
Cost of removal, net of salvage
Change in construction payables, net
Payments pursuant to LTSAs
Other investing activities
Net cash used for investing activities
The accompanying notes are an integral part of these consolidated financial statements.
62
Southern Company 2023 Annual Report
Consolidated Statements of Cash Flows (continued)
For the Years Ended December 31, 2023, 2022, and 2021
Financing Activities:
Increase (decrease) in notes payable, net
Proceeds —
Long-term debt
Short-term borrowings
Common stock
Redemptions and repurchases —
Long-term debt
Short-term borrowings
Preferred stock
Capital contributions from noncontrolling interests
Distributions to noncontrolling interests
Payment of common stock dividends
Other financing activities
Net cash provided from financing activities
Net Change in Cash, Cash Equivalents, and Restricted Cash
Cash, Cash Equivalents, and Restricted Cash at Beginning of Year
Cash, Cash Equivalents, and Restricted Cash at End of Year
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $132, $103, and $92 capitalized, respectively)
Income taxes, net
Noncash transactions —
Accrued property additions at year-end
LTSA credits utilized from the sale of spare parts
Contributions from noncontrolling interests
Contributions of wind turbine equipment
The accompanying notes are an integral part of these consolidated financial statements.
2023
2022
2021
(in millions)
973
(337)
530
8,972
350
36
(4,294)
(1,630)
—
21
(234)
(3,035)
(160)
999
(1,116)
2,037
921
$
5,132
2,650
1,808
8,262
325
73
(2,158)
(1,150)
(298)
73
(259)
(2,907)
(218)
2,336
208
1,829
$ 2,037
(4,327)
(25)
—
501
(351)
(2,777)
(266)
1,945
761
1,068
$ 1,829
$ 2,184
132
$ 1,758
146
$ 1,718
93
1,027
23
—
—
1,024
—
15
—
866
—
89
82
63
Southern Company 2023 Annual Report
Consolidated Balance Sheets
At December 31, 2023 and 2022
Assets
Current Assets:
Cash and cash equivalents
Receivables —
Customer accounts
Unbilled revenues
Under recovered fuel clause revenues
Other accounts and notes
Accumulated provision for uncollectible accounts
Materials and supplies
Fossil fuel for generation
Natural gas for sale
Prepaid expenses
Assets from risk management activities, net of collateral
Regulatory assets – asset retirement obligations
Natural gas cost under recovery
Other regulatory assets
Other current assets
Total current assets
Property, Plant, and Equipment:
In service
Less: Accumulated depreciation
Plant in service, net of depreciation
Other utility plant, net
Nuclear fuel, at amortized cost
Construction work in progress
Total property, plant, and equipment
Other Property and Investments:
Goodwill
Nuclear decommissioning trusts, at fair value
Equity investments in unconsolidated subsidiaries
Other intangible assets, net of amortization of $376 and $340, respectively
Miscellaneous property and investments
Total other property and investments
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization
Deferred charges related to income taxes
Prepaid pension costs
Unamortized loss on reacquired debt
Deferred under recovered retail fuel clause revenues
Regulatory assets – asset retirement obligations, deferred
Other regulatory assets, deferred
Other deferred charges and assets
Total deferred charges and other assets
Total Assets
The accompanying notes are an integral part of these consolidated financial statements.
64
2023
2022
(in millions)
$
748
$
1,917
2,030
786
696
519
(68)
1,989
943
420
406
36
274
—
1,120
533
10,432
128,428
37,725
90,703
499
858
7,784
99,844
5,161
2,424
1,368
368
665
9,986
2,128
1,012
10
637
(71)
1,664
575
438
347
115
332
108
860
344
10,416
117,529
35,297
82,232
599
843
10,896
94,570
5,161
2,145
1,443
406
602
9,757
1,432
886
2,079
220
1,261
5,459
6,264
1,468
19,069
$139,331
1,531
866
2,290
238
2,056
5,764
5,918
1,485
20,148
$134,891
Southern Company 2023 Annual Report Consolidated Balance Sheets (continued)
At December 31, 2023 and 2022
Liabilities and Stockholders’ Equity
Current Liabilities:
Securities due within one year
Notes payable
Accounts payable
Customer deposits
Accrued taxes —
Accrued income taxes
Other accrued taxes
Accrued interest
Accrued compensation
Asset retirement obligations
Liabilities from risk management activities, net of collateral
Operating lease obligations
Natural gas cost over recovery
Other regulatory liabilities
Other current liabilities
Total current liabilities
Long-Term Debt
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes
Deferred credits related to income taxes
Accumulated deferred ITCs
Employee benefit obligations
Operating lease obligations, deferred
Asset retirement obligations, deferred
Other cost of removal obligations
Other regulatory liabilities, deferred
Other deferred credits and liabilities
Total deferred credits and other liabilities
Total Liabilities
Common Stockholders’ Equity:
2023
2022
(in millions)
$
2,476
$
4,285
2,314
2,898
503
8
860
652
2,609
3,525
502
60
764
614
1,151
1,127
744
294
183
214
141
1,029
13,467
57,210
694
178
197
—
382
787
15,724
50,656
10,990
10,036
4,674
2,067
1,115
1,307
9,573
1,957
715
1,031
5,235
2,133
1,238
1,388
10,146
1,903
733
1,167
33,429
33,979
104,106
100,359
Common stock, par value $5 per share (Authorized - 1.5 billion shares)
5,423
5,417
(Issued - 1.1 billion shares; Treasury - 1.0 million shares)
Paid-in capital
Treasury, at cost
Retained earnings
Accumulated other comprehensive loss
Total common stockholders’ equity
Noncontrolling interests
Total Stockholders’ Equity (See accompanying statements)
Total Liabilities and Stockholders’ Equity
Commitments and Contingent Matters (See notes)
The accompanying notes are an integral part of these consolidated financial statements.
13,775
13,673
(59)
(53)
12,482
11,538
(177)
(167)
31,444
3,781
35,225
30,408
4,124
34,532
$139,331
$134,891
65
Southern Company 2023 Annual Report Consolidated Statements of Stockholders' Equity
For the Years Ended December 31, 2023, 2022, and 2021
Southern Company Common Stockholders' Equity
Number of
Common Shares
Common Stock
Issued Treasury
Par
Value
Paid-In
Capital Treasury
Retained
Earnings
Accumulated
Other
Comprehensive
Income
(Loss)
Noncontrolling
Interests
Total
Balance at December 31, 2020
Consolidated net income (loss)
Other comprehensive income
Stock issued
Stock-based compensation
Cash dividends of $2.6200 per share
Capital contributions from
noncontrolling interests
Distributions to
noncontrolling interests
Other
Balance at December 31, 2021
Consolidated net income (loss)
Other comprehensive income
Stock issued
Stock-based compensation
Cash dividends of $2.7000 per share
Capital contributions from
noncontrolling interests
Distributions to
noncontrolling interests
Other
Balance at December 31, 2022
Consolidated net income (loss)
Other comprehensive income (loss)
Stock issued
Stock-based compensation
Cash dividends of $2.7800 per share
Capital contributions from
noncontrolling interests
Distributions to
noncontrolling interests
Other
Balance at December 31, 2023
1,058
—
—
3
—
—
—
—
—
1,061
—
—
29
—
—
—
—
—
1,090
—
—
2
—
—
—
—
—
1,092
(1) $ 5,268 $ 11,834
—
—
—
—
—
—
62
11
—
62
—
—
—
—
—
(in millions)
$ (46) $ 11,311
2,393
—
—
—
—
—
—
—
— (2,777)
$ (395)
—
158
—
—
—
$ 4,262 $ 32,234
2,294
(99)
158
—
73
—
—
62
— (2,777)
—
—
—
(1)
—
—
—
—
—
—
—
—
(1)
—
—
—
—
—
—
—
—
—
—
—
590
590
—
—
5,279
—
—
138
—
—
—
(8)
11,950
—
—
1,670
44
—
—
—
2
(1)
10,929
(47)
3,524
—
—
—
—
—
—
—
— (2,907)
—
—
(237)
—
71
—
—
—
(351)
(351)
(7)
—
32,276
4,402
3,417
(107)
71
—
1,808
—
—
44
— (2,907)
—
—
—
—
—
88
88
—
—
5,417
—
—
6
—
—
—
9
13,673
—
—
30
73
—
—
—
(8)
(6)
11,538
(53)
3,976
—
—
—
—
—
—
—
— (3,035)
—
(1)
(167)
—
(10)
—
—
—
(259)
(259)
(6)
—
34,532
4,124
3,849
(127)
(10)
—
36
—
73
—
— (3,035)
—
—
—
—
—
21
21
—
—
—
—
(1)
—
(1) $5,423 $13,775
—
(6)
—
3
$ (59) $ 12,482
—
—
$ (177)
(236)
(1)
(236)
(5)
$3,781 $ 35,225
The accompanying notes are an integral part of these consolidated financial statements.
66
Southern Company 2023 Annual Report
Index to the Notes to Financial Statements
68
82
102
108
111
115
119
122
129
137
143
167
169
175
183
185
Note 1
Note 2
Note 3
Note 4
Note 5
Note 6
Note 7
Note 8
Note 9
Note 10
Note 11
Note 12
Note 13
Note 14
Note 15
Note 16
Summary of Significant Accounting Policies
Regulatory Matters
Contingencies, Commitments, and Guarantees
Revenue from Contracts with Customers
Property, Plant, and Equipment
Asset Retirement Obligations
Consolidated Entities and Equity Method Investments
Financing
Leases
Income Taxes
Retirement Benefits
Stock Compensation
Fair Value Measurements
Derivatives
Acquisitions and Dispositions
Segment and Related Information
67
Southern Company 2023 Annual Report Notes to Financial Statements
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
General
Southern Company is the parent company of three traditional electric operating companies, as well as Southern Power, Southern Company
Gas, SCS, Southern Linc, Southern Holdings, Southern Nuclear, PowerSecure, and other direct and indirect subsidiaries. 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 natural gas distribution utilities, including Nicor Gas (Illinois), Atlanta Gas Light (Georgia), Virginia Natural Gas, and Chattanooga
Gas (Tennessee). Southern Company Gas is also involved in several other complementary businesses including gas pipeline investments and
gas marketing services. Prior to the sale of Sequent on July 1, 2021, these businesses also included wholesale gas services. SCS, the system
service company, provides, at cost, specialized services to Southern Company and its subsidiary companies. Southern Linc provides digital
wireless communications for use by Southern Company and its subsidiary companies and also markets these services to the public and
provides fiber optics services within the Southeast. Southern Holdings is an intermediate holding company subsidiary. Southern Nuclear
operates and provides services to the Southern Company system’s nuclear power plants, including Alabama Power’s Plant Farley and
Georgia Power’s Plant Hatch and Plant Vogtle Units 1 through 3, and is currently managing construction and start-up of Plant Vogtle Unit 4.
PowerSecure develops distributed energy and resilience solutions and deploys microgrids for commercial, industrial, governmental, and utility
customers. See Note 15 for information regarding the sale of Sequent.
The Registrants’ financial statements reflect investments in subsidiaries on a consolidated basis. Intercompany transactions have been
eliminated in consolidation. The equity method is used for investments in entities in which a Registrant has significant influence but does
not have control and for VIEs where a Registrant has an equity investment but is not the primary beneficiary. Southern Power has controlling
ownership in certain legal entities for which the contractual provisions represent profit-sharing arrangements because the allocations of
cash distributions and tax benefits are not based on fixed ownership percentages. For these arrangements, the noncontrolling interest is
accounted for under a balance sheet approach utilizing the HLBV method. The HLBV method calculates each partner's share of income
based on the change in net equity the partner can legally claim in a HLBV at the end of the period compared to the beginning of the period.
See “Variable Interest Entities“ herein and Note 7 for additional information.
The traditional electric operating companies, Southern Power, certain subsidiaries of Southern Company Gas, and certain other subsidiaries
are subject to regulation by the FERC, and the traditional electric operating companies and the natural gas distribution utilities are also
subject to regulation by their respective state PSCs or other applicable state regulatory agencies. As such, the respective financial statements
of the applicable Registrants reflect the effects of rate regulation in accordance with GAAP and comply with the accounting policies and
practices prescribed by relevant state PSCs or other applicable state regulatory agencies.
The preparation of financial statements in conformity with GAAP requires the use of estimates, and the actual results may differ from those
estimates. Certain prior years' data presented in the financial statements have been reclassified to conform to the current year presentation.
These reclassifications had no impact on the Registrants' results of operations, financial position, or cash flows.
68
Southern Company 2023 Annual Report Notes to Financial Statements
Recently Adopted Accounting Standards
In 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial
Reporting (ASU 2020-04) providing temporary guidance to ease the potential burden in accounting for reference rate reform primarily
resulting from the discontinuation of LIBOR, which began phasing out on December 31, 2021. The discontinuation date of the overnight
1-, 3-, 6-, and 12-month tenors of LIBOR was June 30, 2023, which was beyond the original effective date of ASU 2020-04; therefore, in
December 2022, the FASB issued ASU 2022-06, Reference Rate Reform (Topic 848): Deferral of the Sunset Date of Topic 848 (ASU 2022-06) to
defer the sunset date of ASU 2020-04 from December 31, 2022 to December 31, 2024.
The amendments were elective and applied to all entities that have contracts, hedging relationships, and other transactions that reference LIBOR or
another reference rate expected to be discontinued. The guidance (i) simplified accounting analyses under current GAAP for contract modifications;
(ii) simplified the assessment of hedge effectiveness and allows hedging relationships affected by reference rate reform to continue; and (iii) allowed
a one-time election to sell or transfer debt securities classified as held to maturity that reference a rate affected by reference rate reform. An entity
could elect to apply the amendments prospectively from March 12, 2020 through December 31, 2024 by accounting topic. The Registrants elected
to apply the amendments to modifications of debt and derivative arrangements that meet the scope of ASU 2020-04 and ASU 2022-06.
Certain provisions in PPAs at Southern Power included references to LIBOR. Contract amendments have been executed to change to a SOFR-based
interest rate. Southern Power adopted and applied the practical expedients guidance to these PPAs. Additionally, the Registrants referenced LIBOR
for certain debt and hedging arrangements. As of July 1, 2023, all of the debt and hedging arrangements of the Registrants had transitioned to a
SOFR-based interest rate based on the terms of the agreements. There were no material impacts from the transition to SOFR and no impacts to any
existing accounting conclusions. See Note 14 under “Interest Rate Derivatives“ for additional information.
Affiliate Transactions
The traditional electric operating companies, Southern Power, and Southern Company Gas have agreements with SCS under which certain
of the following services are rendered to them at direct or allocated cost: general executive and advisory, general and design engineering,
operations, purchasing, accounting, finance, treasury, legal, tax, information technology, marketing, auditing, insurance and pension
administration, human resources, systems and procedures, digital wireless communications, cellular tower space, and other services with
respect to business and operations, construction management, and Southern Company power pool transactions. These costs are primarily
included in other operations and maintenance expenses or capitalized to property, plant, and equipment. Costs for these services from SCS
in 2023, 2022, and 2021 were as follows:
2023
2022
2021
Alabama
Power
$611
549
504
Georgia
Power
$857
762
663
Mississippi
Power
(in millions)
$113
115
120
Southern
Power
Southern
Company Gas
$86
86
89
$261
262
239
Alabama Power and Georgia Power also have agreements with Southern Nuclear under which Southern Nuclear renders the following
nuclear-related services at cost: general executive and advisory services; general operations, management, and technical services;
administrative services including procurement, accounting, employee relations, systems, and procedures services; strategic planning and
budgeting services; other services with respect to business and operations; and, for Georgia Power, construction management. These costs are
primarily included in other operations and maintenance expenses or capitalized to property, plant, and equipment. Costs for these services
in 2023, 2022, and 2021 amounted to $251 million, $267 million, and $258 million, respectively, for Alabama Power and $899 million,
$895 million, and $906 million, respectively, for Georgia Power. See Note 2 under “Georgia Power – Nuclear Construction“ for additional
information regarding Southern Nuclear's construction management of Plant Vogtle Unit 4 for Georgia Power.
Cost allocation methodologies used by SCS and Southern Nuclear prior to the repeal of the Public Utility Holding Company Act of 1935,
as amended, were approved by the SEC. Subsequently, additional cost allocation methodologies have been reported to the FERC and
management believes they are reasonable. The FERC permits services to be rendered at cost by system service companies.
Alabama Power's and Georgia Power's power purchases from affiliates through the Southern Company power pool are included in purchased
power, affiliates on their respective statements of income. Mississippi Power's and Southern Power's power purchases from affiliates through
the Southern Company power pool are included in purchased power on their respective statements of income and were as follows:
2023
2022
2021
Mississippi
Power
Southern
Power
(in millions)
$4
4
9
$13
29
15
69
Southern Company 2023 Annual Report
Notes to Financial Statements
Georgia Power has entered into several PPAs with Southern Power for capacity and energy. Georgia Power's total expenses associated
with these PPAs were $143 million, $151 million, and $132 million in 2023, 2022, and 2021, respectively. Southern Power's total revenues
from all PPAs with Georgia Power, included in wholesale revenue affiliates on Southern Power's consolidated statements of income, were
$145 million, $154 million, and $139 million for 2023, 2022, and 2021, respectively. Included within these revenues were affiliate PPAs
accounted for as operating leases, which totaled $116 million, $116 million, and $112 million for 2023, 2022, and 2021, respectively.
See Note 9 for additional information. Also see Note 2 under “Georgia Power – Integrated Resource Plans“ for information regarding
additional affiliate PPAs commencing in 2024.
SCS (as agent for Alabama Power, Georgia Power, and Southern Power) and Southern Company Gas have long-term interstate natural gas
transportation agreements with SNG that are governed by the terms and conditions of SNG's natural gas tariff and are subject to FERC
regulation. See Note 7 under “Southern Company Gas – Equity Method Investments“ for additional information. Transportation costs under
these agreements in 2023, 2022, and 2021 were as follows:
2023
2022
2021
Alabama
Power
Georgia
Power
Southern
Power
Southern
Company Gas
(in millions)
$12
18
14
$101
99
108
$34
37
31
$28
27
29
SCS, as agent for the traditional electric operating companies and Southern Power, has agreements with certain subsidiaries of Southern
Company Gas to purchase natural gas. Natural gas purchases made under these agreements were immaterial for Alabama Power, Georgia
Power, and Mississippi Power for all periods presented, immaterial for Southern Power in 2023 and 2022, and $18 million for Southern
Power in 2021.
Alabama Power and Mississippi Power jointly own Plant Greene County. The companies have an agreement under which Alabama Power
operates Plant Greene County and Mississippi Power reimburses Alabama Power for its proportionate share of non-fuel operations and
maintenance expenses, which totaled $5 million, $6 million, and $10 million in 2023, 2022, and 2021, respectively. See Note 5 under
“Joint Ownership Agreements“ for additional information.
Alabama Power, Georgia Power, and Mississippi Power each have agreements with PowerSecure for equipment purchases and/or services
related to utility infrastructure construction, distributed energy, and energy efficiency projects. Costs under these agreements were
immaterial for all periods presented.
Southern Company Gas has a $77 million contract with the U.S. General Services Administration to increase energy efficiency at certain
federal buildings across Georgia, with completion expected by the end of 2024. Southern Company Gas engaged PowerSecure to provide
the majority of the construction services under the contract. During 2023 and 2022, Southern Company Gas paid $29 million and
$10 million, respectively, to PowerSecure related to this agreement.
See Note 7 under “SEGCO“ for information regarding Alabama Power's and Georgia Power's equity method investment in SEGCO and
related affiliate purchased power costs, as well as Alabama Power's gas pipeline ownership agreement with SEGCO.
Southern Power has several agreements with SCS for transmission services, which are billed to Southern Power based on the Southern
Company Open Access Transmission Tariff as filed with the FERC. Transmission services purchased by Southern Power from SCS totaled
$33 million, $39 million, and $28 million for 2023, 2022, and 2021, respectively, and were charged to other operations and maintenance
expenses in Southern Power's consolidated statements of income.
The traditional electric operating companies and Southern Power may jointly enter into various types of wholesale energy, natural gas,
and certain other contracts, either directly or through SCS as agent. Each participating company may be jointly and severally liable for the
obligations incurred under these agreements. See Note 14 under “Contingent Features“ for additional information. Southern Power and the
traditional electric operating companies generally settle amounts related to the above transactions on a monthly basis in the month following
the performance of such services or the purchase or sale of electricity. See “Revenues – Southern Power“ herein for additional information.
The traditional electric operating companies, Southern Power, and Southern Company Gas provide incidental services to and receive such
services from other Southern Company subsidiaries which are generally minor in duration and amount. Except as described herein, the
traditional electric operating companies, Southern Power, and Southern Company Gas neither provided nor received any material services
to or from affiliates in any year presented.
70
Southern Company 2023 Annual Report Notes to Financial Statements
Regulatory Assets and Liabilities
The traditional electric operating companies and the natural gas distribution utilities are subject to accounting requirements for the effects
of rate regulation. Regulatory assets represent probable future revenues associated with certain costs that are expected to be recovered from
customers through the ratemaking process. Regulatory liabilities represent costs recovered that are expected to be incurred in the future or
probable future reductions in revenues associated with amounts that are expected to be credited to customers through the ratemaking process.
In the event that a portion of a traditional electric operating company's or a natural gas distribution utility's operations is no longer subject to
applicable accounting rules for rate regulation, such company would be required to write off to income or reclassify to AOCI related regulatory
assets and liabilities that are not specifically recoverable through regulated rates. In addition, the traditional electric operating company or
the natural gas distribution utility would be required to determine if any impairment to other assets, including plant, exists and write down
the assets, if impaired, to their fair values. All regulatory assets and liabilities are to be reflected in rates. See Note 2 for additional information
including details of regulatory assets and liabilities reflected in the balance sheets for Southern Company, the traditional electric operating
companies, and Southern Company Gas.
Revenues
The Registrants generate revenues from a variety of sources which are accounted for under various revenue accounting guidance, including
revenue from contracts with customers, lease, derivative, and regulatory accounting. See Notes 4, 9, and 14 for additional information.
Traditional Electric Operating Companies
The majority of the revenues of the traditional electric operating companies are generated from contracts with retail electric customers.
These revenues, generated from the integrated service to deliver electricity when and if called upon by the customer, are recognized
as a single performance obligation satisfied over time, at a tariff rate, and as electricity is delivered to the customer during the month.
Unbilled revenues related to retail sales are accrued at the end of each fiscal period. Retail rates may include provisions to adjust revenues
for fluctuations in fuel costs, fuel hedging, the energy component of purchased power costs, and certain other costs. Revenues are adjusted
for differences between these actual costs and amounts billed in current regulated rates. Under or over recovered regulatory clause
revenues are recorded in the balance sheets and are recovered from or returned to customers, respectively, through adjustments to the
billing factors. See Note 2 for additional information regarding regulatory matters of the traditional electric operating companies.
Wholesale capacity revenues from PPAs are recognized in amounts billable under the contract terms. Energy and other revenues are
generally recognized as services are provided. The contracts for capacity and energy in a wholesale PPA have multiple performance
obligations where the contract's total transaction price is allocated to each performance obligation based on the standalone selling price.
The standalone selling price is primarily determined by the price charged to customers for the specific goods or services transferred with
the performance obligations. Generally, the traditional electric operating companies recognize revenue as the performance obligations are
satisfied over time as electricity is delivered to the customer or as generation capacity is available to the customer.
For both retail and wholesale revenues, the traditional electric operating companies have elected to recognize revenue for their sales of
electricity and capacity using the invoice practical expedient as they generally have a right to consideration in an amount that corresponds
directly with the value to the customer of the performance completed to date and that may be invoiced. Payment for goods and services
rendered is typically due in the subsequent month following satisfaction of the Registrants' performance obligation.
Southern Power
Southern Power sells capacity and energy at rates specified under contractual terms in long-term PPAs. These PPAs are accounted for as leases,
normal sale derivatives, or contracts with customers. Capacity revenues from PPAs classified as operating leases are recognized on a
straight-line basis over the term of the agreement. Energy revenues are recognized in the period the energy is delivered. Capacity revenues
from PPAs classified as sales-type leases are recognized by accounting for interest income on the net investment in the lease.
Southern Power's non-lease contracts commonly include capacity and energy which are considered separate performance obligations.
In these contracts, the total transaction price is allocated to each performance obligation based on the standalone selling price.
The standalone selling price is primarily determined by the price charged to customers for the specific goods or services transferred with
the performance obligations. Generally, Southern Power recognizes revenue as the performance obligations are satisfied over time, as
electricity is delivered to the customer or as generation capacity is made available to the customer.
Southern Power generally has a right to consideration in an amount that corresponds directly with the value to the customer of the
performance completed to date and may recognize revenue in the amount to which the entity has a right to invoice. Payment for goods
and services rendered is typically due in the subsequent month following satisfaction of Southern Power's performance obligation.
71
Southern Company 2023 Annual Report Notes to Financial Statements
When multiple contracts exist with the same counterparty, the revenues from each contract are accounted for as separate arrangements.
Southern Power may also enter into contracts to sell short-term capacity in the wholesale electricity markets. These sales are generally
classified as mark-to-market derivatives and net unrealized gains and losses on such contracts are recorded in wholesale revenues. See Note
14 and “Financial Instruments“ herein for additional information.
Southern Company Gas
Gas Distribution Operations
Southern Company Gas records revenues when goods or services are provided to customers. Those revenues are based on rates approved by
the state regulatory agencies of the natural gas distribution utilities. Atlanta Gas Light operates in a deregulated natural gas market whereby
Marketers, rather than a traditional utility, sell natural gas to end-use customers in Georgia and handle customer billing functions. As required
by the Georgia PSC, Atlanta Gas Light bills Marketers in equal monthly installments for each residential, commercial, and industrial end-use
customer's distribution costs as well as for capacity costs utilizing a seasonal rate design for the calculation of each residential end-use
customer's annual straight-fixed-variable charge, which reflects the historic volumetric usage pattern for the entire residential class.
The majority of the revenues of Southern Company Gas are generated from contracts with natural gas distribution customers.
Revenues from this integrated service to deliver gas when and if called upon by the customer are recognized as a single performance
obligation satisfied over time and are recognized at a tariff rate as gas is delivered to the customer during the month.
The standalone selling price is primarily determined by the price charged to customers for the specific goods or services transferred with
the performance obligations. Generally, Southern Company Gas recognizes revenue as the performance obligations are satisfied over time
as natural gas is delivered to the customer. The performance obligations related to wholesale gas services are satisfied, and revenue is
recognized, at a point in time when natural gas is delivered to the customer.
Southern Company Gas has elected to recognize revenue for sales of gas using the invoice practical expedient as it generally has a right to
consideration in an amount that corresponds directly with the value to the customer of the performance completed to date and that may
be invoiced. Payment for goods and services rendered is typically due in the subsequent month following satisfaction of Southern Company
Gas' performance obligation.
With the exception of Atlanta Gas Light, the natural gas distribution utilities have rate structures that include volumetric rate designs that
allow the opportunity to recover certain costs based on gas usage. Revenues from sales and transportation services are recognized in the
same period in which the related volumes are delivered to customers. Revenues from residential and certain commercial and industrial
customers are recognized on the basis of scheduled meter readings. Additionally, unbilled revenues are recognized for estimated deliveries
of gas not yet billed to these customers, from the last bill date to the end of the accounting period. For other commercial and industrial
customers, revenues are based on actual deliveries through the end of the period.
The tariffs for the natural gas distribution utilities include provisions which allow for the recognition of certain revenues prior to the time
such revenues are billed to customers. These provisions are referred to as alternative revenue programs and provide for the recognition
of certain revenues prior to billing, as long as the amounts recognized will be collected from customers within 24 months of recognition.
Revenue related to alternative revenue programs was $20 million, $(5) million, and $11 million in 2023, 2022, and 2021, respectively.
These programs are as follows:
O Weather normalization adjustments – reduce customer bills when winter weather is colder than normal and increase customer bills
when weather is warmer than normal and are included in the tariffs for Virginia Natural Gas and Chattanooga Gas;
O Revenue normalization mechanisms – mitigate the impact of conservation and declining customer usage and are contained in the tariffs
for Virginia Natural Gas and Nicor Gas; and
O Revenue true-up adjustment – included within the provisions of the GRAM program in which Atlanta Gas Light participates as a short-
term alternative to formal rate case filings, the revenue true-up feature provides for a positive (or negative) adjustment to record
revenue in the amount of any variance to budgeted revenues, which are submitted and approved annually as a requirement of GRAM.
Such adjustments are reflected in customer billings in a subsequent program year.
Wholesale Gas Services
Prior to the sale of Sequent on July 1, 2021, Southern Company Gas netted revenues from energy and risk management activities with
the associated costs. Profits from sales between segments were eliminated and recognized as goods or services sold to end-use customers.
Southern Company Gas recorded wholesale gas services' transactions that qualified as derivatives at fair value with changes in fair value
recognized in earnings in the period of change and characterized as unrealized gains or losses. Gains and losses on derivatives held for
energy trading purposes were presented on a net basis in revenue. See Note 15 under “Southern Company Gas“ for additional information
on the sale of Sequent.
72
Southern Company 2023 Annual Report Notes to Financial Statements
Gas Marketing Services
Southern Company Gas recognizes revenues from natural gas sales and transportation services in the same period in which the related
volumes are delivered to customers and recognizes sales revenues from residential and certain commercial and industrial customers on the
basis of scheduled meter readings. Southern Company Gas also recognizes unbilled revenues for estimated deliveries of gas not yet billed
to these customers from the most recent meter reading date to the end of the accounting period. For other commercial and industrial
customers and for all wholesale customers, revenues are based on actual deliveries during the period.
Southern Company Gas recognizes revenues on 12-month utility-bill management contracts as the lesser of cumulative earned or
cumulative billed amounts.
Concentration of Revenue
Southern Company, Alabama Power, Georgia Power, Mississippi Power (with the exception of its full requirements cost-based MRA electric
tariffs described below), Southern Power, and Southern Company Gas each have a diversified base of customers and no single customer
comprises 10% or more of each company’s revenues.
Mississippi Power provides service under long-term contracts with rural electric cooperative associations and a municipality located in
southeastern Mississippi under requirements cost-based MRA electric tariffs, which are subject to regulation by the FERC. The contracts with
these wholesale customers represented 14.0% of Mississippi Power's total operating revenues in 2023.
Fuel Costs
Fuel costs for the traditional electric operating companies and Southern Power are expensed as the fuel is used. Fuel expense generally
includes fuel transportation costs and the cost of purchased emissions allowances as they are used. For Alabama Power and Georgia Power,
fuel expense also includes the amortization of the cost of nuclear fuel. For the traditional electric operating companies, fuel costs also
include gains and/or losses from fuel-hedging programs as approved by their respective state PSCs.
Cost of Natural Gas
Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, Southern Company Gas charges its utility customers
for natural gas consumed using natural gas cost recovery mechanisms set by the applicable state regulatory agencies. Under these
mechanisms, all prudently-incurred natural gas costs are passed through to customers without markup, subject to regulatory review.
Southern Company Gas defers or accrues the difference between the actual cost of natural gas and the amount of commodity revenue
earned in a given period such that no operating income is recognized related to these costs. The deferred or accrued amount is either billed
or refunded to customers prospectively through adjustments to the commodity rate. Deferred and accrued natural gas costs are included in
the balance sheets as regulatory assets and regulatory liabilities, respectively.
Southern Company Gas' gas marketing services' customers are charged for actual or estimated natural gas consumed. Within cost of natural
gas, Southern Company Gas also includes costs of lost and unaccounted for gas and gains and losses associated with certain derivatives.
Income Taxes
The Registrants use the liability method of accounting for deferred income taxes and provide deferred income taxes for all significant
income tax temporary differences. In accordance with regulatory requirements, deferred federal ITCs for the traditional electric operating
companies are amortized over the average life of the related property, with such amortization normally applied as a credit to reduce
depreciation and amortization in the statements of income. Southern Power's and the natural gas distribution utilities' deferred federal
ITCs, as well as certain state ITCs for Nicor Gas, are amortized to income tax expense over the life of the respective asset.
Under current tax law, certain projects at Southern Power related to the construction of renewable facilities are eligible for federal ITCs.
Southern Power estimates eligible costs which, as they relate to acquisitions, may not be finalized until the allocation of the purchase
price to assets has been finalized. Southern Power applies the deferred method to ITCs, whereby the ITCs are recorded as a deferred credit
and amortized to income tax expense over the life of the respective asset. Furthermore, the tax basis of the asset is reduced by 50% of
the ITCs received, resulting in a net deferred tax asset. Southern Power has elected to recognize the tax benefit of this basis difference as
a reduction to income tax expense in the year in which the plant reaches commercial operation. State ITCs are recognized as an income
tax benefit in the period in which the credits are generated. In addition, certain projects are eligible for federal and state PTCs, which are
recognized as an income tax benefit based on KWH production.
Federal ITCs and PTCs, as well as state ITCs and other state tax credits available to reduce income taxes payable, were not fully utilized
in 2023 and will be carried forward and utilized in future years. In addition, Southern Company is expected to have various state net
operating loss (NOL) carryforwards for certain of its subsidiaries, including Mississippi Power and Southern Power, which would result in
income tax benefits in the future, if utilized. See Note 10 under “Current and Deferred Income Taxes – Tax Credit Carryforwards“ and
“ – Net Operating Loss Carryforwards“ for additional information.
73
Southern Company 2023 Annual Report Notes to Financial Statements
In June 2023, the IRS issued temporary regulations related to the transferability of certain tax credits under the IRA. Southern Company
and certain subsidiaries have tax credits that are eligible to be transferred. The discount recorded on transferred credits is booked through
income tax expense.
Under current tax law, Georgia Power is eligible to generate advanced nuclear PTCs for Plant Vogtle Unit 3, which are recognized as an
income tax benefit based on KWH production and are eligible to be transferred. Pursuant to the Global Amendments to the Vogtle Joint
Ownership Agreements (as defined in Note 2 under “Georgia Power – Nuclear Construction – Joint Owner Contracts“), Georgia Power is
purchasing advanced nuclear PTCs for Plant Vogtle Unit 3 from the other Vogtle Owners. The gain recognized on the purchase of the joint
owner PTCs is recognized as an income tax benefit.
The Registrants recognize tax positions that are “more likely than not“ of being sustained upon examination by the appropriate taxing
authorities. See Note 10 under “Unrecognized Tax Benefits“ for additional information.
Other Taxes
Taxes imposed on and collected from customers on behalf of governmental agencies are presented net on the Registrants' statements of
income and are excluded from the transaction price in determining the revenue related to contracts with a customer.
Southern Company Gas is taxed on its gas revenues by various governmental authorities, but is allowed to recover these taxes from
its customers. Revenue taxes imposed on the natural gas distribution utilities are recorded at the amount charged to customers, which
may include a small administrative fee, as operating revenues, and the related taxes imposed on Southern Company Gas are recorded as
operating expenses on the statements of income. Revenue taxes included in operating expenses were $129 million, $158 million, and
$119 million in 2023, 2022, and 2021, respectively.
Allowance for Funds Used During Construction and Interest Capitalized
The traditional electric operating companies and the natural gas distribution utilities record AFUDC, which represents the estimated debt
and equity costs of capital funds that are necessary to finance the construction of new regulated facilities. While cash is not realized
currently, AFUDC increases the revenue requirement and is recovered over the service life of the asset through a higher rate base and higher
depreciation. The equity component of AFUDC is not taxable.
Interest related to financing the construction of new facilities at Southern Power and new facilities not included in the traditional electric
operating companies' and Southern Company Gas' regulated rates is capitalized in accordance with standard interest capitalization
requirements.
Total AFUDC and interest capitalized for the applicable Registrants in 2023, 2022, and 2021 was as follows:
2023
2022
2021
Southern
Company
Alabama
Power
Georgia
Power(*)
Southern
Power
Southern
Company Gas
$ 400
327
282
$ 109
90
68
(in millions)
$251
213
190
$ 3
—
6
$ 37
24
18
(*) See Note 2 under “Georgia Power – Nuclear Construction“ for information on the inclusion of a portion of construction costs related to Plant Vogtle Unit 4
in Georgia Power's rate base.
The average AFUDC composite rates for 2023, 2022, and 2021 for the traditional electric operating companies and the natural gas
distribution utilities were as follows:
Alabama Power
Georgia Power(a)
Mississippi Power(b)
Southern Company Gas:
Atlanta Gas Light
Chattanooga Gas
Nicor Gas
2023
2022
8.1%
7.6%
—%
7.4%
7.1%
4.6%
7.9%
7.3%
5.3%
7.6%
7.1%
2.0%
2021
7.9%
7.2%
2.5%
7.7%
7.1%
0.1%
(a) Excludes AFUDC related to the construction of Plant Vogtle Units 3 and 4. See Note 2 under “Georgia Power – Nuclear Construction“ for additional information.
(b) Mississippi Power's AFUDC was immaterial in 2023.
74
Southern Company 2023 Annual Report Notes to Financial Statements
Impairment of Long-Lived Assets
The Registrants evaluate long-lived assets and finite-lived intangible assets for impairment when events or changes in circumstances
indicate that the carrying amount of such assets may not be recoverable. The determination of whether an impairment has occurred
is based on either a specific regulatory disallowance, a sales transaction price that is less than the asset group's carrying amount, or an
estimate of undiscounted future cash flows attributable to the asset group, as compared with the carrying amount of the assets. If an
impairment has occurred, the amount of the impairment loss recognized is determined by either the amount of regulatory disallowance
or by the amount the carrying amount exceeds the estimated fair value of the assets. For assets identified as held for sale, the carrying
amount is compared to the estimated fair value less the cost to sell in order to determine if an impairment loss is required. Until the
assets are disposed of, their estimated fair value is re-evaluated when circumstances or events change. See Notes 7 and 9 under “Southern
Company Gas“ and “Southern Company Leveraged Lease,“ respectively, and Note 15 under “Southern Company“ and “Southern Company
Gas“ for information regarding impairment charges recorded during the periods presented.
Goodwill and Other Intangible Assets
Southern Power's intangible assets consist primarily of certain PPAs acquired, which are amortized over the term of the respective PPA.
Southern Company Gas' goodwill and other intangible assets primarily relate to its 2016 acquisition by Southern Company. In addition to
these items, Southern Company's goodwill and other intangible assets also relate to its 2016 acquisition of PowerSecure.
For its 2023 and 2022 annual impairment tests, Southern Company Gas management performed the qualitative assessment and
determined that it was more likely than not that the fair value of all of its reporting units with goodwill exceeded their carrying amounts,
and therefore no quantitative assessment was required. For its 2021 annual impairment test, Southern Company Gas management
performed the quantitative assessment and confirmed that the fair values of all of its reporting units with goodwill exceeded their carrying
amounts.
For its 2023 and 2021 annual impairment tests, PowerSecure management performed the quantitative assessment, which resulted in the
fair value of PowerSecure exceeding its carrying amount. For its 2022 annual impairment test, PowerSecure management performed the
quantitative assessment, which resulted in the fair value of PowerSecure being lower than its carrying amount. The fair value was estimated
using a discounted cash flow analysis. The decline in fair value primarily resulted from declining macroeconomic conditions, reducing sales
growth and estimated cash flows. As a result, a goodwill impairment of $119 million was recorded in the fourth quarter 2022.
At December 31, 2023 and 2022, goodwill was as follows:
Southern Company
Southern Company Gas:
Gas distribution operations
Gas marketing services
Southern Company Gas total
At December 31,
2023
At December 31,
2022
(in millions)
$ 5,161
$ 4,034
981
$ 5,015
$ 5,161
$ 4,034
981
$ 5,015
75
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2023 and 2022, other intangible assets were as follows:
Southern Company
Subject to amortization:
Customer relationships
Trade names
PPA fair value adjustments
Other
Total subject to amortization
Not subject to amortization:
FCC licenses
Total other intangible assets
Southern Power(*)
PPA fair value adjustments
Southern Company Gas(*)
Gas marketing services
Customer relationships
Trade names
Total other intangible assets
(*) All subject to amortization.
At December 31, 2023
At December 31, 2022
Gross
Carrying
Amount
Accumulated
Amortization
(in millions)
Other
Intangible
Assets, Net
Gross
Carrying
Amount
Accumulated
Amortization
(in millions)
Other
Intangible
Assets, Net
$ 212
64
390
3
$ 669
75
$ 744
$ (172)
(53)
(148)
(3)
$ (376)
—
$ (376)
$ 40
11
242
—
$293
75
$368
$212
64
390
5
$671
75
$746
$(162)
(44)
(129)
(5)
$(340)
—
$(340)
$ 50
20
261
—
$331
75
$406
$ 390
$ (148)
$242
$390
$(129)
$261
$ 156
26
$ 182
$ (145)
(21)
$ (166)
$ 11
5
$ 16
$156
26
$182
$(139)
(17)
$(156)
$ 17
9
$ 26
Amortization associated with other intangible assets in 2023, 2022, and 2021 was as follows:
Southern Company(a)
Southern Power(b)
Southern Company Gas:
Gas marketing services
2023
$38
20
10
2022
(in millions)
$39
20
11
2021
$44
20
15
(a) Includes $20 million annually recorded as a reduction to operating revenues.
(b) Recorded as a reduction to operating revenues.
At December 31, 2023, the estimated amortization associated with other intangible assets for the next five years is as follows:
Southern Company
Southern Power
Southern Company Gas
Acquisition Accounting
2024
2025
$35
20
7
$32
20
6
2026
(in millions)
$27
20
3
2027
2028
$24
20
—
$24
20
—
At the time of an acquisition, management will assess whether acquired assets and activities meet the definition of a business.
Acquisitions that meet the definition of a business are accounted for under the acquisition method, and operating results from the
date of acquisition are included in the acquiring entity's financial statements. Identifiable assets acquired, liabilities assumed, and any
noncontrolling interests (including any intangible assets) are recognized and measured at fair value. Assets acquired that do not meet the
definition of a business are accounted for as an asset acquisition. The purchase price of each asset acquisition is allocated based on the
relative fair value of assets acquired.
Determining the fair value of assets acquired and liabilities assumed requires management judgment and management may engage
independent valuation experts to assist in this process. Fair values are determined by using market participant assumptions and typically
include the timing and amounts of future cash flows, incurred construction costs, the nature of acquired contracts, discount rates, power
76
Southern Company 2023 Annual Report Notes to Financial Statements
market prices, and expected asset lives. For potential or successful acquisitions that meet the definition of a business, any due diligence or
transaction costs incurred are expensed as incurred. If the acquisition is an asset acquisition, direct and incremental transaction costs can be
capitalized as a component of the cost of the assets acquired.
Historically, any contingent consideration relates to fixed amounts due to the seller once an acquired construction project is placed in
service. For contingent consideration with variable payments, management fair values the arrangement with any changes recorded in the
statements of income. See Note 13 for additional fair value information.
Development Costs
For Southern Power, development costs are capitalized once a project is probable of completion, primarily based on a review of its economics
and operational feasibility, as well as the status of power off-take agreements and regulatory approvals, if applicable. Southern Power's
capitalized development costs are included in CWIP on the balance sheets. All of Southern Power's development costs incurred prior to the
determination that a project is probable of completion are expensed as incurred and included in other operations and maintenance expense
in the statements of income. If it is determined that a project is no longer probable of completion, any of Southern Power's capitalized
development costs are expensed and included in other operations and maintenance expense in the statements of income.
Long-Term Service Agreements
The traditional electric operating companies and Southern Power have entered into LTSAs for the purpose of securing maintenance support
for certain of their generating facilities. The LTSAs cover all planned inspections on the covered equipment, which generally includes the
cost of all labor and materials. The LTSAs also obligate the counterparties to cover the costs of unplanned maintenance on the covered
equipment subject to limits and scope specified in each contract.
Payments made under the LTSAs for the performance of any planned inspections or unplanned capital maintenance are recorded in the
statements of cash flows as investing activities. Receipts of major parts into materials and supplies inventory prior to planned inspections
are treated as noncash transactions in the statements of cash flows. Any payments made prior to the work being performed are recorded
as prepayments in other current assets and noncurrent assets on the balance sheets. At the time work is performed, an appropriate amount
is accrued for future payments or transferred from the prepayment and recorded as property, plant, and equipment or expensed.
Transmission Receivables/Prepayments
As a result of Southern Power's acquisition and construction of generating facilities, Southern Power has transmission receivables and/or
prepayments representing the portion of interconnection network and transmission upgrades that will be reimbursed to Southern Power.
Upon completion of the related project, transmission costs are generally reimbursed by the interconnection provider within a five-year
period and the receivable/prepayments are reduced as payments or services are received.
Cash, Cash Equivalents, and Restricted Cash
For purposes of the financial statements, temporary cash investments are considered cash equivalents. Temporary cash investments are
securities with original maturities of 90 days or less.
77
Southern Company 2023 Annual Report Notes to Financial Statements
The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the balance sheets that total to
the amount shown in the statements of cash flows for the applicable Registrants:
At December 31, 2023
Cash and cash equivalents
Restricted cash(a):
Other current assets
Other deferred charges and assets
Total cash, cash equivalents, and restricted cash(b)
At December 31, 2022
Cash and cash equivalents
Restricted cash(a):
Other current assets
Other deferred charges and assets
Total cash, cash equivalents, and restricted cash(b)
Southern
Company
Alabama
Power
Georgia
Power
Southern
Power
Southern
Company Gas
(in millions)
$ 748
$324
$ 9
$124
141
31
$ 921
85
—
$409
37
29
$ 75
17
3
$144
$1,917
$687
$364
$131
62
58
$2,037
—
—
$687
60
56
$480
—
3
$133
$33
2
—
$35
$81
2
—
$83
(a) For Alabama Power, reflects proceeds from the issuance of solid waste disposal facility revenue bonds in 2023. For Georgia Power, reflects proceeds from
the issuance of solid waste disposal facility revenue bonds in 2022. See Note 8 under “Long-term Debt“ for additional information. For Southern Power,
reflects $17 million at December 31, 2023 resulting from an arbitration award held to fund future replacement costs and $3 million at both December 31,
2023 and 2022 held to fund estimated construction completion costs at the Deuel Harvest wind facility. See Note 3 under “General Litigation Matters –
Southern Power“ and Note 15 under “Southern Power“ for additional information. For Southern Company Gas, reflects collateral for workers' compensation,
life insurance, and long-term disability insurance.
(b) Total may not add due to rounding.
Storm Damage and Reliability Reserves
In accordance with their respective state PSC orders, the traditional electric operating companies accrue certain amounts annually related
to storm damage recovery. Each traditional electric operating company maintains a reserve to cover or is allowed to defer and recover the
cost of damages from major storms to its transmission and distribution lines and, for Mississippi Power, the cost of uninsured damages to
its generation facilities and other property. Alabama Power also has authority from the Alabama PSC to accrue certain additional amounts
as circumstances warrant. Alabama Power recorded an additional accrual of $65 million in 2021.
Storm damage reserve activity for the traditional electric operating companies during 2023 was as follows:
Balance at December 31, 2022
Accrual
Weather-related damages
Balance at December 31, 2023
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
$216
61
(211)
$ 66
(in millions)
$ 97
18
(39)
$ 76
$ 83
31
(168)
$ (54)
$ 36
12
(4)
$ 44
The traditional electric operating companies accrued the following amounts related to storm damage recovery in 2022 and 2021:
2022
2021
Southern
Company(a)(b)
Alabama
Power(a)
Georgia
Power
Mississippi
Power(b)
$ 239
286
(in millions)
$ 19
75
$ 213
213
$ 7
(2)
(a) Alabama Power's 2021 amount includes the $65 million additional accrual discussed above.
(b) Mississippi Power's net accrual includes carrying costs, as well as amortization of related excess deferred income tax benefits.
In 2022, costs for weather-related damages charged against storm damage reserves totaled $24 million and $82 million for Alabama Power
and Georgia Power, respectively, and were immaterial for Mississippi Power.
See Note 2 under “Alabama Power – Rate NDR,“ “Georgia Power – Storm Damage Recovery,“ and “Mississippi Power – System Restoration
Rider“ for additional information regarding each company's storm damage reserve.
78
Southern Company 2023 Annual Report Notes to Financial Statements
During 2022, the Alabama PSC and the Mississippi PSC authorized Alabama Power and Mississippi Power, respectively, to make accruals
to a reliability reserve if certain conditions are met. During 2023 and 2022, Alabama Power and Mississippi Power accrued the following
amounts to their reliability reserves:
2023
2022
Southern
Company
$ 63
191
Alabama
Power
(in millions)
$ 52
166
Mississippi
Power
$ 11
25
See Note 2 under “Alabama Power – Reliability Reserve Accounting Order“ and “Mississippi Power – Reliability Reserve Accounting Order“
for additional information.
Materials and Supplies
Materials and supplies for the traditional electric operating companies generally includes the average cost of transmission, distribution, and
generating plant materials. Materials and supplies for Southern Company Gas generally includes propane gas inventory, liquefied natural
gas inventory, fleet fuel, and other materials and supplies. Materials and supplies for Southern Power generally includes the average cost of
generating plant materials.
Materials are recorded to inventory when purchased and then expensed or capitalized to property, plant, and equipment, as appropriate, at
weighted average cost when installed. In addition, certain major parts are recorded as inventory when acquired and then capitalized at cost
when installed to property, plant, and equipment.
Fuel Inventory
Fuel inventory for the traditional electric operating companies includes the average cost of coal, natural gas, oil, transportation, and
emissions allowances. Fuel inventory for Southern Power, which is included in other current assets, includes the average cost of oil, natural
gas, and emissions allowances. Fuel is recorded to inventory when purchased and then expensed, at weighted average cost, as used.
Emissions allowances granted by the EPA are included in inventory at zero cost. The traditional electric operating companies recover fuel
expense through fuel cost recovery rates approved by each state PSC or, for wholesale rates, the FERC.
Natural Gas for Sale
With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a weighted average cost of gas basis.
In Georgia's deregulated, competitive environment, Marketers sell natural gas to firm end-use customers at market-based prices. On a
monthly basis, Atlanta Gas Light assigns to Marketers the majority of the pipeline storage services that it has under contract, along with a
corresponding amount of inventory. Atlanta Gas Light retains and manages a portion of its pipeline storage assets and related natural gas
inventories for system balancing and to serve system demand.
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. The cost of natural gas,
including inventory costs, is recovered from customers under a purchased gas recovery mechanism adjusted for differences between
actual costs and amounts billed; therefore, LIFO liquidations have no impact on Southern Company's or Southern Company Gas' net
income. At December 31, 2023, the Nicor Gas LIFO inventory balance was $186 million. Based on the average cost of gas purchased in
December 2023, the estimated replacement cost of Nicor Gas' inventory at December 31, 2023 was $268 million.
Provision for Uncollectible Accounts
The customers of the traditional electric operating companies and the natural gas distribution utilities are billed monthly. For the majority
of receivables, a provision for uncollectible accounts is established based on historical collection experience and other factors. For the
remaining receivables, if the company is aware of a specific customer's inability to pay, a provision for uncollectible accounts is recorded
to reduce the receivable balance to the amount reasonably expected to be collected. If circumstances change, the estimate of the
recoverability of accounts receivable could change as well. Circumstances that could affect this estimate include, but are not limited to,
customer credit issues, customer deposits, and general economic conditions. Customers' accounts are written off once they are deemed to
be uncollectible. For all periods presented, uncollectible accounts averaged less than 1% of revenues for each Registrant.
Credit risk exposure at Nicor Gas is mitigated by a bad debt rider approved by the Illinois Commission. The bad debt rider provides for
the recovery from (or refund to) customers of the difference between Nicor Gas' actual bad debt experience on an annual basis and the
benchmark bad debt expense used to establish its base rates for the respective year.
79
Southern Company 2023 Annual Report Notes to Financial Statements
Concentration of Credit Risk
Concentration of credit risk occurs at Atlanta Gas Light for amounts billed for services and other costs to its customers, which consist of
13 Marketers in Georgia (including SouthStar). The credit risk exposure to the Marketers varies seasonally, with the lowest exposure in the
non-peak summer months and the highest exposure in the peak winter months. Marketers are responsible for the retail sale of natural
gas to end-use customers in Georgia. The functions of the retail sale of gas include the purchase and sale of natural gas, customer service,
billings, and collections. The provisions of Atlanta Gas Light's tariff allow Atlanta Gas Light to obtain credit security support in an amount
equal to a minimum of two times a Marketer's highest month's estimated bill from Atlanta Gas Light.
Financial Instruments
The traditional electric operating companies and Southern Power use derivative financial instruments to limit exposure to fluctuations
in interest rates, the prices of certain fuel purchases, electricity purchases and sales, and occasionally foreign currency exchange rates.
Southern Company Gas uses derivative financial instruments to limit exposure to fluctuations in natural gas prices, weather, interest rates,
and commodity prices. All derivative financial instruments are recognized as either assets or liabilities on the balance sheets (included
in “Other“ or shown separately as “Risk Management Activities“) and are measured at fair value. See Note 13 for additional information
regarding fair value. Substantially all of the traditional electric operating companies' and Southern Power's bulk energy purchases and
sales contracts that meet the definition of a derivative are excluded from fair value accounting requirements because they qualify for
the “normal“ scope exception, and are accounted for under the accrual method. Derivative contracts that qualify as cash flow hedges of
anticipated transactions or are recoverable through the traditional electric operating companies' and the natural gas distribution utilities'
fuel-hedging programs result in the deferral of related gains and losses in AOCI or regulatory assets and liabilities, respectively, until the
hedged transactions occur. Other derivative contracts that qualify as fair value hedges are marked to market through current period income
and are recorded on a net basis in the statements of income. Cash flows from derivatives are classified on the statements of cash flows in
the same category as the hedged item. See Note 14 for additional information regarding derivatives.
The Registrants offset fair value amounts recognized for multiple derivative instruments executed with the same counterparty under
netting arrangements. The Registrants had no outstanding collateral repayment obligations or rights to reclaim collateral arising from
derivative instruments recognized at December 31, 2023.
The Registrants are exposed to potential losses related to financial instruments in the event of counterparties' nonperformance.
The Registrants have established risk management policies and controls to determine and monitor the creditworthiness of counterparties
in order to mitigate their exposure to counterparty credit risk.
Southern Company Gas
Southern Company Gas enters into weather derivative contracts as economic hedges of natural gas revenues in the event of warmer-than-
normal weather in the Heating Season. Exchange-traded options are carried at fair value, with changes reflected in natural gas revenues.
Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded
contracts are also reflected in natural gas revenues in the statements of income.
Southern Company Gas enters into transactions to secure transportation capacity between delivery points in order to serve its customers
and various markets. NYMEX futures and OTC contracts are used to capture the price differential or spread between the locations served
by the capacity to substantially protect the natural gas revenues that will ultimately be realized when the physical flow of natural
gas between delivery points occurs. These contracts generally meet the definition of derivatives and are carried at fair value on the
balance sheets, with changes in fair value included in earnings in the period of change. These contracts are not designated as hedges for
accounting purposes.
The purchase, transportation, storage, and sale of natural gas are accounted for on a weighted average cost or accrual basis, as appropriate,
rather than on the fair value basis utilized for the derivatives used to mitigate the natural gas price risk associated with the storage and
transportation portfolio. Monthly demand charges are incurred for the contracted storage and transportation capacity and payments
associated with asset management agreements, and these demand charges and payments are recognized on the statements of income in
the period they are incurred. This difference in accounting methods can result in volatility in reported earnings, even though the economic
margin is substantially unchanged from the dates the transactions were consummated.
Comprehensive Income
The objective of comprehensive income is to report a measure of all changes in common stock equity of an enterprise that result from
transactions and other economic events of the period other than transactions with owners. Comprehensive income consists of net income
attributable to the Registrant, changes in the fair value of qualifying cash flow hedges, and reclassifications for amounts included in net
income. Comprehensive income also consists of certain changes in pension and other postretirement benefit plans for Southern Company,
Southern Power, and Southern Company Gas.
80
Southern Company 2023 Annual Report Notes to Financial Statements
AOCI (loss) balances, net of tax effects, for Southern Company, Southern Power, and Southern Company Gas were as follows:
Southern Company
Balance at December 31, 2022
Current period change
Balance at December 31, 2023
Southern Power
Balance at December 31, 2022
Current period change
Balance at December 31, 2023
Southern Company Gas
Balance at December 31, 2022
Current period change
Balance at December 31, 2023
(*) May not add due to rounding.
Variable Interest Entities
Qualifying
Hedges
$ (149)
28
$(121)
$
$
(9)
8
(1)
$ (25)
1
$ (24)
Pension and
Other
Postretirement
Benefit Plans
(in millions)
Accumulated
Other
Comprehensive
Income (Loss)(*)
$ (18)
(38)
$ (56)
$
(9)
(7)
$ (16)
$ 56
(16)
$ 40
$(167)
(10)
$(177)
$ (18)
1
$ (17)
$ 31
(15)
$ 16
The Registrants may hold ownership interests in a number of business ventures with varying ownership structures. Partnership interests
and other variable interests are evaluated to determine if each entity is a VIE. The primary beneficiary of a VIE is required to consolidate
the VIE when it has both the power to direct the activities of the VIE that most significantly impact the VIE's economic performance and
the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. See Note 7 for
additional information regarding VIEs.
81
Southern Company 2023 Annual Report Notes to Financial Statements
2. REGULATORY MATTERS
Regulatory Assets and Liabilities
Details of regulatory assets and (liabilities) reflected in the balance sheets at December 31, 2023 and 2022 are provided in the following tables:
Southern
Company
Alabama
Power
Georgia
Power
(in millions)
Mississippi
Power
Southern
Company Gas
At December 31, 2023
AROs(a)(w)
Retiree benefit plans(b)(w)
Remaining net book value of retired assets(c)
Deferred income tax charges(d)
Under recovered regulatory clause revenues(e)
Fuel-hedging (realized and unrealized) losses(f)
Deferred depreciation(g)
Environmental remediation(h)(w)
Loss on reacquired debt(i)
Vacation pay(j)(w)
Software and cloud computing costs(k)
Regulatory clauses(l)
Storm damage(m)
Nuclear outage(n)
Long-term debt fair value adjustment(o)
Qualifying repairs of natural gas distribution systems(p)
Plant Daniel Units 3 and 4(q)
Kemper County energy facility assets, net(r)
Other regulatory assets(s)
Deferred income tax credits(d)
Other cost of removal obligations(a)
Over recovered regulatory clause revenues(e)
Reliability reserves(t)
Storm/property damage reserves(t)
Customer refunds(u)
Fuel-hedging (realized and unrealized) gains(f)
Other regulatory liabilities(v)
Total regulatory assets (liabilities), net
At December 31, 2022
AROs(a)(w)
Retiree benefit plans(b)(w)
Remaining net book value of retired assets(c)
Under recovered regulatory clause revenues(e)
Deferred income tax charges(d)
Environmental remediation(h)(w)
Loss on reacquired debt(i)
Vacation pay(j)(w)
Regulatory clauses(l)
Software and cloud computing costs(k)
Nuclear outage(n)
Long-term debt fair value adjustment(o)
Fuel-hedging (realized and unrealized) losses(f)
Storm damage(m)
Plant Daniel Units 3 and 4(q)
Qualifying repairs of natural gas distribution systems(p)
Kemper County energy facility assets, net(r)
Other regulatory assets(s)
Deferred income tax credits(d)
Other cost of removal obligations(a)
Storm/property damage reserves(t)
Reliability reserves(t)
Customer refunds(u)
Fuel-hedging (realized and unrealized) gains(f)
Over recovered regulatory clause revenues(e)
Other regulatory liabilities(v)
Total regulatory assets (liabilities), net
82
$ 5,733
3,011
1,357
897
413
270
270
255
238
217
150
140
92
83
60
40
25
7
182
(4,686)
(1,312)
(287)
(179)
(120)
(19)
(6)
(308)
$ 6,523
$ 6,096
2,517
1,543
953
866
294
257
212
142
111
82
69
60
44
27
26
20
171
(5,251)
(1,430)
(216)
(191)
(183)
(83)
(64)
(239)
$ 5,833
$ 1,936
815
499
262
381
100
143
—
35
83
59
112
—
50
—
—
—
—
39
(1,506)
28
(3)
(143)
(76)
(15)
(5)
(74)
$ 2,720
$ 1,971
675
562
788
250
—
38
82
142
46
52
—
15
—
—
—
—
36
(1,925)
11
(97)
(166)
(62)
(38)
—
(40)
$ 2,340
$ 3,505
976
841
605
—
121
127
20
197
107
84
—
54
33
—
—
—
—
33
(2,161)
617
(46)
—
—
(4)
(1)
(18)
$ 5,090
$ 3,829
848
962
—
583
25
213
108
—
59
30
—
45
—
—
—
—
27
(2,244)
462
(83)
—
(121)
(21)
(38)
(21)
$ 4,663
$ 247
140
17
28
12
49
—
—
5
11
2
—
38
—
—
—
25
7
18
(241)
(186)
—
(36)
(44)
—
(2)
$ 90
$ 242
113
19
31
30
—
5
10
—
—
—
—
—
44
27
—
20
16
(269)
(196)
(36)
(25)
—
(24)
—
(3)
4
$
$
—
146
—
—
20
—
—
235
1
16
5
28
—
—
60
40
—
—
93
(759)
(1,771)
(238)
—
—
—
—
(101)
$ (2,225)
$
—
114
—
134
—
269
1
12
—
6
—
69
—
—
—
26
—
92
(788)
(1,707)
—
—
—
—
(26)
(93)
$ (1,891)
Southern Company 2023 Annual Report Notes to Financial Statements
Unless otherwise noted, the following recovery and amortization periods for these regulatory assets and (liabilities) have been approved by the respective
state PSC or regulatory agency:
(a) AROs and other cost of removal obligations generally are recorded over the related property lives, which may range up to 64 years for Alabama Power,
56 years for Georgia Power, 55 years for Mississippi Power, and 85 years for Southern Company Gas. AROs and cost of removal obligations are settled and
trued up following completion of the related activities. Alabama Power is recovering CCR ARO expenditures over a 38-year period ending in 2054 through
Rate CNP Compliance. Effective January 1, 2023, Georgia Power is recovering CCR ARO expenditures over four-year periods through its ECCR tariff. Prior to
2023, expenditures were recovered over three-year periods. See “Georgia Power – Rate Plans“ herein and Note 6 for additional information.
(b) Recovered and amortized over the average remaining service period, which may range up to 13 years for Alabama Power and Mississippi Power and up
to 14 years for Georgia Power and Southern Company Gas. Southern Company's balances also include amounts at SCS and Southern Nuclear that are
allocated to the applicable regulated utilities. See Note 11 for additional information.
(c) Alabama Power: Primarily represents the net book value of Plant Gorgas Unit 10 ($451 million at December 31, 2023) being amortized over 14 years (through
2037) and Plant Barry Unit 4 ($39 million at December 31, 2023) being amortized over 11 years (through 2034). See “Alabama Power – Environmental
Accounting Order“ herein for additional information.
Georgia Power: Net book values of Plant Wansley Units 1 and 2, Plant Hammond Units 1 through 4, and Plant Branch Unit 4 (totaling $488 million,
$339 million, and $8 million, respectively, at December 31, 2023) are being amortized over remaining periods between one and 12 years (between 2024
and 2035). Balance also includes unusable materials and supplies inventories, for which the Georgia PSC will determine a recovery period in a future base
rate case.
Mississippi Power: Represents net book value of certain environmental compliance assets at Plant Watson and Plant Greene County. The retail portion is
being amortized over a 10-year period through 2030 and the wholesale portion is being amortized over a 14-year period through 2035. See “Mississippi
Power – Environmental Compliance Overview Plan“ herein for additional information.
(d) Deferred income tax charges are recovered and deferred income tax credits are primarily amortized over the related property lives, which may range up
to 64 years for Alabama Power, 56 years for Georgia Power, 55 years for Mississippi Power, and 85 years for Southern Company Gas. See Note 10 for
additional information. As a result of the Tax Reform Legislation, these accounts include certain deferred income tax assets and liabilities not subject to
normalization, as described further below:
Alabama Power: Related amounts at December 31, 2023 include excess federal deferred income tax liabilities that are available for the benefit of customers
in 2024 and/or 2025, as discussed under “Alabama Power – Excess Accumulated Deferred Income Tax Accounting Order“ herein. Remaining amounts are
being recovered and amortized ratably over the related property lives.
Georgia Power: Related amounts include $145 million of deferred income tax assets related to construction costs for Plant Vogtle Units 3 and 4 to be
recovered over a 10-year period beginning the month after Unit 4 achieves commercial operation. See “Georgia Power – Nuclear Construction – Regulatory
Matters“ herein for additional information on recovery of costs related to Plant Vogtle Units 3 and 4.
Mississippi Power: Related amounts include retail deferred income tax liabilities ($11 million at December 31, 2023) that are expected to be fully amortized
through 2024.
Southern Company Gas: Related amounts include deferred income tax liabilities ($1 million at December 31, 2023) being amortized through 2024.
See “Southern Company Gas – Rate Proceedings“ herein for additional information.
(e) Alabama Power: Balances are recorded monthly and expected to be recovered over periods of up to seven years, with the majority expected to be
recovered within one year. See “Alabama Power – Rate CNP PPA,“ “ – Rate CNP Compliance,“ and “ – Rate ECR“ herein for additional information.
Georgia Power: Balances are recorded monthly and expected to be recovered or returned within two years. See “Georgia Power – Rate Plans“ herein for
additional information.
Mississippi Power: At December 31, 2023, $12 million is expected to be recovered through various rate recovery mechanisms over a period to be
determined in future rate filings. See “Mississippi Power – Ad Valorem Tax Adjustment“ herein for additional information.
Southern Company Gas: Balances are recorded and recovered or amortized over periods generally not exceeding five years. In addition to natural gas cost
recovery mechanisms, the natural gas distribution utilities have various other cost recovery mechanisms for the recovery of costs, including those related to
infrastructure replacement programs.
(f) Fuel-hedging assets and liabilities are recorded over the life of the underlying hedged purchase contracts. Upon final settlement, actual costs incurred are
recovered through the applicable traditional electric operating company's fuel cost recovery mechanism. Purchase contracts generally do not exceed three
and a half years for Alabama Power, three years for Georgia Power, and four years for Mississippi Power.
(g) Alabama Power: Represents deferred depreciation expense for Plant Barry Unit 5 ($57 million at December 31, 2023) and Plant Barry common coal
assets ($24 million at December 31, 2023) to be amortized until 2036 beginning when Plant Barry Unit 5 is retired and Plant Gaston Unit 5 coal assets
($62 million at December 31, 2023) to be amortized until 2039 beginning when the assets are retired.
Georgia Power: Represents deferred depreciation expense for Plant Scherer Units 1 through 3 ($70 million at December 31, 2023) to be amortized over
six years beginning in 2029 and Plant Bowen Units 1 and 2 ($40 million at December 31, 2023) to be amortized over four years beginning in 2031, both
as approved under Georgia Power's 2022 ARP, and Plant Vogtle Unit 3 and common facilities ($17 million at December 31, 2023) to be amortized over a
10-year period beginning the month after Plant Vogtle Unit 4 achieves commercial operation. See “Georgia Power – Nuclear Construction – Regulatory
Matters“ herein for additional information on recovery of costs related to Plant Vogtle Units 3 and 4.
(h) Effective January 1, 2023, Georgia Power is recovering $5 million annually for environmental remediation under the 2022 ARP. Southern Company
Gas' costs are recovered through environmental cost recovery mechanisms when the remediation work is performed. See Note 3 under “Environmental
Remediation“ for additional information.
(i) Recovered over either the remaining life of the original issue or, if refinanced, over the remaining life of the new issue. At December 31, 2023, the remaining
amortization periods do not exceed 24 years for Alabama Power, 29 years for Georgia Power, 18 years for Mississippi Power, and four years for Southern
Company Gas.
(j) Recorded as earned by employees and recovered as paid, generally within one year. Includes both vacation and banked holiday pay, if applicable.
(k) Represents certain deferred operations and maintenance costs associated with software and cloud computing projects. For Alabama Power, costs are
amortized ratably over the life of the related software, which ranges up to 10 years (through 2034). See “Alabama Power – Software Accounting Order“
83
Southern Company 2023 Annual Report Notes to Financial Statements
herein for additional information. For Georgia Power, costs incurred through 2022 are being amortized over five years (through 2027) and the recovery
period for costs incurred after 2022 will be determined in its next base rate case. For Mississippi Power, the recovery period will be determined in
Mississippi Power's annual PEP filing process. For Southern Company Gas, costs are being amortized ratably over the life of the related software, which
ranges up to 10 years (through 2034).
(l) Alabama Power: Effective January 1, 2023, balance is being amortized through Rate RSE over a five-year period ending in 2027.
Southern Company Gas: Represents amounts related to Nicor Gas' volume balancing adjustment rider expected to be recovered over a period of less than
two years.
(m) See “Georgia Power – Storm Damage Recovery“ herein and Note 1 under “Storm Damage and Reliability Reserves“ for additional information. Mississippi
Power's balance represents deferred storm costs associated with Hurricanes Ida and Zeta being recovered through PEP over a seven-year period
through 2029.
(n) Nuclear outage costs are deferred to a regulatory asset when incurred and amortized over a subsequent period of 18 months for Alabama Power and up to
24 months for Georgia Power. See Note 5 for additional information.
(o) Recovered over the remaining lives of the original debt issuances at acquisition, which range up to 15 years at December 31, 2023.
(p) Represents deferred costs of certain repairs at Atlanta Gas Light being amortized over 20 years.
(q) Represents the difference between Mississippi Power's revenue requirement for Plant Daniel Units 3 and 4 under purchase accounting and operating lease
accounting. At December 31, 2023, consists of the $17 million retail portion being amortized through 2039 over the remaining life of the related property
and the $8 million wholesale portion being amortized through 2035.
(r) At December 31, 2023, includes $9 million of regulatory assets (wholesale) expected to be fully amortized by 2035 and $2 million of regulatory liabilities
(retail) expected to be fully amortized by 2024.
(s) Comprised of numerous immaterial components with remaining amortization periods at December 31, 2023 generally not exceeding 20 years for Alabama
Power, 10 years for Georgia Power, 14 years for Mississippi Power, and 15 years for Southern Company Gas.
(t) Utilized as related expenses are incurred. See “Alabama Power – Rate NDR“ and “ – Reliability Reserve Accounting Order,“ “Georgia Power – Storm Damage
Recovery,“ and “Mississippi Power – System Restoration Rider“ and “ – Reliability Reserve Accounting Order“ herein and Note 1 under “Storm Damage and
Reliability Reserves“ for additional information.
(u) Primarily includes approximately $15 million and $62 million at December 31, 2023 and 2022, respectively, for Alabama Power and $119 million at
December 31, 2022 for Georgia Power as a result of each company exceeding its allowed retail return range. Georgia Power's balances also include
immaterial amounts related to refunds for transmission service customers. See “Alabama Power – Rate RSE“ and “Georgia Power – Rate Plans“ herein for
additional information.
(v) Comprised of numerous immaterial components with remaining amortization periods at December 31, 2023 generally not exceeding 11 years for Alabama
Power, nine years for Georgia Power, four years for Mississippi Power, and 20 years for Southern Company Gas.
(w) Generally not earning a return as they are excluded from rate base or are offset in rate base by a corresponding asset or liability.
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.
Renewable Generation Certificate
Through the issuance of a Renewable Generation Certificate (RGC), Alabama Power is authorized by the Alabama PSC to procure renewable
capacity and energy and to market the related energy and environmental attributes to customers and other third parties. On April 4,
2023, the Alabama PSC approved two new solar PPAs totaling 160 MWs. Upon approval of these PPAs, Alabama Power had procured solar
capacity totaling approximately 490 MWs under the RGC's original 500-MW limit.
On June 14, 2023, the Alabama PSC issued an order approving modifications to Alabama Power's RGC. The modifications authorized
Alabama Power to procure an additional 2,400 MWs of renewable capacity and energy by June 14, 2029 and to market the related energy
and environmental attributes to customers and other third parties. The modifications also increased the size of allowable renewable projects
from 80 MWs to 200 MWs and increased the annual approval limit from 160 MWs to 400 MWs.
Rate RSE
The Alabama PSC has adopted Rate RSE that provides for periodic annual adjustments based upon Alabama Power's projected weighted
common equity return (WCER) compared to an allowable range. Rate RSE adjustments are based on forward-looking information for the
applicable upcoming calendar year. Rate RSE adjustments for any two-year period, when averaged together, cannot exceed 4.0% and any
annual adjustment is limited to 5.0%. When the projected WCER is under the allowed range, there is an adjusting point of 5.98% and eligibility
for a performance-based adder of seven basis points, or 0.07%, to the WCER adjusting point if Alabama Power (i) has an “A“ credit rating
equivalent with at least one of the recognized rating agencies or (ii) is in the top one-third of a designated customer value benchmark survey.
Alabama Power continues to reduce growth in total debt by increasing equity, with corresponding reductions in debt issuances, thereby
de-leveraging its capital structure. Alabama Power's goal is to achieve an equity ratio of approximately 55% by the end of 2025.
At December 31, 2023 and 2022, Alabama Power's equity ratio was approximately 52.3% and 52.2%, respectively.
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Southern Company 2023 Annual Report Notes to Financial Statements
Generally, during a year without a Rate RSE upward adjustment, if Alabama Power's actual WCER is between 6.15% and 7.65%,
customers will receive 25% of the amount between 6.15% and 6.65%, 40% of the amount between 6.65% and 7.15%, and 75% of the
amount between 7.15% and 7.65%. Customers will receive all amounts in excess of an actual WCER of 7.65%. During a year with a Rate
RSE upward adjustment, if Alabama Power's actual WCER exceeds 6.15%, customers receive 50% of the amount between 6.15% and
6.90% and all amounts in excess of an actual WCER of 6.90%. Alabama Power's ability to retain a portion of the revenue that causes the
actual WCER for a given year to exceed the allowed range positions Alabama Power to address the pressure on its credit quality, without
increasing retail rates under Rate RSE in the near term. There is no provision for additional customer billings should the actual retail return
fall below the WCER range.
Retail rates under Rate RSE did not change for 2022 or 2023.
For the years ended December 31, 2021, 2022, and 2023, Alabama Power's WCER exceeded 6.15%, resulting in Alabama Power
establishing a current regulatory liability of $181 million, $62 million, and $15 million, respectively, for Rate RSE refunds. In accordance
with an Alabama PSC order issued in February 2022, Alabama Power applied $126 million of the 2021 refund to reduce the Rate ECR
under recovered balance and the remaining $55 million was refunded to customers through bill credits in July 2022. In accordance
with an Alabama PSC order issued on February 7, 2023, Alabama Power refunded the 2022 amount to customers through bill credits in
August 2023. The $15 million regulatory liability at December 31, 2023 will be refunded to customers through bill credits in April 2024.
On December 1, 2023, Alabama Power made its required annual Rate RSE submission to the Alabama PSC of projected data for calendar
year 2024. Projected earnings were within the specified range; therefore, retail rates under Rate RSE remain unchanged for 2024.
Excess Accumulated Deferred Income Tax Accounting Order
In December 2022, the Alabama PSC directed Alabama Power to accelerate the amortization of a regulatory liability associated with excess
federal accumulated deferred income taxes. Under this order, in 2023, approximately $304 million was returned to customers through bill
credits to offset the impact of the rate increase discussed under “Rate CNP Depreciation“ herein.
On October 3, 2023, the Alabama PSC issued an order modifying its December 2022 order and authorizing Alabama Power to (i) flow back in
2023 approximately $24 million of certain federal excess accumulated deferred income taxes resulting from the Tax Cuts and Jobs Act of 2017
and (ii) make available any remaining balance of excess accumulated deferred income taxes at the end of 2023 for the benefit of customers
in 2024 and/or 2025. At December 31, 2023, the remaining balance was $81 million, of which approximately $67 million and $14 million will
flow back in 2024 and 2025, respectively, for the benefit of customers.
Rate CNP New Plant
Rate CNP New Plant allows for recovery of Alabama Power's retail costs associated with newly developed or acquired certificated
generating facilities placed into retail service. No adjustments to Rate CNP New Plant occurred during the period January 2021 through
October 2022.
In July 2022, the Alabama PSC approved a CCN authorizing Alabama Power to complete the acquisition of the Calhoun Generating Station.
The transaction closed in September 2022 and, in October 2022, Alabama Power filed Rate CNP New Plant with the Alabama PSC to
recover the related costs. The filing reflected an increase in annual revenues of $34 million, or 0.6%, effective with November 2022 billings.
In 2020, the Alabama PSC approved a CCN authorizing Alabama Power to complete the acquisition of the Central Alabama Generating
Station, which occurred in August 2020. Through May 2023, Alabama Power recovered substantially all costs associated with the Central
Alabama Generating Station through Rate RSE, offset by revenues from a power sales agreement. Beginning in July 2022, fuel costs
associated with Central Alabama Generating Station are being recovered through Rate ECR. On March 24, 2023, Alabama Power filed
Rate CNP New Plant with the Alabama PSC to recover costs associated with the acquisition of the Central Alabama Generating Station.
The filing reflected an annual increase in retail revenues of $78 million, or 1.1%, effective with June 2023 billings. On May 24, 2023, the
Central Alabama Generating Station was placed into retail service.
The Alabama PSC's 2020 CCN also authorized Alabama Power to construct an approximately 720-MW combined cycle facility at Alabama
Power's Plant Barry (Plant Barry Unit 8) and the recovery of estimated in-service costs. On November 1, 2023, the unit was placed in
service. On December 1, 2023, Alabama Power filed Rate CNP New Plant with the Alabama PSC to recover the related costs. The filing
reflected an annual increase in retail revenues of $91 million, or 1.4%, effective with January 2024 billings.
Rate CNP PPA
Rate CNP PPA allows for the recovery of Alabama Power's retail costs associated with certificated PPAs. Revenues for Rate CNP PPA, as
recorded on the financial statements, are adjusted for differences in actual recoverable costs and amounts billed in current regulated rates.
Accordingly, changes in the billing factors will have no significant effect on Southern Company's or Alabama Power's revenues or net income
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Southern Company 2023 Annual Report Notes to Financial Statements
but will affect annual cash flow. No adjustments to Rate CNP PPA occurred during the period 2021 through 2023 and no adjustment is
expected for 2024. At December 31, 2023 and 2022, Alabama Power had an under recovered Rate CNP PPA balance of $103 million and
$120 million, respectively, of which $18 million and $18 million, respectively, is included in other regulatory assets, current and $85 million
and $102 million, respectively, is included in other regulatory assets, deferred on the balance sheet.
Rate CNP Compliance
Rate CNP Compliance allows for the recovery of Alabama Power's retail costs associated with laws, regulations, and other such mandates
directed at the utility industry involving the environment, security, reliability, safety, sustainability, or similar considerations impacting
Alabama Power's facilities or operations. Rate CNP Compliance is based on forward-looking information and provides for the recovery
of these costs pursuant to factors that are calculated and submitted to the Alabama PSC by December 1 with rates effective for the
following calendar year. Compliance costs to be recovered include operations and maintenance expenses, depreciation, and a return on
certain invested capital. Revenues for Rate CNP Compliance, as recorded on the financial statements, are adjusted for differences in actual
recoverable costs and amounts billed in current regulated rates. Accordingly, changes in the billing factors will have no significant effect on
Southern Company's or Alabama Power's revenues or net income, but will affect annual cash flow. Changes in Rate CNP Compliance-related
operations and maintenance expenses and depreciation generally will have no effect on net income.
In November 2021, December 2022, and December 2023, Alabama Power submitted calculations to the Alabama PSC associated with
its cost of complying with governmental mandates for the following calendar year, as provided under Rate CNP Compliance. The 2021
filing reflected a projected under recovered retail revenue requirement of approximately $59 million. In December 2021, the Alabama PSC
issued a consent order that Alabama Power leave the 2021 Rate CNP Compliance factors in effect for 2022, with any prior year under
collected amount deemed recovered before any current year amounts are recovered and any remaining under recovery reflected in the
2022 filing. The 2022 filing reflected a $255 million, or 3.7%, annual increase effective with January 2023 billings, primarily due to updated
depreciation rates. The 2023 filing reflected a $23 million, or 0.3%, annual decrease effective with January 2024 billings.
At December 31, 2023, Alabama Power had an under recovered Rate CNP Compliance balance of $33 million, of which $8 million is
included in other regulatory assets, current and $25 million is included in other regulatory assets, deferred on the balances sheet, compared
to an under recovered balance at December 31, 2022 of $47 million included in other regulatory assets, current on the balance sheet.
Rate CNP Depreciation
In December 2022, the Alabama PSC approved Rate CNP Depreciation, which allows Alabama Power to recover changes in depreciation
resulting from updates to certain depreciation rates, excluding any depreciation recovered through Rate CNP New Plant, Rate CNP
Compliance, or costs associated with the capitalization of asset retirement costs. Rate CNP Depreciation resulted in an annual revenue
increase of approximately $318 million, or 4.6%, effective with January 2023 billings. See “Excess Accumulated Deferred Income Tax
Accounting Order“ herein for information related to 2023 customer bill credits approved by the Alabama PSC.
Rate ECR
Rate ECR recovers Alabama Power's retail energy costs based on an estimate of future energy costs and the current over or under
recovered balance. Revenues recognized under Rate ECR and recorded on the financial statements are adjusted for the difference in actual
recoverable fuel costs and amounts billed in current regulated rates. The difference in the recoverable fuel costs and amounts billed gives
rise to the over or under recovered amounts recorded as regulatory assets or liabilities. Alabama Power, along with the Alabama PSC,
continually monitors the over or under recovered cost balance to determine whether an adjustment to billing rates is required. Changes in
the Rate ECR factor have no significant effect on Southern Company's or Alabama Power's net income but will impact the related operating
cash flows. The Alabama PSC may approve billing rates under Rate ECR of up to 5.910 cents per KWH.
The Alabama PSC approved adjustments to Rate ECR from 1.960 cents per KWH to 2.557 cents per KWH, or approximately $310 million
annually, effective with August 2022 billings and from 2.557 cents per KWH to 3.510 cents per KWH, or approximately $500 million
annually, effective with December 2022 billings. On November 9, 2023, the Alabama PSC approved a decrease to Rate ECR from 3.510 cents
per KWH to 3.270 cents per KWH, or approximately $126 million annually, effective with December 2023 billings. The rate will adjust to
5.910 cents per KWH in January 2025 absent a further order from the Alabama PSC.
At December 31, 2023 and 2022, Alabama Power's under recovered fuel costs totaled $246 million and $622 million, respectively, of which
$246 million and $102 million, respectively, is included in regulatory assets – under recovered retail fuel clause revenues and $520 million
of the December 31, 2022 balance is included in other regulatory assets, deferred on the balance sheets. These classifications are based on
estimates, which include such factors as weather, generation availability, energy demand, and the price of energy. A change in any of these
factors could have a significant impact on the timing of any recovery or return of fuel costs.
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Southern Company 2023 Annual Report Notes to Financial Statements
Software Accounting Order
The Alabama PSC authorizes Alabama Power to establish a regulatory asset for operations and maintenance costs associated with software
implementation projects. The regulatory asset is amortized ratably over the life of the related software. At December 31, 2023 and 2022,
the regulatory asset balance totaled $59 million and $46 million, respectively, and is included in other regulatory assets, deferred on the
balance sheet.
Plant Greene County
Alabama Power jointly owns Plant Greene County with an affiliate, Mississippi Power. See Note 5 under “Joint Ownership Agreements“
for additional information. In 2021, the Mississippi PSC concluded its review of Mississippi Power's 2021 IRP, which included a schedule
to retire Mississippi Power's 40% ownership interest in Plant Greene County Units 1 and 2 in December 2025 and 2026, respectively,
consistent with each unit's remaining useful life. Alabama Power and Mississippi Power have continued to evaluate operating conditions
and business needs relevant to the anticipated retirement of Plant Greene County and now expect the units to remain in service beyond
the previously indicated dates. The Plant Greene County unit retirements require the completion by Alabama Power of transmission and
system reliability improvements, as well as agreement by Alabama Power. The ultimate outcome of this matter cannot be determined at
this time. See “Mississippi Power – Integrated Resource Plan“ herein for additional information.
Rate NDR
Based on an order from the Alabama PSC, Alabama Power maintains a reserve for operations and maintenance expenses to cover the
cost of damages from major storms to its transmission and distribution facilities. The order approves a separate monthly Rate NDR
charge to customers consisting of two components. The first component is intended to establish and maintain a reserve balance for
future storms and is an on-going part of customer billing. When the reserve balance falls below $50 million, a reserve establishment
charge will be activated (and the on-going reserve maintenance charge concurrently suspended) until the reserve balance reaches
$75 million.
The second component of the Rate NDR charge is intended to allow recovery of any existing deferred storm-related operations
and maintenance costs and any future reserve deficits over a 48-month period (24-month period prior to modifications approved
by the Alabama PSC in July 2022). The Alabama PSC order gives Alabama Power authority to record a deficit balance in the NDR
when costs of storm damage exceed any established reserve balance. The maximum total Rate NDR charge was limited to $10.00
per month per non-residential customer account and $5.00 per month per residential customer account through July 12, 2022.
Subsequently, modifications approved by the Alabama PSC replaced the maximum total Rate NDR charge with a maximum charge
to recover a deficit of $5 per month per non-residential customer account and $2.50 per month per residential customer account.
Alabama Power has the authority, based on an order from the Alabama PSC, to accrue certain additional amounts as circumstances
warrant, which can be used to offset storm charges. Alabama Power made an additional accrual of $65 million in 2021.
Alabama Power collected approximately $12 million, $14 million, and $6 million in 2023, 2022, and 2021, respectively, under Rate
NDR. Beginning with August 2022 billings, the reserve establishment charge was suspended and the reserve maintenance charge was
activated as a result of the NDR balance exceeding $75 million. Alabama Power expects to collect approximately $12 million annually
under Rate NDR unless the NDR balance falls below $50 million. At December 31, 2023 and 2022, the NDR balance was $76 million
and $97 million, respectively, and is included in other regulatory liabilities, deferred on the balance sheets.
As revenue from the Rate NDR charge is recognized, an equal amount of operations and maintenance expenses related to the NDR will
also be recognized. As a result, the Rate NDR charge will not have an effect on net income but will impact operating cash flows.
Reliability Reserve Accounting Order
In July 2022, the Alabama PSC approved an accounting order authorizing Alabama Power to create a reliability reserve separate from
the NDR and transition the previous Rate NDR authority related to reliability expenditures to the reliability reserve. Alabama Power may
make accruals to the reliability reserve if the NDR balance exceeds $35 million. At December 31, 2023 and 2022, Alabama Power accrued
$52 million and $166 million, respectively, to the reserve.
On July 11, 2023, the Alabama PSC issued an order authorizing Alabama Power to expand the existing authority of its reliability reserve to
include certain production-related expenses that are intended to maintain reliability in between scheduled generating unit maintenance outages.
On August 18, 2023, Alabama Power notified the Alabama PSC of its intent to use a portion of its reliability reserve balance in 2023.
During the fourth quarter 2023, Alabama Power used $75 million of the reliability reserve for reliability-related transmission, distribution,
and generation expenses and nuclear production-related expenses.
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Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2023 and 2022, Alabama Power's reliability reserve balance was $143 million and $166 million, respectively, and is
included in other regulatory liabilities, deferred on the balance sheets.
Environmental Accounting Order
Based on an order from the Alabama PSC (Environmental Accounting Order), Alabama Power is authorized to establish a regulatory asset to
record the unrecovered investment costs, including the unrecovered plant asset balance and the unrecovered costs associated with site removal
and closure associated with future unit retirements caused by environmental regulations. The regulatory asset is amortized and recovered over
the affected unit's remaining useful life, as established prior to the decision regarding early retirement, through Rate CNP Compliance.
With the completion of the Calhoun Generating Station acquisition, Alabama Power expected to retire Plant Barry Unit 5 in late 2023 or early
2024, subject to certain operating conditions. In September 2022, Alabama Power reclassified approximately $600 million for Plant Barry
Unit 5 from plant in service, net of depreciation to other utility plant, net and will continue to depreciate the asset according to the original
depreciation rates. Alabama Power has continued to evaluate operating conditions relevant to the expected retirement of Plant Barry Unit 5
and now expects to retire the unit on or before December 31, 2028. At retirement, Alabama Power will reclassify the remaining net investment
costs of the unit to a regulatory asset to be recovered over the unit's remaining useful life, as established prior to the decision to retire, through
Rate CNP Compliance. See “Rate CNP New Plant“ herein for additional information.
In December 2022, in conjunction with Alabama Power's compliance plan for the EPA's final steam electric ELG reconsideration rule, Plant Barry
Unit 4 ceased using coal and began operating solely on natural gas. As a result, approximately $42 million of plant in service, net of depreciation
was reclassified to a regulatory asset to be recovered through Rate CNP Compliance through 2034, the unit's remaining useful life.
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 recovers its costs from the regulated retail business through traditional base tariffs, Demand-Side Management
(DSM) tariffs, the ECCR tariff, and Municipal Franchise Fee (MFF) tariffs. These tariffs were set under the 2019 ARP for the years 2020 through
2022 and under the 2022 ARP for the years 2023 through 2025 as described herein. In addition, fuel costs are collected through a separate
fuel cost recovery tariff.
See “Nuclear Construction – Regulatory Matters“ herein for information regarding the approved recovery through retail base rates of certain
costs related to Plant Vogtle Unit 3 and the common facilities shared between Plant Vogtle Units 3 and 4 (Common Facilities) that became
effective August 1, 2023 based on the in-service date of July 31, 2023 for Unit 3, as well as the base rate adjustments that will occur the first
day of the month after Unit 4 achieves commercial operation. Financing costs on certified construction costs of Plant Vogtle Units 3 and 4
that are not included in rate base are being collected through Georgia Power's NCCR tariff. When the base rate adjustments occur following
commercial operation of Unit 4, the NCCR tariff will cease to be collected and financing costs will be included in Georgia Power's general retail
revenue requirements. See “Nuclear Construction“ herein for additional information on Plant Vogtle Units 3 and 4.
Rate Plans
2022 ARP
In December 2022, the Georgia PSC voted to approve the 2022 ARP, under which Georgia Power increased its rates on January 1, 2023.
On November 16, 2023, the Georgia PSC approved tariff adjustments effective January 1, 2024. Details of tariff adjustments are provided
in the following table:
Tariff
Traditional base
ECCR
DSM
MFF
Total
2023
2024
(in millions)
$ 194
(21)
37
6
$ 216
$ 275
(99)
10
5
$ 191
Under the 2022 ARP, Georgia Power will adjust traditional base, ECCR, DSM, and MFF rates effective January 1, 2025, with the incremental
revenue requirements related to DSM tariffs and CCR AROs subject to updates through annual compliance filings to be made at least
90 days prior to the effective date.
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Southern Company 2023 Annual Report Notes to Financial Statements
In the 2022 ARP, the Georgia PSC approved recovery through the ECCR tariff of estimated CCR ARO compliance costs for 2023, 2024, and
2025 over four-year periods beginning January 1 of each respective year, with recovery of construction contingency beginning in the year
following actual expenditures, resulting in $60 million and $20 million reductions in the related amortization expense for 2024 and 2023,
respectively. Compliance costs incurred were $300 million in 2023 and are expected to be $305 million and $330 million in 2024 and
2025, respectively. The CCR ARO costs are expected to be revised for actual expenditures and updated estimates through future annual
compliance filings.
Further, under the 2022 ARP, Georgia Power's retail ROE is set at 10.50% and its equity ratio is set at 56%. Earnings will be evaluated against
a retail ROE range of 9.50% to 11.90%. Any retail earnings above 11.90% will be shared, with 40% being applied to reduce regulatory assets,
40% directly refunded to customers, and the remaining 20% retained by Georgia Power. There will be no recovery of any earnings shortfall
below 9.50% on an actual basis. However, if at any time during the term of the 2022 ARP, Georgia Power projects that its retail earnings will
be below 9.50% for any calendar year, it may petition the Georgia PSC for implementation of the Interim Cost Recovery (ICR) tariff to adjust
Georgia Power's retail rates to achieve a 9.50% ROE. The Georgia PSC would have 90 days to rule on Georgia Power's request. The ICR tariff
would expire at the earlier of January 1, 2026 or the end of the calendar year in which the ICR tariff becomes effective. In lieu of requesting
implementation of an ICR tariff, or if the Georgia PSC chooses not to implement the ICR tariff, Georgia Power may file a full rate case.
In 2023, Georgia Power's retail ROE was within the allowed retail ROE range.
Except as provided above, Georgia Power will not file for a general base rate increase while the 2022 ARP is in effect. Georgia Power is
required to file a general base rate case by July 1, 2025, in response to which the Georgia PSC would be expected to determine whether the
2022 ARP should be continued, modified, or discontinued.
2019 ARP
The Georgia PSC approved the following tariff adjustments under the 2019 ARP effective January 1 2022:
Tariff
Traditional base
ECCR
DSM
MFF
Total
2022
(in millions)
$ 192
(12)
(25)
2
$ 157
In the 2019 ARP, the Georgia PSC approved recovery through the ECCR tariff of the estimated under recovered balance of CCR ARO compliance
costs. Under the 2019 ARP, the under recovered balance at December 31, 2019 and compliance costs for 2020 were recovered over the
three-year period ended December 31, 2022. Recovery of estimated compliance costs for 2021 and 2022 are being recovered over four-year
periods beginning January 1 of each respective year, as authorized under the 2019 ARP and modified under the 2022 ARP, with recovery of
construction contingency beginning in the year following actual expenditure. The CCR ARO costs recovered through the ECCR tariff are revised
for actual expenditures and updated estimates through annual compliance filings, which resulted in an approximate $10 million increase
effective January 1, 2022 in the related cost recovery.
Georgia Power's retail ROE under the 2019 ARP was set at 10.50% and earnings were evaluated against a retail ROE range of 9.50% to 12.00%.
Any retail earnings above 12.00% were shared, with 40% applied to reduce regulatory assets, 40% directly refunded to customers, and the
remaining 20% retained by Georgia Power. In 2020, Georgia Power's retail ROE was within the allowed retail ROE range. In 2021, Georgia
Power's retail ROE exceeded 12.00%, and Georgia Power reduced regulatory assets by approximately $5 million and accrued approximately
$5 million which was refunded to customers in 2022. In 2022, Georgia Power's retail ROE exceeded 12.00%, and Georgia Power reduced
regulatory assets by $117 million and refunded $117 million to customers through bill credits in the first quarter 2023.
Integrated Resource Plans
In July 2022, the Georgia PSC approved Georgia Power's 2022 IRP, as modified by a stipulated agreement among Georgia Power, the
staff of the Georgia PSC, and certain intervenors and as further modified by the Georgia PSC. In the 2022 IRP decision, the Georgia
PSC approved, among other things, the certification of six PPAs (including five affiliate PPAs with Southern Power that are subject to
approval by the FERC) with capacities of 1,567 MWs beginning in 2024, 380 MWs beginning in 2025, and 228 MWs beginning in 2028,
procured through RFPs authorized in the 2019 IRP. See Note 9 for additional information.
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Southern Company 2023 Annual Report Notes to Financial Statements
On October 27, 2023, Georgia Power filed an updated IRP (2023 IRP Update) with the Georgia PSC, which sets forth a plan to support
the recent increase in the state of Georgia's projected energy needs since the 2022 IRP. In the 2023 IRP Update, Georgia Power requested
the following:
O Authority to develop, own, and operate up to 1,400 MWs from three simple cycle combustion turbines at Plant Yates.
O Certification of an affiliate PPA with Mississippi Power for 750 MWs, which began January 1, 2024 and will continue through
December 2028.
O Certification of a non-affiliate PPA for 230 MWs starting the month after conclusion of the 2023 IRP Update proceeding continuing
through December 2028.
O Authority to develop, own, and operate up to 1,000 MWs of battery energy storage system facilities, including storage systems
collocated with existing and new Georgia Power-owned solar facilities.
O Approval of transmission projects necessary to support the generation resources requested in the 2023 IRP Update.
The 2023 IRP Update assumes a retirement date at the end of 2035 for Plant Bowen Units 1 and 2 (1,400 MWs). Georgia Power expects
to make a formal recommendation in the 2025 IRP on the retirement or continued operations for Plant Bowen Units 1 and 2, as well
as evaluate extending the operation of Plant Scherer Unit 3 (614 MWs based on 75% ownership) and Plant Gaston Units 1 through 4
(500 MWs based on 50% ownership through SEGCO) beyond the retirement dates in 2028 that were approved in the 2022 IRP. See Note 7
under “SEGCO“ for additional information.
Georgia Power expects the Georgia PSC to render a final decision on the 2023 IRP Update on April 16, 2024.
On January 12, 2024, Georgia Power entered into an Agreement for Engineering, Procurement, and Construction with Mitsubishi Power
Americas, Inc. and Black & Veatch Construction, Inc. to construct three 442-MW simple cycle combustion turbine units at Plant Yates (Plant
Yates Units 8, 9, and 10), which are expected to be placed in service in the fourth quarter 2026, the second quarter 2027, and the third
quarter 2027, respectively.
The ultimate outcome of these matters cannot be determined at this time.
In August 2022, Restore Chattooga Gorge Coalition (RCG) filed a petition in the Superior Court of Fulton County, Georgia against Georgia
Power and the Georgia PSC. The petition challenged Georgia Power's plan to expend $115 million to modernize Plant Tugalo (a hydro
facility), as approved in the 2019 IRP, and sought judicial review of the Georgia PSC's order in the 2022 IRP proceeding with respect to
the denial of RCG's challenge to the modernization plan. On October 23, 2023, the court granted Georgia Power's and the Georgia PSC's
motions to dismiss the RCG petition. This matter is now concluded.
Fuel Cost Recovery
Georgia Power has established fuel cost recovery rates approved by the Georgia PSC. During the second half of 2021, the price of natural
gas rose significantly and resulted in an under recovered fuel balance exceeding $200 million. Therefore, in November 2021, the Georgia
PSC voted to approve Georgia Power's interim fuel rider, which increased fuel rates by 15%, or approximately $252 million annually,
effective January 1, 2022.
During 2022, Georgia Power's under recovered fuel balance continued to increase significantly due to higher fuel and purchased power
costs. On May 16, 2023, the Georgia PSC approved a stipulation agreement between Georgia Power and the staff of the Georgia PSC to
increase annual fuel billings by 54%, or approximately $1.1 billion, effective June 1, 2023. The increase includes a three-year recovery
period for $2.2 billion of Georgia Power's under recovered fuel balance at May 31, 2023. Under the approved stipulation agreement,
Georgia Power is allowed to adjust its fuel cost recovery rates under an interim fuel rider prior to the next fuel case, subject to a
maximum 40% cumulative change, if its under or over recovered fuel balance accumulated since May 31, 2023 exceeds $200 million.
Georgia Power is scheduled to file its next fuel case no later than February 28, 2026.
Georgia Power's under recovered fuel balance totaled $1.9 billion at December 31, 2023, of which $694 million is included in under
recovered fuel clause revenues and under recovered retail fuel clause revenues on Southern Company's and Georgia Power's balance
sheets, respectively, and $1.2 billion is included in deferred under recovered retail fuel clause revenues on Southern Company's and
Georgia Power's balance sheets. The under recovered fuel balance totaled $2.1 billion at December 31, 2022 and is included in deferred
under recovered retail fuel clause revenues on Southern Company's and Georgia Power's balance sheets.
Georgia Power's fuel cost recovery mechanism includes costs associated with a natural gas hedging program, as revised and approved by
the Georgia PSC, allowing the use of an array of derivative instruments within a 36-month time horizon.
Fuel cost recovery revenues as recorded on the financial statements 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 or Georgia Power's revenues or net income but will affect operating cash flows.
90
Southern Company 2023 Annual Report Notes to Financial Statements
Storm Damage Recovery
Georgia Power defers and recovers certain costs related to damages from major storms as mandated by the Georgia PSC. During 2021 and
2022, Georgia Power recovered $213 million annually under the 2019 ARP. Beginning January 1, 2023, Georgia Power is recovering $31 million
annually under the 2022 ARP. At December 31, 2022, Georgia Power's storm damage reserve balance was $83 million and is included in
other regulatory liabilities, deferred on Southern Company's balance sheet and other deferred credits and liabilities on Georgia Power's
balance sheet. During 2023, significant storms caused damage to Georgia Power's transmission and distribution facilities. The incremental
restoration costs related to these storms exceeded the storm damage reserve and were deferred in the regulatory asset for storm damage.
At December 31, 2023, Georgia Power's regulatory asset balance related to storm damage was $54 million, of which $31 million is included in
other regulatory assets, current and $23 million is included in other regulatory assets, deferred on Southern Company's and Georgia Power's
balance sheets. The rate of storm damage cost recovery is expected to be adjusted in future regulatory proceedings as necessary. As a result of
this regulatory treatment, costs related to storms are not expected to have a material impact on Southern Company's or Georgia Power's net
income but do impact the related operating cash flows. See Note 1 under “Storm Damage and Reliability Reserves“ for additional information.
Nuclear Construction
In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a 45.7% ownership interest.
In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction of the two AP1000
nuclear units (with electric generating capacity of approximately 1,100 MWs each) and related facilities to begin. Until March 2017,
construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement.
In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners,
entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for
the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services,
procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will
continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units.
In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, under which
Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, subject to adjustment based on Bechtel's performance against cost
and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its proportionate share, based on its ownership interest, of all
amounts owed to Bechtel under the Bechtel Agreement.
See Note 8 under “Long-term Debt – DOE Loan Guarantee Borrowings“ for information on the Amended and Restated Loan Guarantee
Agreement, including applicable covenants, events of default, and mandatory prepayment events.
Cost and Schedule
Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including
contingency, through the second quarter 2024 is as follows:
Base project capital cost forecast(a)(b)
Construction contingency estimate
Total project capital cost forecast(a)(b)
Net investment at December 31, 2023(b)
Remaining estimate to complete
(in millions)
$ 10,717
36
10,753
(10,564)
189
$
(a) Includes approximately $610 million of costs that are not shared with the other Vogtle Owners, including $33 million of construction monitoring costs, and
approximately $567 million of incremental costs under the cost-sharing provisions of the joint ownership agreements described below. Excludes financing
costs expected to be capitalized through AFUDC of approximately $440 million, of which $417 million had been accrued through December 31, 2023.
(b) Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds.
Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.53 billion, of
which $3.50 billion had been incurred through December 31, 2023.
Georgia Power placed Unit 3 in service on July 31, 2023. As part of its ongoing processes, Southern Nuclear continues to evaluate cost and
schedule forecasts for Unit 4 on a regular basis to incorporate current information available, particularly in the areas of start-up testing and
related test results and engineering support. As of December 31, 2023, based on completion of construction work and the assessment of
start-up and pre-operational testing remaining, Southern Nuclear has an estimated $36 million for construction contingency remaining in
the estimate to complete. This contingency is projected to be allocated in the future to address any further Unit 4 schedule extensions or
remediation of other issues discovered during start-up testing.
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Southern Company 2023 Annual Report Notes to Financial Statements
Hot functional testing for Unit 4 was completed on May 1, 2023. On July 20, 2023, Southern Nuclear announced that all Unit 4 ITAACs had
been submitted to the NRC, and, on July 28, 2023, the NRC published its 103(g) finding that the accepted criteria in the combined license for
Unit 4 had been met, which allowed nuclear fuel to be loaded and start-up testing to begin. Fuel load for Unit 4 was completed on August 19,
2023. On October 6, 2023, Georgia Power announced that during start-up and pre-operational testing for Unit 4, Southern Nuclear identified
a motor fault in one of four reactor coolant pumps (RCPs). This RCP was replaced with an on-site spare RCP from inventory.
On February 1, 2024, Georgia Power announced that during start-up and pre-operational testing for Unit 4, Southern Nuclear identified,
and has remediated, vibrations associated with certain piping within the cooling system. Considering the remaining pre-operational testing,
Unit 4 is projected to be placed in service during the second quarter 2024. On February 14, 2024, Unit 4 achieved self-sustaining nuclear
fission, commonly referred to as initial criticality.
With Unit 3's four RCPs operating as designed, Southern Nuclear believes that the motor fault on this single Unit 4 RCP is an isolated
event. However, any findings related to the root cause of the motor fault on the single Unit 4 RCP could require engineering changes or
remediation related to the other seven Unit 3 and Unit 4 RCPs. The projected schedule for Unit 4 significantly depends on the progression
of start-up and pre-operational testing, which may be impacted by equipment or other operational failures. As Unit 4 progresses further
through testing, ongoing and potential future challenges may also include the management of contractors and vendors; the availability of
materials and parts, and/or related cost escalation; the availability of supervisory and technical support resources; and the timeframe and
duration of pre-operational testing. New challenges also may continue to arise as Unit 4 moves further into testing and start-up, which
may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on
new technology that only within the last several years began initial operation in the global nuclear industry at this scale). These challenges
may result in further schedule delays and/or cost increases.
With the receipt of the NRC's 103(g) findings for Units 3 and 4 in August 2022 and July 2023, respectively, the site is subject to the
NRC's operating reactor oversight process and must meet applicable technical and operational requirements contained in its operating
license. Various design and other licensing-based compliance matters may result in additional license amendment requests 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 Unit 4 project schedule that could result in increased costs.
The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond June 2024
for Unit 4, including the joint owner cost sharing impacts described below, is estimated to result in additional base capital costs for Georgia
Power of up to $25 million per month as well as any additional related construction, support resources, or testing costs. Pursuant to the
regulatory orders discussed below, any further changes to the capital cost forecast will not be recoverable through regulated rates and will be
required to be charged to income. Such charges could be material.
Joint Owner Contracts
In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to
provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further
amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements
related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4
to continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements).
The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners' sole recourse against Georgia Power or Southern Nuclear for
any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power and/or
Southern Nuclear as agent, except in cases of willful misconduct.
Amendments to the Vogtle Joint Ownership Agreements
In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term
sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power's wholly-owned subsidiaries MEAG Power SPVJ, LLC
(MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially
mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership
Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet)
with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle
Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement
to implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power's
wholly-owned subsidiaries MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership
Agreements to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments).
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Southern Company 2023 Annual Report Notes to Financial Statements
Pursuant to the Global Amendments: (i) each Vogtle Owner paid its proportionate share of qualifying construction costs for Plant Vogtle
Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4, of which
Georgia Power's share is $8.4 billion (VCM 19 Forecast Amount), plus $800 million; (ii) Georgia Power was responsible for 55.7% of actual
qualifying construction costs between $800 million and $1.6 billion over the VCM 19 Forecast Amount (resulting in $80 million of potential
additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata in accordance with their
respective ownership interests; and (iii) Georgia Power was responsible for 65.7% of qualifying construction costs between $1.6 billion and
$2.1 billion over the VCM 19 Forecast Amount (resulting in a further $100 million of potential additional costs to Georgia Power), with the
remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective ownership interests. The Global
Amendments provide that if the EAC was revised and exceeded the VCM 19 Forecast Amount by more than $2.1 billion, each of the other
Vogtle Owners had a one-time option at the time the project budget cost forecast was so revised to tender a portion of its ownership
interest to Georgia Power in exchange for Georgia Power's agreement to pay 100% of such Vogtle Owner's remaining share of total
construction costs in excess of the VCM 19 Forecast Amount plus $2.1 billion.
In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 must
vote to continue construction if certain adverse events (Project Adverse Events) occur, including, among other events: (i) the bankruptcy
of Toshiba; (ii) the termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel
Agreement, or the agency agreement with Southern Nuclear; (iii) Georgia Power's public announcement of its intention not to submit
for rate recovery any portion of its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power's
costs relating to the construction of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts
paid by Georgia Power on behalf of the other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of
costs during any six-month VCM reporting period that are disallowed by the Georgia PSC for recovery, or for which Georgia Power elects
not to seek cost recovery, through retail rates; and (iv) an incremental extension of one year or more from the seventeenth VCM report
estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in
February 2022 triggered the requirement for a vote to continue construction and all the Vogtle Owners voted to continue construction.
The filing of Georgia Power's prudency application with the Georgia PSC, which included Georgia Power's public announcement of its
intention not to submit for rate recovery an amount that is greater than the first 6% of costs during any six-month VCM reporting period,
triggered the requirement for a vote to continue construction and all the Vogtle Owners voted to continue construction. See additional
information on Georgia Power's prudency application filing below.
In September 2022, Georgia Power and MEAG Power reached an agreement to resolve a dispute regarding the cost-sharing and tender
provisions of the Global Amendments. Under the terms of the agreement, among other items, (i) MEAG Power will not exercise its
tender option and will retain its full ownership interest in Plant Vogtle Units 3 and 4; (ii) Georgia Power will reimburse a portion of MEAG
Power's costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure
costs, which payments will total approximately $92 million based on the current project capital cost forecast; and (iii) Georgia Power
will reimburse 20% of MEAG Power's costs of construction with respect to any amounts over the current project capital cost forecast,
with no further adjustment for force majeure costs. In addition, MEAG Power agreed to vote to continue construction upon occurrence
of a Project Adverse Event unless the commercial operation date of either of Plant Vogtle Unit 3 or Unit 4 is not projected to occur by
December 31, 2025.
On October 5, 2023 and October 17, 2023, Georgia Power reached agreements with OPC and Dalton, respectively, to resolve its respective
dispute with each of OPC and Dalton regarding the cost-sharing and tender provisions of the Global Amendments. Under the terms of the
agreements with OPC and Dalton, among other items, (i) each of OPC and Dalton retracted its exercise of the tender option and will retain
its full ownership interest in Plant Vogtle Units 3 and 4, (ii) Georgia Power made payments immediately after execution of the agreements
of $308 million and $17 million to OPC and Dalton, respectively, representing payment for a portion of each of OPC's and Dalton's costs of
construction for Plant Vogtle Units 3 and 4 previously incurred, (iii) Georgia Power will pay a portion of each of OPC's and Dalton's further
costs of construction for Plant Vogtle Units 3 and 4 as such costs are incurred and with no further adjustment for force majeure costs,
which payments will be in an aggregate amount of approximately $105 million and $6 million for OPC and Dalton, respectively, based
on the current project capital cost forecast, and (iv) Georgia Power will pay 66% of each of OPC's and Dalton's costs of construction with
respect to any amounts above the current project capital cost forecast, with no further adjustment for force majeure costs.
Georgia Power recorded pre-tax charges to income through the fourth quarter 2022 of $407 million ($304 million after tax) associated
with the cost-sharing provisions of the Global Amendments, including the settlement with MEAG Power. Based on the current project
capital cost forecast and the settlements with OPC and Dalton described above, Georgia Power recorded a pre-tax charge to income of
approximately $160 million ($120 million after tax) in the third quarter 2023. These charges are included in the total project capital cost
forecast and will not be recovered from retail customers.
The ultimate impact of these matters on the project capital cost forecast for Plant Vogtle Units 3 and 4 cannot be determined at this time.
93
Southern Company 2023 Annual Report Notes to Financial Statements
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 December 31, 2023, Georgia Power had recovered approximately $3.0 billion of financing costs. Financing costs related
to capital costs above $4.418 billion up to $7.562 billion approved for recovery as described below are being recognized through AFUDC and
will be recovered through retail rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to
any capital costs in excess of $7.562 billion. In December 2022, the Georgia PSC approved Georgia Power's filing to increase the NCCR tariff
by $36 million annually, effective January 1, 2023. On November 1, 2023, Georgia Power filed a request to continue for 2024 the NCCR
tariff that was effective during 2023. The staff of the Georgia PSC accepted the proposal and no further approval from the Georgia PSC was
required. See additional information below on AFUDC and the NCCR tariff following commercial operation of Unit 4.
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 January 2018, the Georgia PSC issued an order approving Georgia Power's seventeenth
VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 2018
order, resolved certain regulatory matters related to Plant Vogtle Units 3 and 4 including, but not limited to: (i) 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; (ii) confirmed that a prudence proceeding on cost recovery would occur following Unit 4 fuel load,
consistent with applicable Georgia law; (iii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point
authorized by the Georgia PSC at that time) to 10.00% effective January 1, 2016, (b) from 10.00% to 8.30%, effective January 1, 2020,
and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case will be less than Georgia Power's average cost of
long-term debt); and (iv) 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.
The January 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 $310 million, $300 million, and $270 million in 2023, 2022, and 2021, respectively, and are estimated to have a
negative earnings impact of approximately $90 million in 2024.
In 2021, the Georgia PSC approved an order under which Georgia Power would include in rate base an allocation of $2.1 billion to Plant
Vogtle Unit 3 and the Common Facilities from the $3.6 billion of Plant Vogtle Units 3 and 4 costs previously deemed prudent by the
Georgia PSC and would recover the related depreciation expense through retail base rates effective the month after Unit 3 is placed in
service. In compliance with the Georgia PSC order, Georgia Power increased annual retail base rates by $318 million effective August 1,
2023 based on the in-service date of July 31, 2023 for Unit 3. The related increase in annual retail base rates included recovery of all
projected operations and maintenance expenses for Unit 3 and the Common Facilities and other related costs of operation, partially offset
by the related PTCs. Financing costs (debt and equity) on the remaining portion of the total Unit 3 and the Common Facilities construction
costs continue to be recovered through the NCCR tariff or deferred. Georgia Power is deferring as a regulatory asset the debt component
of financing costs ($14 million at December 31, 2023) as well as the remaining depreciation expense ($17 million at December 31, 2023)
until Unit 4 costs are placed in retail base rates. The equity component of financing costs ($23 million at December 31, 2023) represents
an unrecognized ratemaking amount that is not reflected on Georgia Power's balance sheets. This amount will be recognized in Georgia
Power's income statements in the periods it is billable to customers.
On August 19, 2023, fuel load for Unit 4 was completed, and, on August 30, 2023, Georgia Power filed an application to adjust rates to
include reasonable and prudent Plant Vogtle Units 3 and 4 costs (Application). On December 19, 2023, the Georgia PSC voted to approve
the Application as modified by the related stipulated agreement (Prudency Stipulation) among Georgia Power, the staff of the Georgia PSC,
and certain intervenors.
While recognizing the Prudency Stipulation, the Application provided the necessary support to justify the reasonableness, prudence, and
recovery of $8.826 billion in total construction and capital costs, $1.07 billion in associated retail rate base items, and the operating costs
related to the full operation and output of Plant Vogtle Units 3 and 4. Under the terms of the approved Prudency Stipulation, Georgia Power
will recover $7.562 billion in total construction and capital costs and associated retail rate base items of $1.02 billion, which includes AFUDC
financing costs above $4.418 billion (the Georgia PSC-certified amount) up to $7.562 billion. Georgia Power will also recover projected
operations and maintenance expenses, depreciation expense, nuclear decommissioning accruals, and property taxes, net of projected PTCs.
After considering construction and capital costs already in retail base rates of $2.1 billion and $362 million of associated retail rate base items
(approved by the Georgia PSC in 2021) and upon achieving commercial operation of Unit 4, Georgia Power will include in retail rate base the
remaining $5.462 billion of construction and capital costs as well as $656 million of associated retail rate base items.
94
Southern Company 2023 Annual Report Notes to Financial Statements
When the rate adjustment occurs, Georgia Power's NCCR tariff will cease to be collected and financing costs will be included in Georgia
Power's general retail revenue requirements. Further, as included in the approved Prudency Stipulation, if commercial operation for Unit 4 is
not achieved by March 31, 2024, Georgia Power's ROE used to determine the NCCR tariff and calculate AFUDC will be reduced to zero, which
will result in an estimated negative impact to earnings of approximately $30 million per month until the month following the date commercial
operation for Unit 4 is achieved. As of each Unit's respective first refueling outage, if the respective Unit's performance has materially deviated
from expected performance, the Georgia PSC may order Georgia Power to credit customers for operations and maintenance expenses or
disallow costs associated with the repair or replacement of any system, structure, or component found to have caused the material deviation
in performance if proven to be the result of imprudent engineering, construction, procurement, testing, or start-up.
Annual retail base revenues will increase approximately $729 million and the average retail base rates will be adjusted by approximately 5%
(net of the elimination of the NCCR tariff described above) effective the first day of the month after Unit 4 achieves commercial operation.
The approval of the Application and the Prudency Stipulation resolves all issues for determination by the Georgia PSC regarding the
reasonableness, prudence, and cost recovery for the remaining Plant Vogtle Units 3 and 4 construction and capital costs not already in retail
base rates.
As a result of the Georgia PSC's approval of the Prudency Stipulation, Georgia Power recorded a pre-tax credit to income of approximately
$228 million ($170 million after tax) in the fourth quarter 2023 to recognize CWIP costs previously charged to income, which are now
recoverable through retail rates. Associated AFUDC on these costs was also recognized.
The ultimate outcome of these matters cannot be determined at this time.
Mississippi Power
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 and several separate cost recovery clauses for specific categories of costs.
These separate cost recovery clauses address such items as fuel and purchased power, 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.
Performance Evaluation Plan
Mississippi Power's retail base rates generally are set under the PEP, a rate plan approved by the Mississippi PSC. In recognition that Mississippi
Power's long-term financial success is dependent upon how well it satisfies its customers' needs, PEP includes performance indicators that
directly tie customer service indicators to Mississippi Power's allowed ROE. PEP measures Mississippi Power's performance on a 10-point scale as
a weighted average of results in three areas: average customer price, as compared to prices of other regional utilities (weighted at 40%); service
reliability, measured in percentage of time customers had electric service (40%); and customer satisfaction, measured in a survey of residential
customers (20%). Typically, two PEP filings are made for each calendar year: the PEP projected filing in March of the current year and the PEP
lookback filing in March of the subsequent year. The annual PEP projected filings utilize a historic test year adjusted for “known and measurable“
changes and discounted cash flow and regression formulas to determine base ROE. The PEP lookback filing reflects the actual revenue requirement.
In June 2021 and June 2022, the Mississippi PSC approved Mississippi Power's annual retail PEP filings, resulting in annual increases in
revenues of approximately $16 million, or 1.8%, and $18 million, or 1.9%, respectively, effective with the first billing cycle of April 2021
and April 2022, respectively. On June 13, 2023, the Mississippi PSC approved Mississippi Power's annual retail PEP filing for 2023 indicating
no change in retail rates.
Integrated Resource Plan
In 2020, the Mississippi PSC issued an order requiring Mississippi Power to incorporate into its 2021 IRP a schedule of early or anticipated
retirement of 950 MWs of fossil-steam generation by year-end 2027 to reduce the excess reserve margin Mississippi Power anticipated at that
time. The order stated that Mississippi Power will be allowed to defer any retirement-related costs as regulatory assets for future recovery.
In 2021, the Mississippi PSC concluded its review of Mississippi Power's 2021 IRP. The 2021 IRP included a schedule to retire Plant
Watson Unit 4 (268 MWs) and Mississippi Power's 40% ownership interest in Plant Greene County Units 1 and 2 (103 MWs each)
in December 2023, 2025, and 2026, respectively, consistent with each unit's remaining useful life in the most recent approved
depreciation studies. In addition, the schedule reflected the early retirement of Mississippi Power's 50% undivided ownership interest
in Plant Daniel Units 1 and 2 (502 MWs) by the end of 2027. The Plant Greene County unit retirements require the completion by
Alabama Power of transmission and system reliability improvements, as well as agreement by Alabama Power.
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Southern Company 2023 Annual Report Notes to Financial Statements
The remaining net book value of Plant Daniel Units 1 and 2 was approximately $489 million at December 31, 2023 and Mississippi
Power is continuing to depreciate these units using the current approved rates. Mississippi Power expects to reclassify the net book
value remaining at retirement to a regulatory asset to be amortized over a period to be determined by the Mississippi PSC in future
proceedings, consistent with the 2020 order. The Plant Watson and Greene County units are expected to be fully depreciated upon
retirement. See Note 3 under “Other Matters – Mississippi Power“ for additional information on Plant Daniel Units 1 and 2.
In October 2023, Mississippi Power signed an affiliate PPA with Georgia Power for 750 MWs of capacity, which began January 1, 2024
and will continue through December 2028. In order to fulfill this PPA and serve the interests of customers, Mississippi Power now
expects electric generating units identified in its 2021 IRP to remain in service beyond the previously indicated dates. Mississippi Power
is expected to file its next IRP in April 2024 in accordance with the rules and orders of the Mississippi PSC.
The ultimate outcome of these matters cannot be determined at this time.
Environmental Compliance Overview Plan
In accordance with a 2011 accounting order from the Mississippi PSC, Mississippi Power has the authority to defer in a regulatory asset for
future recovery all plant retirement- or partial retirement-related costs resulting from environmental regulations.
In June 2021, April 2022, and April 2023, the Mississippi PSC approved Mississippi Power's annual ECO Plan filings, resulting in a decrease in
revenues of approximately $9 million annually effective with the first billing cycle of July 2021, an increase in revenues of approximately
$1 million annually effective with the first billing cycle of May 2022, and a $3 million annual increase in revenues effective with the first
billing cycle of May 2023, respectively.
On February 12, 2024, Mississippi Power submitted its annual ECO Plan filing to the Mississippi PSC, which requested a $9 million annual
increase in revenues. The ultimate outcome of this matter cannot be determined at this time.
Fuel Cost Recovery
Mississippi Power annually establishes, and is required to file for an adjustment to, the retail fuel cost recovery factor that is approved
by the Mississippi PSC. The Mississippi PSC approved increases of $2 million and $43 million effective in February 2021 and 2022,
respectively. In November 2022, Mississippi Power filed a request with the Mississippi PSC to increase retail fuel revenues by $25 million
annually effective with the first billing cycle of February 2023 and an additional $25 million annually effective with the first billing cycle
of June 2023. On January 10, 2023, the Mississippi PSC voted to defer approval of the filing. Mississippi Power is allowed to maintain
current billing rates and continue accruing its weighted-average cost of capital on any under or over fuel recovery balance. On February 6,
2024, the Mississippi PSC approved Mississippi Power's request to increase retail fuel revenues by $18 million annually effective with the
first billing cycle of March 2024. The approved filing included the deferral of approximately $61 million of under recovered fuel costs
as of October 2023, which is expected to be included in Mississippi Power's next fuel filing. Mississippi Power will continue to accrue its
weighted-average cost of capital on any under or over fuel recovery balance.
At December 31, 2023, Mississippi Power had $50 million of deferred under recovered retail fuel clause revenues and $27 million of over
recovered retail fuel clause revenues primarily associated with its fuel-hedging program on its balance sheet. At December 31, 2022, under
recovered retail fuel costs of approximately $1 million were included in other customer accounts receivable on Mississippi Power's balance
sheet. See Note 1 under “Fuel Costs“ for additional information.
Mississippi Power has wholesale MRA and Market Based (MB) fuel cost recovery factors. Effective with the first billing cycles for
January 2022, 2023, and 2024, annual revenues under the wholesale MRA fuel rate increased $11 million and $22 million and decreased
$4 million, respectively. The wholesale MB fuel rate did not change materially in any period presented. At December 31, 2023 and 2022,
wholesale fuel costs were over recovered $5 million and under recovered $6 million, respectively.
Mississippi Power's operating revenues are adjusted for differences in actual recoverable fuel cost and amounts billed in accordance with
the currently approved cost recovery rate. Accordingly, changes in the billing factor should have no significant effect on Mississippi Power's
revenues or net income but will affect operating cash flows.
Ad Valorem Tax Adjustment
Mississippi Power annually establishes an ad valorem tax adjustment factor that is approved by the Mississippi PSC. Effective with the
first billing cycle of May 2021, July 2022, and June 2023, the Mississippi PSC approved changes in annual revenues collected through
the ad valorem tax adjustment factor resulting in a $28 million increase, a $5 million increase, and a $7 million decrease, respectively.
The 2021 increase included approximately $19 million of ad valorem taxes previously recovered through PEP in accordance with a
2019 rate case settlement agreement.
96
Southern Company 2023 Annual Report Notes to Financial Statements
System Restoration Rider
Mississippi Power carries insurance for the cost of certain types of damage to generation plants and general property. However, Mississippi
Power is self-insured for the cost of storm, fire, and other uninsured casualty damage to its property, including transmission and
distribution facilities. As permitted by the Mississippi PSC and the FERC, Mississippi Power accrues for the cost of such damage through
an annual expense accrual which is credited to regulatory liability accounts for the retail and wholesale jurisdictions. The cost of repairing
actual damage resulting from such events that individually exceed $50,000 is charged to the reserve. Every year, the Mississippi PSC, the
MPUS, and Mississippi Power agree on SRR revenue level(s).
Mississippi Power's net retail SRR accrual, which includes carrying costs and previously included amortization of related excess deferred
income tax benefits, was $11.7 million in 2023, $6.9 million in 2022, and $(1.8) million in 2021. At December 31, 2023 and 2022, the retail
property damage reserve balance was $45 million and $37 million, respectively.
In 2021, the Mississippi PSC approved Mississippi Power's annual SRR filing, which requested an increase in retail revenues of approximately
$9 million annually effective with the first billing cycle of March 2022. On April 4, 2023, the Mississippi PSC approved Mississippi
Power's annual SRR filing, which indicated no change in retail rates. Mississippi Power's minimum annual SRR accrual was increased from
$8.3 million to $11.7 million. In the event the expected annual charges exceed the annual accrual or the target balance has been met,
Mississippi Power and the Mississippi PSC will determine the appropriate change to the annual accrual. Additionally, if PEP earnings are
above a certain threshold, Mississippi Power has the ability to apply any required PEP refund as an additional accrual to the property
damage reserve in lieu of customer refunds.
On February 1, 2024, Mississippi Power submitted its annual SRR filing to the Mississippi PSC, which indicated no change in retail rates.
The filing includes a request to increase the minimum annual SRR accrual from $11.7 million to $12.6 million.
Reliability Reserve Accounting Order
In December 2022, the Mississippi PSC approved an accounting order authorizing Mississippi Power to create a reliability reserve for the
purpose of deferring generation, transmission, and distribution reliability-related expenditures for use in a future year. Mississippi Power
may make accruals to the reliability reserve each year after meeting with the MPUS and Mississippi PSC staff. Mississippi Power will
provide annually, through its capital plan, energy delivery plan, or PEP filing, any amounts to be charged against the reliability reserve
during the current year. During 2023 and 2022, Mississippi Power accrued $11 million and $25 million, respectively, to the reliability
reserve. At December 31, 2023 and 2022, the reliability reserve balance was $36 million and $25 million, respectively.
Municipal and Rural Associations Tariff
Mississippi Power provides wholesale electric service to Cooperative Energy, East Mississippi Electric Power Association, and the City of
Collins, all located in southeastern Mississippi, under a long-term, cost-based, FERC-regulated MRA tariff.
In 2017, Mississippi Power and Cooperative Energy executed, and the FERC accepted, a Shared Service Agreement (SSA), as part of the MRA
tariff, under which Mississippi Power and Cooperative Energy share in providing electricity to the Cooperative Energy delivery points under
the tariff. In August 2022, the FERC accepted an amended SSA between Mississippi Power and Cooperative Energy, effective July 1, 2022,
under which Cooperative Energy will continue to decrease its use of Mississippi Power's generation services under the MRA tariff up to
2.5% annually through 2035. At December 31, 2023, Mississippi Power is serving approximately 390 MWs of Cooperative Energy's annual
demand. Beginning in 2036, Cooperative Energy will provide 100% of its electricity requirements at the MRA delivery points under the
tariff. Neither party has the option to cancel the amended SSA.
On October 27, 2023, the FERC approved a settlement agreement filed by Mississippi Power and Cooperative Energy on July 31, 2023
related to Mississippi Power's July 2022 request for a $23 million increase in annual wholesale base revenues under the MRA tariff.
The settlement agreement provides for a $16 million increase in annual wholesale base revenues, effective September 14, 2022, and a
refund to customers of approximately $6 million primarily related to the difference between the approved rates and interim rates.
Southern Company Gas
Utility Regulation and Rate Design
The natural gas distribution utilities are subject to regulation and oversight by their respective state regulatory agencies. Rates charged
to customers vary according to customer class (residential, commercial, or industrial) and rate jurisdiction. These agencies approve rates
designed to provide the opportunity to generate revenues to recover all prudently-incurred costs, including a return on rate base sufficient
to pay interest on debt and provide a reasonable ROE.
97
Southern Company 2023 Annual Report Notes to Financial Statements
As a result of operating in a deregulated environment, Atlanta Gas Light earns revenue by charging rates to its customers based primarily
on monthly fixed charges that are set by the Georgia PSC and adjusted periodically. The Marketers add these fixed charges when billing
their respective customers. This mechanism, called a straight-fixed-variable rate design, minimizes the seasonality of Atlanta Gas Light's
revenues since the monthly fixed charge is not volumetric or directly weather dependent.
With the exception of Atlanta Gas Light, the earnings of the natural gas distribution utilities can be affected by customer consumption
patterns that are largely a function of weather conditions and price levels for natural gas. Specifically, customer demand substantially
increases during the Heating Season when natural gas is used for heating purposes. Southern Company Gas has various mechanisms, such
as weather and revenue normalization mechanisms and weather derivative instruments, that limit exposure to weather changes within
typical ranges in these utilities' respective service territories.
In addition to natural gas cost recovery mechanisms, other cost recovery mechanisms and regulatory riders, which vary by utility, allow
recovery of certain costs, such as those related to infrastructure replacement programs as well as environmental remediation, energy
efficiency plans, and bad debts. In traditional rate designs, utilities recover a significant portion of the fixed customer service and pipeline
infrastructure costs based on assumed natural gas volumes used by customers. With the exception of Chattanooga Gas, the natural gas
distribution utilities have decoupled regulatory mechanisms that Southern Company Gas believes encourage conservation by separating
the recoverable amount of these fixed costs from the amounts of natural gas used by customers. See “Rate Proceedings“ herein for
additional information. Also see “Infrastructure Replacement Programs and Capital Projects“ herein for additional information regarding
infrastructure replacement programs at certain of the natural gas distribution utilities.
The following table provides regulatory information for Southern Company Gas' natural gas distribution utilities:
Authorized ROE at December 31, 2023
Weather normalization mechanisms(a)
Decoupled, including straight-fixed-variable rates(b)
Regulatory infrastructure program rate(c)
Bad debt rider(d)
Energy efficiency plan(e)
Annual base rate adjustment mechanism(f)
Year of last base rate case decision
Nicor Gas
Atlanta Gas Light
Virginia Natural Gas
Chattanooga Gas
9.51%
10.25%
9.70%
9.80%
2023
2019
2023
2018
(a) Designed to help stabilize operating results by allowing recovery of costs in the event of unseasonal weather, but are not direct offsets to the potential
impacts on earnings of weather and customer consumption.
(b) Allows for recovery of fixed customer service costs separately from assumed natural gas volumes used by customers and provides a benchmark level of
revenue for recovery.
(c) See “Infrastructure Replacement Programs and Capital Projects“ herein for additional information. Chattanooga Gas' pipeline replacement program costs are
recovered through its annual base rate review mechanism.
(d) The recovery (refund) of bad debt expense over (under) an established benchmark expense. The gas portion of bad debt expense is recovered through
purchased gas adjustment mechanisms. Nicor Gas also has a rider to recover the non-gas portion of bad debt expense.
(e) Recovery of costs associated with plans to achieve specified energy savings goals.
(f) Regulatory mechanism allowing annual adjustments to base rates up or down based on authorized ROE and/or ROE range.
Infrastructure Replacement Programs and Capital Projects
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 timely recovery of capital expenditures for specific infrastructure replacement programs
and Atlanta Gas Light has a separate rate rider that provides for the timely recovery of capital expenditures for a specific reinforcement
capital program. Total capital expenditures incurred during 2023 for all gas distribution operations were $1.6 billion.
The following table and discussions provide updates on the infrastructure replacement programs and capital projects at the natural gas distribution
utilities at December 31, 2023. These programs are risk-based and designed to update and replace cast iron, bare steel, and mid-vintage plastic
materials or expand Southern Company Gas' distribution systems to improve reliability and meet operational flexibility and growth.
98
Southern Company 2023 Annual Report Notes to Financial Statements
Utility
Program
Recovery
Investing in Illinois
Qualifying Infrastructure
Plant(*)
SAVE
System Reinforcement
Rider
Pipeline Replacement
Program
Rider
Rider
Rider
Rate Base
Nicor Gas
Virginia Natural Gas
Atlanta Gas Light
Chattanooga Gas
Total
Capital
Expenditures
in 2023
Capital
Expenditures
Since Project
Inception
Pipe
Installed
Since
Project
Inception
Scope of
Program
Program
Duration
Last
Year of
Program
(in millions)
(miles)
(miles)
(years)
$365
75
104
9
$553
$3,228
486
1,367
567
180
16
20
15
1,367
695
N/A
73
$3,910
1,969
2,135
9
13
3
7
2023
2024
2024
2027
(*) Included replacement of pipes, compressors, and transmission mains along with other improvements such as new meters. This program ended November
30, 2023 with all expenditures placed in service. Recovery of program costs is described under “Nicor Gas“ herein.
Nicor Gas
Illinois legislation allows Nicor Gas to provide more widespread safety and reliability enhancements to its distribution system through 2023
and stipulates that rate increases to customers as a result of any infrastructure investments shall not exceed a cumulative annual average
of 4.0% or, in any given year, 5.5% of base rate revenues. In 2014, the Illinois Commission approved the nine-year regulatory infrastructure
program, Investing in Illinois, which concluded in 2023 and is subject to annual review, as discussed further below. In accordance with
orders from the Illinois Commission, Nicor Gas recovers program costs incurred through a separate rider and base rates. See “Rate
Proceedings – Nicor Gas“ herein for additional information.
On June 15, 2023, the Illinois Commission concluded its review of the Qualifying Infrastructure Plant (QIP) capital investments by Nicor Gas
for calendar year 2019 under the QIP rider, also referred to as Investing in Illinois program. The Illinois Commission disallowed $32 million
of the $415 million of capital investments commissioned in 2019, together with the related return on investment. Nicor Gas recorded a
pre-tax charge to income in the second quarter 2023 of $38 million ($28 million after tax) associated with the disallowance of capital
investments placed in service in 2019. The disallowance is reflected on the statement of income as an $8 million reduction to revenues and
$30 million in estimated loss on regulatory disallowance. On August 3, 2023, the Illinois Commission denied a rehearing request filed by
Nicor Gas. On August 24, 2023, Nicor Gas filed a notice of appeal with the Illinois Appellate Court. Nicor Gas defends these investments in
infrastructure as prudently incurred.
The following table provides a summary of QIP capital investments during the nine-year program:
Year
2015 – 2018
2019
2020
2021
2022
2023
Status of QIP Annual
Review Proceeding
Capital
Investments
Disallowed
Month of
Disallowance
Complete
Complete(a)
Filed March 2021
Filed March 2022
Filed March 2023
To be filed by March 20, 2024
(in millions)
$
1,246
$
415
402(b)
392(b)
408(b)
365(b)
—
32
June 2023
6(a)(c) November 2023
25(a)(c) November 2023
$
3,228
$
63
(a) Appealed to the Illinois Appellate Court.
(b) Capital investments are subject to the required QIP annual review proceeding; years 2020 through 2022 are pending with the Illinois Commission.
(c) Disallowed in Nicor Gas' 2023 general base rate case proceeding. See “Rate Proceedings – Nicor Gas“ herein for additional information regarding the Illinois
Commission's disallowance of certain capital investments.
Any further cost disallowances by the Illinois Commission in the pending cases could be material to the financial statements of Southern
Company Gas. The ultimate outcome of these matters cannot be determined at this time.
99
Southern Company 2023 Annual Report Notes to Financial Statements
Virginia Natural Gas
The SAVE program, an accelerated infrastructure replacement program, allows Virginia Natural Gas to continue replacing aging pipeline
infrastructure through 2024. The program includes authorized annual investments of $60 million in 2021 and $70 million in each year from
2022 through 2024, with a total potential variance of up to $5 million allowed for the program, for a maximum total investment over the
six-year term (2019 through 2024) of $365 million.
On February 9, 2024, Virginia Natural Gas filed with the Virginia Commission a request to extend the existing SAVE program through 2029.
The request includes investments of $70 million in each year from 2025 through 2029, with a potential variance of up to $5 million
allowed for the program, for a maximum total investment over the five-year extension (2025 through 2029) of $355 million.
Virginia Natural Gas expects the Virginia Commission to issue a final order on this matter in the second quarter 2024. The ultimate outcome
of this matter cannot be determined at this time.
The SAVE program is subject to annual review by the Virginia Commission. In accordance with the base rate case approved by the Virginia
Commission in 2023, Virginia Natural Gas is recovering program costs incurred prior to January 1, 2023 through base rates. Program costs
incurred subsequent to January 1, 2023 are currently being recovered through a separate rider and are subject to future base rate case
proceedings. See “Rate Proceedings – Virginia Natural Gas“ herein for additional information.
Atlanta Gas Light
In 2019, the Georgia PSC approved the continuation of GRAM as part of Atlanta Gas Light's 2019 rate case order. Various infrastructure
programs previously authorized by the Georgia PSC, including the Integrated Vintage Plastic Replacement Program to replace aging
plastic pipe and the Integrated System Reinforcement Program to upgrade Atlanta Gas Light's distribution system and LNG facilities in
Georgia, continue under GRAM and the recovery of and return on the infrastructure program investments are included in annual base
rate adjustments. The amounts to be recovered through rates related to allowed, but not incurred, costs have been quantified as an
unrecognized ratemaking amount that is not reflected on the balance sheets. These allowed costs are primarily the equity return on the
capital investment under the infrastructure programs in place prior to GRAM and are being recovered through GRAM and base rates
until the earlier of the full recovery of such amounts or December 31, 2025. The under recovered balance at December 31, 2023 was
$44 million, including $23 million of unrecognized equity return, and is expected to be recovered by December 31, 2025. The Georgia PSC
reviews Atlanta Gas Light's performance annually under GRAM. See “Unrecognized Ratemaking Amounts“ herein for additional information.
Atlanta Gas Light and the staff of the Georgia PSC previously agreed to a variation of the Integrated Customer Growth Program to extend
pipeline facilities to serve customers in areas without pipeline access and create new economic development opportunities in Georgia.
A separate tariff provides recovery of up to $15 million annually for strategic economic development projects approved by the Georgia PSC.
See “Rate Proceedings – Atlanta Gas Light“ herein for additional information regarding the Georgia PSC's 2021 approval of Atlanta Gas
Light's GRAM filing and Integrated Capacity and Delivery Plan. The Georgia PSC also approved a new System Reinforcement Rider for
authorized large pressure improvement and system reliability projects, which is expected to recover related capital investments totaling
$286 million for the years 2022 through 2024, of which $104 million and $76 million was incurred in 2023 and 2022, respectively.
Chattanooga Gas
In 2021, the Tennessee Public Utilities Commission approved Chattanooga Gas' pipeline replacement program to replace approximately
73 miles of distribution main over a seven-year period. The estimated total cost of the program is $118 million, which will be recovered
through Chattanooga Gas' annual base rate review mechanism.
Natural Gas Cost Recovery
With the exception of Atlanta Gas Light, 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. The natural gas distribution
utilities defer or accrue the difference between the actual cost of natural gas and the amount of commodity revenue earned in a
given period. The deferred or accrued amount is either billed or refunded to customers prospectively through adjustments to the
commodity rate. Deferred natural gas costs are reflected as regulatory assets and accrued natural gas costs are reflected as regulatory
liabilities. Natural gas costs generally do not have a significant effect on Southern Company's or Southern Company Gas' net income, but
could have a significant effect on cash flows. Since Atlanta Gas Light does not sell natural gas directly to its end-use customers, it does
not utilize a traditional natural gas cost recovery mechanism. However, Atlanta Gas Light does maintain natural gas inventory for the
Marketers in Georgia and recovers the cost through recovery mechanisms approved by the Georgia PSC. At December 31, 2023, the over
recovered balance was $214 million, which was included in natural gas cost over recovery on Southern Company's and Southern Company
Gas' balance sheets. At December 31, 2022, the under recovered balance was $108 million, which was included in natural gas cost under
recovery on Southern Company's and Southern Company Gas' balance sheets.
100
Southern Company 2023 Annual Report Notes to Financial Statements
Rate Proceedings
Nicor Gas
In 2021, the Illinois Commission approved a $240 million annual base rate increase, which became effective November 24, 2021. The base
rate increase included $94 million related to the recovery of program costs under the Investing in Illinois program and was based on a ROE
of 9.75% and an equity ratio of 54.5%.
On November 16, 2023, the Illinois Commission approved a $223 million annual base rate increase for Nicor Gas, which became effective
December 1, 2023. The base rate increase was based on a return on equity of 9.51% and an equity ratio of 50.00%.
In connection with Nicor Gas' general base rate case proceeding, the Illinois Commission disallowed $126.8 million of capital investments
that have been completed or planned to be completed through December 31, 2024. This includes $31 million for capital investments
placed in service in 2022 and 2023 under the Investing in Illinois program and $95.9 million for other transmission and distribution capital
investments. Nicor Gas recorded a pre-tax charge to income in the fourth quarter 2023 of $58 million ($44 million after tax) associated
with the disallowances, with the remaining $69 million related to prospective projects that will be postponed and/or reevaluated.
The disallowance is reflected on the statement of income in estimated loss on regulatory disallowance. See “Infrastructure Replacement
Programs and Capital Projects – Nicor Gas“ herein for additional information regarding the Illinois Commission's disallowance of certain
capital investments. On January 3, 2024, the Illinois Commission denied a request by Nicor Gas for rehearing on the base rate case
disallowances associated with capital investment, as well as on other issues determined in the Illinois Commission's November 16, 2023
base rate case decision. On February 6, 2024, Nicor Gas filed a notice of appeal with the Illinois Appellate Court related to the Illinois
Commission's rate case ruling. The ultimate outcome of this matter cannot be determined at this time.
Atlanta Gas Light
The Georgia PSC evaluates Atlanta Gas Light's earnings against a ROE range of 10.05% to 10.45%, with disposition of any earnings above
10.45% to be determined by the Georgia PSC. Additionally, the Georgia PSC allows inclusion in base rates of the recovery of and return
on the infrastructure program investments, including, but not limited to, GRAM adjustments. GRAM filing rate adjustments are based on
an authorized ROE of 10.25%. GRAM adjustments for 2021 could not exceed 5% of 2020 base rates. The 5% limitation does not set a
precedent in any future rate proceedings by Atlanta Gas Light.
In April 2021, Atlanta Gas Light filed its Integrated Capacity and Delivery Plan (i-CDP) with the Georgia PSC, which included a series of
ongoing and proposed pipeline safety, reliability, and growth programs for the next 10 years (2022 through 2031), as well as the required
capital investments and related costs to implement the programs. The i-CDP reflected capital investments totaling approximately
$0.5 billion to $0.6 billion annually.
In November 2021, the Georgia PSC approved a stipulation agreement between Atlanta Gas Light and the staff of the Georgia PSC, under which,
for the years 2022 through 2024, Atlanta Gas Light will incrementally reduce its combined GRAM and System Reinforcement Rider request by 10%
through Atlanta Gas Light's GRAM mechanism, which resulted in a reduction of $5 million for 2022, $7 million for 2023, and $9 million for 2024.
The stipulation agreement also provided for $1.7 billion of total capital investment for the years 2022 through 2024.
In November 2021, December 2022, and December 2023, the Georgia PSC approved Atlanta Gas Light's annual GRAM filings,
which resulted in an annual rate increase of $43 million effective January 1, 2022, an annual rate increase of $53 million effective
January 1, 2023, and an annual rate increase of $53 million effective January 1, 2024, respectively.
On February 1, 2024, Atlanta Gas Light filed its triennial i-CDP with the Georgia PSC, which included a series of ongoing and proposed
pipeline safety, reliability, and growth programs for the next 10 years (2025 through 2034), as well as the required capital investments
and related costs to implement the programs. The i-CDP reflected capital investments totaling approximately $0.7 billion to $1.0 billion
annually. Atlanta Gas Light expects the Georgia PSC to issue a final order on this matter in the third quarter 2024. The ultimate outcome of
this matter cannot be determined at this time.
Virginia Natural Gas
In 2021, the Virginia Commission approved a stipulation agreement related to Virginia Natural Gas' 2020 general rate case filing, which
allowed for a $43 million increase in annual base rate revenues, including $14 million related to the recovery of investments under the
SAVE program, based on a ROE of 9.5% and an equity ratio of 51.9%. Interim rates became effective as of November 1, 2020, subject
to refund, based on Virginia Natural Gas' original requested increase of approximately $50 million. Refunds to customers related to the
difference between the approved rates effective October 1, 2021 and the interim rates were completed during the fourth quarter 2021.
101
Southern Company 2023 Annual Report Notes to Financial Statements
On August 28, 2023, the Virginia Commission approved a stipulation agreement related to Virginia Natural Gas' August 2022 general
base rate case filing, which allowed for a $48 million increase in annual base rate revenues based on a ROE of 9.70% and an equity
ratio of 49.06%. Interim rates became effective as of January 1, 2023, subject to refund, based on Virginia Natural Gas' original
requested increase of approximately $69 million. Refunds to customers related to the difference between the approved rates effective
September 1, 2023 and the interim rates were completed during the fourth quarter 2023.
Unrecognized Ratemaking Amounts
The following table illustrates Southern Company Gas' authorized ratemaking amounts that are not recognized on its balance sheets.
These amounts are primarily comprised of an allowed equity rate of return on assets associated with certain regulatory infrastructure
programs. These amounts will be recognized as revenues in Southern Company Gas' financial statements in the periods they are billable to
customers, the majority of which will be recovered by 2025.
Atlanta Gas Light
Virginia Natural Gas
Chattanooga Gas
Nicor Gas
Total
December 31, 2023
December 31, 2022
(in millions)
$23
10
7
3
$43
$35
10
2
3
$50
3. CONTINGENCIES, COMMITMENTS, AND GUARANTEES
General Litigation Matters
The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential
litigation or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current
proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current
proceedings would have a material effect on such Registrant's financial statements.
The Registrants intend to dispute the allegations raised in and vigorously defend against the pending legal challenges discussed below;
however, the ultimate outcome of these matters cannot be determined at this time.
Southern Company and Mississippi Power
In 2010, the DOE, through a cooperative agreement with SCS, agreed to fund $270 million of the Kemper County energy facility through
the grants awarded to the project by the DOE under the Clean Coal Power Initiative Round 2. In 2016, additional DOE grants in the amount
of $137 million were awarded to the Kemper County energy facility. In 2018, Mississippi Power filed with the DOE its request for property
closeout certification under the contract related to the $387 million of total grants received. In 2020, Mississippi Power and Southern
Company executed an agreement with the DOE completing Mississippi Power's request, which enabled Mississippi Power to proceed with
full dismantlement of the abandoned gasifier-related assets and site restoration activities. In connection with the DOE closeout discussions,
in 2019, the Civil Division of the Department of Justice informed Southern Company and Mississippi Power of a civil investigation
related to the DOE grants. On August 4, 2023, the U.S. District Court for the Northern District of Georgia unsealed a civil action in which
defendants Southern Company, SCS, and Mississippi Power are alleged to have violated certain provisions of the False Claims Act by
fraudulently inducing the DOE to disburse funds pursuant to the grants. The federal government declined to intervene in the action.
On October 30, 2023, the plaintiff, a former SCS employee, filed an amended complaint, again alleging certain violations of the False Claims
Act. The plaintiff seeks to recover all damages incurred personally and on behalf of the government caused by the defendants' alleged
violations, as well as treble damages and attorneys' fees, among other relief. The ultimate outcome of this matter cannot be determined at
this time; however, an adverse outcome could have a material impact on Southern Company's and Mississippi Power's financial statements.
Alabama Power
In September 2022, Mobile Baykeeper filed a citizen suit in the U.S. District Court for the Southern District of Alabama alleging that
Alabama Power's plan to close the Plant Barry ash pond utilizing a closure-in-place methodology violates the Resource Conservation and
Recovery Act (RCRA) and regulations governing CCR. Among other relief requested, Mobile Baykeeper sought a declaratory judgment that
the RCRA and regulations governing CCR were being violated, preliminary and injunctive relief to prevent implementation of Alabama
Power's closure plan and the development of a closure plan that satisfies regulations governing CCR requirements. In December 2022,
Alabama Power filed a motion to dismiss the case. On January 4, 2024, the lawsuit was dismissed without prejudice by the U.S. District
Court judge. On February 1, 2024, the plaintiff filed a motion to reconsider.
102
Southern Company 2023 Annual Report Notes to Financial Statements
On January 31, 2023, the EPA issued a Notice of Potential Violations associated with Alabama Power's plan to close the Plant Barry ash
pond. Alabama Power has affirmed to the EPA its position that it is in compliance with CCR requirements. The ultimate outcome of this
matter cannot be determined at this time but could have a material impact on Alabama Power's ARO estimates and cash flows.
See Note 6 for a discussion of Alabama Power's ARO liabilities.
Georgia Power
In July 2020, a group of individual plaintiffs filed a complaint, which was amended in December 2022, in the Superior Court of Fulton County,
Georgia against Georgia Power alleging that the construction and operation of Plant Scherer has impacted groundwater and air, resulting in
alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages,
a medical monitoring fund, and injunctive relief. In December 2022, the Superior Court of Fulton County, Georgia granted Georgia Power's
motion to transfer the case to the Superior Court of Monroe County, Georgia. On May 9, 2023, the Superior Court of Monroe County, Georgia
denied Georgia Power's motion to dismiss the case for lack of subject matter jurisdiction. On July 27, 2023, the Superior Court of Monroe
County, Georgia denied the remaining motions to dismiss certain claims and plaintiffs that Georgia Power filed at the outset of the case.
In October 2021, February 2022, and January 2023, a total of eight additional complaints were filed in the Superior Court of Monroe County,
Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater and air, resulting in alleged personal
injuries and property damage. The plaintiffs sought an unspecified amount of monetary damages including punitive damages. After Georgia
Power removed these cases to the U.S. District Court for the Middle District of Georgia, the plaintiffs voluntarily dismissed their complaints
without prejudice in November 2022 and January 2023. On May 12, 2023, the plaintiffs in the cases originally filed in October 2021,
February 2022, and January 2023 refiled their eight complaints in the Superior Court of Monroe County, Georgia. Also on May 12, 2023, a new
complaint was filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that the construction and operation of
Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries. The plaintiff seeks an unspecified amount of monetary
damages, including punitive damages. On May 18, 2023, Georgia Power removed all of these cases to the U.S. District Court for the Middle
District of Georgia. The plaintiffs are requesting the court remand the cases back to the Superior Court of Monroe County, Georgia.
The amount of possible loss, if any, from these matters cannot be estimated at this time.
Mississippi Power
In 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three
then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March
2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised
upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service.
The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the
previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and
make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers
by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and
their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district
court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the
Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all
defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file
a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional
state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds.
In November 2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power.
In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended
complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. In March 2022, the
U.S. Court of Appeals for the Fifth Circuit issued an opinion affirming the dismissal of the claims against the Mississippi PSC defendants but
reversing the dismissal of the claims against Mississippi Power. In May 2022, the U.S. Court of Appeals for the Fifth Circuit denied a petition
by Mississippi Power for a rehearing en banc and remanded the case to the U.S. District Court for the Southern District of Mississippi for
further proceedings. In June 2022, Mississippi Power filed with the trial court a motion to dismiss the complaint with prejudice, which was
granted on March 15, 2023. On March 28, 2023, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit.
On December 14, 2023, the U.S. Court of Appeals for the Fifth Circuit affirmed the district court's order dismissing the plaintiffs' complaint
against Mississippi Power. On December 28, 2023, the plaintiffs filed a petition for panel rehearing, which was denied on January 10, 2024.
The plaintiffs have until April 9, 2024 to file a petition for writ of certiorari with the U.S. Supreme Court. The ultimate outcome of this matter
cannot be determined at this time.
103
Southern Company 2023 Annual Report Notes to Financial Statements
Southern Power
In July 2021, Southern Power and certain of its subsidiaries filed an arbitration demand with the American Arbitration Association against
First Solar Electric, LLC (First Solar) for defective design of actuators on trackers and inverters installed by First Solar under the engineering,
procurement, and construction agreements associated with five solar projects owned by Southern Power and partners and managed by Southern
Power. In February 2023, arbitration hearings concluded. In July 2023, an interim award of approximately $36 million was entered in favor of
Southern Power and was subsequently received in September 2023. The interim award included $18 million representing recovery of losses
associated with replacement costs, penalty payments, and lost revenues previously incurred. This recovery is reflected in Southern Power's 2023
statement of income as an $11 million reduction to other operations and maintenance expense and a $7 million increase in other revenues, with
$6 million allocated through noncontrolling interests to Southern Power's partners. The remaining $18 million in award proceeds received in
excess of the losses incurred is recognized on the balance sheet at December 31, 2023 as restricted cash and a liability to fund future replacement
costs. In November 2023, the final award was issued and Southern Power filed for confirmation of the final award in the Delaware Court of
Chancery. In December 2023, First Solar filed a motion to dismiss the confirmation and, in February 2024, filed a petition to vacate the arbitration
award in the Supreme Court of New York County, New York. The ultimate outcome of this matter cannot be determined at this time.
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 conduct studies to determine
the extent of any required cleanup and have recognized the estimated costs to clean up known impacted sites in the financial statements.
A liability for environmental remediation costs is recognized only when a loss is determined to be probable and reasonably estimable and
is reduced as expenditures are incurred. The traditional electric operating companies and the natural gas distribution utilities in Illinois and
Georgia have each received authority from their respective state PSCs or other applicable state regulatory agencies to recover approved
environmental remediation costs through regulatory mechanisms. Any difference between the liabilities accrued and costs recovered
through rates is deferred as a regulatory asset or liability. These regulatory mechanisms are adjusted annually or as necessary within limits
approved by the state PSCs or other applicable state regulatory agencies.
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. For 2023, 2022, and 2021, Georgia Power recovered approximately $5 million, $12 million,
and $12 million, respectively, through the ECCR tariff for environmental remediation.
Southern Company Gas is subject to environmental remediation liabilities associated with 40 former manufactured gas plant sites in four
different states. Southern Company Gas' accrued environmental remediation liability at December 31, 2023 and 2022 was based on the
estimated cost of environmental investigation and remediation associated with these sites.
At December 31, 2023 and 2022, the environmental remediation liability and the balance of under recovered environmental remediation
costs were reflected in the balance sheets of Southern Company, Georgia Power, and Southern Company Gas as shown in the table below.
Alabama Power and Mississippi Power did not have environmental remediation liabilities at December 31, 2023 or 2022.
December 31, 2023:
Environmental remediation liability:
Other current liabilities
Accrued environmental remediation
Under recovered environmental remediation costs:
Other regulatory assets, current
Other regulatory assets, deferred
December 31, 2022:
Environmental remediation liability:
Other current liabilities
Accrued environmental remediation
Under recovered environmental remediation costs:
Other regulatory assets, current
Other regulatory assets, deferred
104
Southern
Company
Georgia
Power
(in millions)
Southern
Company Gas
$ 44
192
$ 45
210
$ 65
207
$ 59
235
$14
—
$ 5
15
$15
—
$ 5
20
$ 30
192
$ 40
195
$ 49
207
$ 54
215
Southern Company 2023 Annual Report Notes to Financial Statements
The ultimate outcome of these matters cannot be determined at this time; however, as a result of the regulatory treatment for
environmental remediation expenses described above, the final disposition of these matters is not expected to have a material impact on
the financial statements of the applicable Registrants.
Nuclear Fuel Disposal Costs
Acting through the DOE and pursuant to the Nuclear Waste Policy Act of 1982, the U.S. government entered into contracts with Alabama
Power and Georgia Power that required the DOE to take title to and dispose of spent nuclear fuel generated at Plants Farley, Hatch,
and Vogtle Units 1 and 2 beginning no later than January 31, 1998. The DOE has yet to commence performance of its contractual and
statutory obligation to dispose of spent nuclear fuel. Consequently, Alabama Power and Georgia Power pursued and continue to pursue
legal remedies against the U.S. government for its partial breach of contract.
In 2014, Alabama Power and Georgia Power filed their third round of lawsuits against the U.S. government in the Court of Federal Claims,
seeking damages for the costs of continuing to store spent nuclear fuel at Plants Farley, Hatch, and Vogtle Units 1 and 2 for the period
from January 1, 2011 through December 31, 2013. The damage period was subsequently extended to December 31, 2014. In 2019, the
Court of Federal Claims granted Alabama Power's and Georgia Power's motion for summary judgment on damages not disputed by the
U.S. government, awarding those undisputed damages to Alabama Power and Georgia Power. However, those undisputed damages are not
collectible until the court enters final judgment on the remaining damages.
In 2017, Alabama Power and Georgia Power filed their fourth round of lawsuits against the U.S. government in the Court of Federal Claims,
seeking damages for the costs of continuing to store spent nuclear fuel at Plants Farley, Hatch, and Vogtle Units 1 and 2 for the period from
January 1, 2015 through December 31, 2017. In 2020, Alabama Power and Georgia Power filed amended complaints in those fourth-round
lawsuits adding damages incurred from January 1, 2018 to December 31, 2019 to the claim period.
The outstanding claims for the period January 1, 2011 through December 31, 2019 total $106 million and $128 million for Alabama Power
and Georgia Power (based on its ownership interests), respectively. Damages will continue to accumulate until the issue is resolved, the
U.S. government disposes of Alabama Power's and Georgia Power's spent nuclear fuel pursuant to its contractual obligations, or alternative
storage is otherwise provided. No amounts have been recognized in the financial statements as of December 31, 2023 for any potential
recoveries from the pending lawsuits.
The final outcome of these matters cannot be determined at this time. However, Alabama Power and Georgia Power expect to credit any
recoveries for the benefit of customers in accordance with direction from their respective PSC; therefore, no material impact on Southern
Company's, Alabama Power's, or Georgia Power's net income is expected.
On-site dry spent fuel storage facilities are operational at all three plants and can be expanded to accommodate spent fuel through the
expected life of each plant.
Nuclear Insurance
Under the Price-Anderson Amendments Act (Act), Alabama Power and Georgia Power maintain agreements of indemnity with the NRC
that, together with private insurance, cover third-party liability arising from any nuclear incident occurring at the companies' nuclear power
plants. The Act provides funds up to $16.2 billion for public liability claims that could arise from a single nuclear incident. Each nuclear
plant is insured against this liability to a maximum of $450 million by American Nuclear Insurers (ANI), with the remaining coverage
provided by a mandatory program of deferred premiums that could be assessed, after a nuclear incident, against all owners of commercial
nuclear reactors. A company could be assessed up to $166 million per incident for each licensed reactor it operates but not more than an
aggregate of $25 million per incident to be paid in a calendar year for each reactor. Such maximum assessment, excluding any applicable
state premium taxes, for Alabama Power and Georgia Power, based on its ownership and buyback interests in all licensed reactors, is
$332 million and $473 million, respectively, per incident, but not more than an aggregate of $49 million and $71 million, respectively, to
be paid for each incident in any one year. Both the maximum assessment per reactor and the maximum yearly assessment are adjusted
for inflation at least every five years. The next scheduled adjustment is due no later than November 1, 2028. See Note 5 under “Joint
Ownership Agreements“ for additional information on joint ownership agreements.
Alabama Power and Georgia Power are members of Nuclear Electric Insurance Limited (NEIL), a mutual insurer established to provide
property damage insurance in an amount up to $1.5 billion for members' operating nuclear generating facilities. Additionally, both
companies have NEIL policies that currently provide decontamination, excess property insurance, and premature decommissioning coverage
up to $1.25 billion for nuclear losses and policies providing coverage up to $750 million for non-nuclear losses in excess of the $1.5 billion
primary coverage.
105
Southern Company 2023 Annual Report Notes to Financial Statements
NEIL also covers the additional costs that would be incurred in obtaining replacement power during a prolonged accidental outage at a
member's nuclear plant. Members can purchase this coverage, subject to a deductible waiting period of up to 26 weeks, with a maximum
per occurrence per unit limit of $490 million. After the deductible period, weekly indemnity payments would be received until either the
unit is operational or until the limit is exhausted. Alabama Power and Georgia Power each purchase limits based on the projected full cost
of replacement power, subject to ownership limitations, and have each elected a 12-week deductible waiting period for each nuclear plant.
A builders' risk property insurance policy has been purchased from NEIL for the construction of Plant Vogtle Unit 4. This policy provides the
Vogtle Owners up to $2.75 billion for accidental property damage occurring during construction.
Under each of the NEIL policies, members are subject to assessments each year if losses exceed the accumulated funds available to the
insurer. The maximum annual assessments for Alabama Power and Georgia Power as of December 31, 2023 under the NEIL policies would
be $54 million and $89 million, respectively.
Claims resulting from terrorist acts and cyber events are covered under both the ANI and NEIL policies (subject to normal policy limits).
The maximum aggregate that NEIL will pay for all claims resulting from terrorist acts and cyber events in any 12-month period is
$3.2 billion each, plus such additional amounts NEIL can recover through reinsurance, indemnity, or other sources.
For all on-site property damage insurance policies for commercial nuclear power plants, the NRC requires that the proceeds of such policies
shall be dedicated first for the sole purpose of placing the reactor in a safe and stable condition after an accident. Any remaining proceeds
are to be applied next toward the costs of decontamination and debris removal operations ordered by the NRC, and any further remaining
proceeds are to be paid either to the applicable company or to its debt trustees as may be appropriate under the policies and applicable
trust indentures. In the event of a loss, the amount of insurance available might not be adequate to cover property damage and other
expenses incurred. Uninsured losses and other expenses, to the extent not recovered from customers, would be borne by Alabama Power
or Georgia Power, as applicable, and could have a material effect on Southern Company's, Alabama Power's, and Georgia Power's financial
condition and results of operations.
All retrospective assessments, whether generated for liability, property, or replacement power, may be subject to applicable state premium taxes.
Other Matters
Traditional Electric Operating Companies
In April 2019, Bellsouth Telecommunications d/b/a AT&T Alabama (AT&T) filed a complaint against Alabama Power with the FCC alleging
that the pole rental rate AT&T is required to pay pursuant to the parties' joint use agreement is unjust and unreasonable under federal law.
The complaint sought a new rate and approximately $87 million in refunds of alleged overpayments for the preceding six years. In August
2019, the FCC stayed the case in favor of arbitration, which AT&T has not pursued. The joint use agreement remains in effect. The ultimate
outcome of this matter cannot be determined at this time, but an adverse outcome could have a material impact on the financial statements
of Southern Company and Alabama Power. Georgia Power and Mississippi Power have joint use agreements with other AT&T affiliates.
Mississippi Power
Kemper County Energy Facility
In 2021, 2022, and 2023, Mississippi Power recorded charges to income associated with abandonment and related closure costs and
ongoing period costs, net of salvage proceeds, for the mine and gasifier-related assets at the Kemper County energy facility. These charges,
including related tax impacts, totaled $11 million pre-tax ($8 million after tax) in 2021, $15 million pre-tax ($12 million after tax) in 2022,
and $17 million pre-tax ($12 million after tax) in 2023. The pre-tax charges are included in other operations and maintenance expenses on
the statements of income.
Dismantlement of the abandoned gasifier-related assets and site restoration activities are expected to be completed by 2026.
Additional pre-tax period costs associated with dismantlement and site restoration activities, including related costs for compliance and
safety, ARO accretion, and property taxes, net of salvage, are estimated to total approximately $15 million annually through 2025.
Mississippi Power owns the lignite mine located around the Kemper County energy facility site. As a result of the abandonment of the
Kemper IGCC, final mine reclamation began in 2018 and was substantially completed in 2020, with monitoring expected to continue
through 2028.
As the mining permit holder, Liberty Fuels Company, LLC, a wholly-owned subsidiary of The North American Coal Corporation, has a legal
obligation to perform mine reclamation and Mississippi Power has a contractual obligation to fund all reclamation activities. See Note 6 for
additional information.
See “General Litigation Matters – Southern Company and Mississippi Power“ herein for information regarding litigation associated with the
Kemper County energy facility.
106
Southern Company 2023 Annual Report Notes to Financial Statements
Plant Daniel
In conjunction with Southern Company's 2019 sale of Gulf Power, NextEra Energy held back $75 million of the purchase price pending
Mississippi Power and NextEra Energy negotiating a mutually acceptable revised operating agreement for Plant Daniel. In July 2022,
the co-owners executed a revised operating agreement and Southern Company subsequently received the remaining $75 million of the
purchase price. The dispatch procedures in the revised operating agreement for the two jointly-owned coal units at Plant Daniel resulted
in Mississippi Power designating one of the two units as primary and the other as secondary in lieu of each company separately owning
100% of a single generating unit. Mississippi Power did not exercise an option to purchase its co-owner's ownership interest for $1 on
January 15, 2024. The revised operating agreement did not have a material impact on Mississippi Power's financial statements. See Note 2
under “Mississippi Power – Integrated Resource Plan“ for additional information on Plant Daniel.
Commitments
To supply a portion of the fuel requirements of the Southern Company system's electric generating plants, the Southern Company system
has entered into various long-term commitments not recognized on the balance sheets for the procurement and delivery of fossil fuel
and, for Alabama Power and Georgia Power, nuclear fuel. The majority of the Registrants' fuel expense for the periods presented was
purchased under long-term commitments. Each Registrant expects that a substantial amount of its future fuel needs will continue to be
purchased under long-term commitments.
Georgia Power has commitments, in the form of capacity purchases, regarding a portion of a 5% interest in the original cost of Plant
Vogtle Units 1 and 2 owned by MEAG Power that are in effect until the later of the retirement of the plant or the latest stated maturity
date of MEAG Power's bonds issued to finance such ownership interest. The payments for capacity are required whether or not any
capacity is available. Portions of the capacity payments made to MEAG Power for its Plant Vogtle Units 1 and 2 investment relate to
costs in excess of Georgia Power's allowed investment for ratemaking purposes. The present value of these portions at the time of the
disallowance was written off. Generally, the cost of such capacity is included in purchased power in Southern Company's statements of
income and in purchased power, non-affiliates in Georgia Power's statements of income. Georgia Power's capacity payments related to
this commitment totaled $3 million, $4 million, and $6 million in 2023, 2022, and 2021, respectively. At December 31, 2023, Georgia
Power's estimated long-term obligations related to this commitment totaled $39 million, consisting of $4 million annually for 2024 and
2025, $2 million annually for 2026 through 2028, and $25 million thereafter.
See Note 9 for information regarding PPAs accounted for as leases.
Southern Company Gas has commitments for pipeline charges, storage capacity, and gas supply, including charges recoverable through
natural gas cost recovery mechanisms or, alternatively, billed to marketers selling retail natural gas. Gas supply commitments include
amounts for gas commodity purchases associated with Nicor Gas and SouthStar of 38 million mmBtu at floating gas prices calculated
using forward natural gas prices at December 31, 2023 and valued at $98 million. Southern Company Gas provides guarantees to certain
gas suppliers for certain of its subsidiaries in support of payment obligations. Southern Company Gas' expected future contractual
obligations for pipeline charges, storage capacity, and gas supply that are not recognized on the balance sheets at December 31, 2023
were as follows:
2024
2025
2026
2027
2028
Thereafter
Total
Guarantees
Pipeline Charges, Storage
Capacity, and Gas Supply
(in millions)
$ 587
432
231
148
103
785
$ 2,286
SCS may enter into various types of wholesale energy and natural gas contracts acting as an agent for the traditional electric operating
companies and Southern Power. Under these agreements, each of the traditional electric operating companies and Southern Power may
be jointly and severally liable. Accordingly, Southern Company has entered into keep-well agreements with each of the traditional electric
operating companies to ensure they will not subsidize or be responsible for any costs, losses, liabilities, or damages resulting from the
inclusion of Southern Power as a contracting party under these agreements.
107
Southern Company 2023 Annual Report Notes to Financial Statements
Alabama Power has guaranteed a $100 million principal amount long-term bank loan SEGCO entered into in 2018 and subsequently
extended and amended. Georgia Power has agreed to reimburse Alabama Power for the portion of such obligation corresponding to
Georgia Power's proportionate ownership of SEGCO's stock if Alabama Power is called upon to make such payment under its guarantee.
At December 31, 2023, the capitalization of SEGCO consisted of $69 million of equity and $100 million of long-term debt that matures
in November 2024, on which the annual interest requirement is derived from a variable rate index. SEGCO had no short-term debt
outstanding at December 31, 2023. See Note 7 under “SEGCO“ for additional information.
As discussed in Note 9, Alabama Power and Georgia Power have entered into certain residual value guarantees related to railcar leases.
4. REVENUE FROM CONTRACTS WITH CUSTOMERS
The Registrants generate revenues from a variety of sources, some of which are not accounted for as revenue from contracts with
customers, such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 under “Revenues“ for additional information on
the revenue policies of the Registrants. See Notes 9 and 14 for additional information on revenue accounted for under lease and derivative
accounting guidance, respectively.
The following table disaggregates revenue from contracts with customers for the periods presented:
2023
Operating revenues
Retail electric revenues
Residential
Commercial
Industrial
Other
Total retail electric revenues
Natural gas distribution revenues
Residential
Commercial
Transportation
Industrial
Other
Total natural gas distribution revenues
Wholesale electric revenues
PPA energy revenues
PPA capacity revenues
Non-PPA revenues
Total wholesale electric revenues
Other natural gas revenues
Gas marketing services
Other natural gas revenues
Total natural gas revenues
Other revenues
Total revenue from contracts with
customers
Other revenue sources(a)
Total operating revenues
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
$ 7,309
5,860
3,613
112
16,894
$ 2,904
1,928
1,721
12
6,565
$ 4,105
3,624
1,558
91
9,378
$ 300
308
334
9
951
1,981
505
1,184
45
324
4,039
1,107
624
250
1,981
528
31
559
1,355
—
—
—
—
—
—
234
156
65
455
—
—
—
213
—
—
—
—
—
—
87
51
35
173
—
—
—
578
—
—
—
—
—
—
20
45
407
472
—
—
—
39
24,828
425
$25,253
7,233
(183)
$ 7,050
10,129
(11)
$10,118
1,462
12
$1,474
$ —
—
—
—
—
—
—
—
—
—
—
790
376
409
1,575
—
—
—
55
1,630
559
$2,189
$ —
—
—
—
—
1,981
505
1,184
45
324
4,039
—
—
—
—
528
31
559
—
4,598
104
$ 4,702
108
Southern Company 2023 Annual Report Notes to Financial Statements
2022
Operating revenues
Retail electric revenues
Residential
Commercial
Industrial
Other
Total retail electric revenues
Natural gas distribution revenues
Residential
Commercial
Transportation
Industrial
Other
Total natural gas distribution revenues
Wholesale electric revenues
PPA energy revenues
PPA capacity revenues
Non-PPA revenues
Total wholesale electric revenues
Other natural gas revenues
Gas marketing services
Other natural gas revenues
Total other natural gas revenues
Other revenues
Total revenue from contracts with
customers
Other revenue sources(a)
Total operating revenues
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
$ 6,604
5,369
3,764
102
15,839
$2,638
1,685
1,507
14
5,844
$ 3,664
3,385
1,921
79
9,049
$ 302
299
336
9
946
2,843
763
1,186
84
342
5,218
2,274
596
250
3,120
636
51
687
1,077
—
—
—
—
—
—
489
194
200
883
—
—
—
194
—
—
—
—
—
—
130
47
30
207
—
—
—
446
—
—
—
—
—
—
16
4
690
710
—
—
—
47
25,941
3,338
$29,279
6,921
896
$7,817
9,702
1,882
$ 11,584
1,703
(9)
$1,694
$ —
—
—
—
—
—
—
—
—
—
—
1,673
356
740
2,769
—
—
—
36
2,805
564
$ 3,369
$ —
—
—
—
—
2,843
763
1,186
84
342
5,218
—
—
—
—
636
51
687
—
5,905
57
$ 5,962
109
Southern Company 2023 Annual Report Notes to Financial Statements
2021
Operating revenues
Retail electric revenues
Residential
Commercial
Industrial
Other
Total retail electric revenues
Natural gas distribution revenues
Residential
Commercial
Transportation
Industrial
Other
Total natural gas distribution revenues
Wholesale electric revenues
PPA energy revenues
PPA capacity revenues
Non-PPA revenues
Total wholesale electric revenues
Other natural gas revenues
Wholesale gas services
Gas marketing services
Other natural gas revenues
Total other natural gas revenues
Other revenues
Total revenue from contracts with
customers
Other revenue sources(a)
Other adjustments(b)
Total operating revenues
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
$ 6,207
4,877
3,067
93
14,244
$2,467
1,600
1,386
17
5,470
$ 3,471
3,010
1,391
68
7,940
$ 269
267
290
8
834
1,799
470
1,038
49
269
3,625
1,122
493
236
1,851
2,168
464
36
2,668
1,075
—
—
—
—
—
—
184
115
170
469
—
—
—
—
202
—
—
—
—
—
—
95
55
21
171
—
—
—
—
452
—
—
—
—
—
—
11
5
401
417
—
—
—
—
31
23,463
3,349
(3,699)
$23,113
6,141
272
—
$6,413
8,563
697
—
$ 9,260
1,282
40
—
$1,322
$ —
—
—
—
—
—
—
—
—
—
—
854
323
398
1,575
—
—
—
—
30
1,605
611
—
$ 2,216
$ —
—
—
—
—
1,799
470
1,038
49
269
3,625
—
—
—
—
2,168
464
36
2,668
—
6,293
1,786
(3,699)
$ 4,380
(a) Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs at Southern Company Gas,
and cost recovery mechanisms and revenues (including those related to fuel costs) that meet other scope exceptions for revenues from contracts with
customers at the traditional electric operating companies.
(b) Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net
of the related costs of those activities on the statement of income. See Notes 15 and 16 under “Southern Company Gas“ for information on the sale of
Sequent and components of wholesale gas services' operating revenues, respectively.
110
Southern Company 2023 Annual Report Notes to Financial Statements
Contract Balances
The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts
with customers at December 31, 2023 and 2022:
Accounts Receivable
At December 31, 2023
At December 31, 2022
Contract Assets
At December 31, 2023
At December 31, 2022
Contract Liabilities
At December 31, 2023
At December 31, 2022
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
$2,820
3,123
$ 271
156
$ 116
45
$821
696
$
2
2
$ —
4
$ 1,011
922
$ 121
89
$
1
9
$ 90
92
$ —
—
$ —
—
$122
237
$ —
—
$
4
1
$ 684
1,107
$
56
—
$ —
—
Contract assets for Georgia Power primarily relate to retail customer fixed bill programs, where the payment is contingent upon Georgia
Power's continued performance and the customer's continued participation in the program over a one-year contract term, and unregulated
service agreements, where payment is contingent on project completion. Contract liabilities for Georgia Power primarily relate to cash
collections recognized in advance of revenue for unregulated service agreements. Southern Company Gas' contract assets relate to work
performed on an energy efficiency enhancement and upgrade contract with the U.S. General Services Administration. Southern Company
Gas receives cash advances from a third-party financial institution to fund work performed, of which approximately $59 million had
been received at December 31, 2023. These advances have been accounted for as long-term debt on the balance sheets. See Note 1
under “Affiliate Transactions“ for additional information regarding the construction contract. At December 31, 2023 and 2022, Southern
Company's unregulated distributed generation business had contract assets of $91 million and $65 million, respectively, and contract
liabilities of $115 million and $32 million, respectively, for outstanding performance obligations.
Revenues recognized in 2023 and 2022, which were included in contract liabilities at December 31, 2023 and 2022, respectively, were
$36 million annually for Southern Company and immaterial for the other Registrants. Contract liabilities are primarily classified as current
on the balance sheets as the corresponding revenues are generally expected to be recognized within one year.
Remaining Performance Obligations
The Subsidiary Registrants may enter into long-term contracts with customers in which revenues are recognized as performance obligations
are satisfied over the contract term. For the traditional electric operating companies and Southern Power, these contracts primarily relate to
PPAs whereby electricity and generation capacity are provided to a customer. The revenue recognized for the delivery of electricity is variable;
however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. For Southern Company Gas, these
contracts primarily relate to the U.S. General Services Administration contract described above. Southern Company's unregulated distributed
generation business also has partially satisfied performance obligations related to certain fixed price contracts. Revenues from contracts with
customers related to these performance obligations remaining at December 31, 2023 are expected to be recognized as follows:
Southern Company
Alabama Power
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas
2024
2025
2026
2027
2028
Thereafter
$ 940
23
73
60
379
26
$ 552
9
41
63
301
—
(in millions)
$ 338
—
14
66
299
—
$332
—
15
69
306
—
$323
—
15
73
297
—
$ 2,045
—
9
—
2,041
—
5. PROPERTY, PLANT, AND EQUIPMENT
Property, plant, and equipment is stated at original cost or fair value at acquisition, as appropriate, less any regulatory disallowances
and impairments. Original cost may include: materials; labor; minor items of property; appropriate administrative and general costs;
payroll-related costs such as taxes, pensions, and other benefits; and the interest capitalized and/or cost of equity funds used
during construction.
111
Southern Company 2023 Annual Report Notes to Financial Statements
The Registrants' property, plant, and equipment in service consisted of the following at December 31, 2023 and 2022:
At December 31, 2023:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
Electric utilities:
Generation
Transmission
Distribution
General/other
Electric utilities' plant in service
Southern Company Gas:
Natural gas transportation and distribution
Storage facilities
Other
Southern Company Gas plant in service
Other plant in service
Total plant in service
$ 57,325
15,561
26,482
6,305
105,673
17,798
1,565
1,477
20,840
1,915
$128,428
$16,584
6,152
9,775
2,918
35,429
—
—
—
—
—
$35,429
$22,587
8,402
15,380
3,001
49,370
—
—
—
—
—
$49,370
$2,909
966
1,327
321
5,523
—
—
—
—
—
$5,523
$14,649
—
—
41
14,690
—
—
—
—
—
$14,690
$
—
—
—
—
—
17,798
1,565
1,477
20,840
—
$20,840
At December 31, 2022:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
Electric utilities:
Generation
Transmission
Distribution
General/other
Electric utilities' plant in service
Southern Company Gas:
Natural gas transportation and distribution
Storage facilities
Other
Southern Company Gas plant in service
Other plant in service
Total plant in service
$ 51,756
14,201
24,200
5,806
95,963
16,810
1,553
1,360
19,723
1,843
$117,529
$15,920
5,658
9,154
2,740
33,472
—
—
—
—
—
$33,472
$17,755
7,576
13,819
2,729
41,879
—
—
—
—
—
$41,879
$2,826
927
1,228
273
5,254
—
—
—
—
—
$5,254
$14,619
—
—
39
14,658
—
—
—
—
—
$14,658
$
—
—
—
—
—
16,810
1,553
1,360
19,723
—
$ 19,723
The cost of replacements of property, exclusive of minor items of property, is capitalized. The cost of maintenance, repairs, and replacement
of minor items of property is charged to other operations and maintenance expenses as incurred or performed with the exception of
nuclear refueling costs and certain maintenance costs including those described below.
In accordance with orders from their respective state PSCs, Alabama Power and Georgia Power defer nuclear refueling outage operations and
maintenance expenses to a regulatory asset when the charges are incurred. Alabama Power amortizes the costs over a subsequent 18-month
period with Plant Farley's fall outage cost amortization beginning in January of the following year and spring outage cost amortization beginning
in July of the same year. Georgia Power amortizes its costs over each unit's operating cycle, or 18 months for Plant Vogtle Units 1, 2, and 3 and
24 months for Plant Hatch Units 1 and 2. Georgia Power's amortization period begins the month the refueling outage starts.
A portion of Mississippi Power's railway track maintenance costs is charged to fuel stock and recovered through Mississippi Power's
fuel clause.
The portion of Southern Company Gas' non-working gas used to maintain the structural integrity of natural gas storage facilities that is
considered to be non-recoverable is depreciated, while the recoverable or retained portion is not depreciated.
See Note 9 for information on finance lease right-of-use (ROU) assets, net, which are included in property, plant, and equipment.
112
Southern Company 2023 Annual Report Notes to Financial Statements
The Registrants have deferred certain implementation costs related to cloud hosting arrangements. At December 31, 2023 and 2022,
deferred cloud implementation costs, net of amortization, which are generally included in other deferred charges and assets on the
Registrants' balance sheets, are as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company Gas
(in millions)
Deferred cloud implementation costs, net:
At December 31, 2023
At December 31, 2022
$325
345
$85
81
$ 99
108
$ 13
14
$ 15
18
$43
54
Once a hosted software is placed into service, the related deferred costs are amortized on a straight-line basis over the remaining expected
hosting arrangement term, including any renewal options that are reasonably certain of exercise. The amortization is reflected with the
associated cloud hosting fees, which are generally reflected in other operations and maintenance expenses on the Registrants' statements
of income. In 2023, amortization of deferred cloud implementation costs recognized was $46 million for Southern Company, $11 million
for Alabama Power, $19 million for Georgia Power, $8 million for Southern Company Gas, and immaterial for the other Registrants. In 2022,
amortization of deferred cloud implementation costs recognized was $29 million for Southern Company, $8 million for Alabama Power,
$12 million for Georgia Power, and immaterial for the other Registrants. In 2021, amortization from deferred cloud implementation costs
recognized was immaterial for all Registrants.
See Note 2 under “Regulatory Assets and Liabilities“ and “Alabama Power – Software Accounting Order“ for information on deferrals
of certain other operations and maintenance costs associated with software and cloud computing projects by the traditional
electric operating companies and natural gas distribution utilities, as authorized by their respective state PSCs or applicable state
regulatory agencies.
Depreciation and Amortization
The traditional electric operating companies' and Southern Company Gas' depreciation of the original cost of utility plant in service is
provided primarily by using composite straight-line rates. The approximate rates for 2023, 2022, and 2021 are as follows:
Alabama Power
Georgia Power
Mississippi Power
Southern Company Gas
2023
2022
2021
4.1 %
3.8%
3.4%
2.7 %
2.7%
3.3%
3.4%
2.7%
2.7%
3.3%
3.6%
2.8%
Depreciation studies are conducted periodically to update the composite rates. These studies are filed with the respective state
PSC and/or other applicable state and federal regulatory agencies for the traditional electric operating companies and the natural gas
distribution utilities. Effective January 1, 2023, Alabama Power's and Georgia Power's depreciation rates were revised. See Note 2 for
additional information.
When property, plant, and equipment subject to composite depreciation is retired or otherwise disposed of in the normal course of
business, its original cost, together with the cost of removal, less salvage, is charged to accumulated depreciation. For other property
dispositions, the applicable cost and accumulated depreciation are removed from the balance sheet accounts, and a gain or loss is
recognized. Minor items of property included in the original cost of the asset are retired when the related property unit is retired.
At December 31, 2023 and 2022, accumulated depreciation for Southern Company and Southern Company Gas consisted of utility plant
in service totaling $36.6 billion and $34.3 billion, respectively, for Southern Company and $5.3 billion and $5.1 billion, respectively, for
Southern Company Gas, as well as other plant in service totaling $1.1 billion and $1.0 billion, respectively, for Southern Company and
$210 million and $184 million, respectively, for Southern Company Gas. Other plant in service includes the non-utility assets of Southern
Company Gas, as well as, for Southern Company, certain other non-utility subsidiaries. Depreciation of the original cost of other plant
in service is provided primarily on a straight-line basis over estimated useful lives. Useful lives for Southern Company Gas's non-utility
assets range from five to 12 years for transportation equipment, 30 to 75 years for storage facilities, and up to 75 years for other assets.
Useful lives for the assets of Southern Company's other non-utility subsidiaries range up to 30 years.
113
Southern Company 2023 Annual Report Notes to Financial Statements
Southern Power
Southern Power applies component depreciation, where depreciation is computed principally by the straight-line method over the
estimated useful life of the asset. Certain of Southern Power's generation assets related to natural gas-fired facilities are depreciated on a
units-of-production basis, using hours or starts, to better match outage and maintenance costs to the usage of, and revenues from, these
assets. The primary assets in Southern Power's property, plant, and equipment are generating facilities, which generally have estimated
useful lives as follows:
Southern Power Generating Facility
Natural gas
Solar
Wind
Useful life
Up to 50 years
Up to 35 years
Up to 35 years
When Southern Power's depreciable property, plant, and equipment is retired, or otherwise disposed of in the normal course of business,
the applicable cost and accumulated depreciation is removed and a gain or loss is recognized in the statements of income. Southern Power
reviews its estimated useful lives and salvage values on an ongoing basis. The results of these reviews could result in changes which could
have a material impact on Southern Power's net income.
Joint Ownership Agreements
At December 31, 2023, the Registrants' percentage ownership and investment (exclusive of nuclear fuel) in jointly-owned facilities in
commercial operation were as follows:
Facility (Type)
Alabama Power
Greene County (natural gas) Units 1 and 2
Plant Miller (coal) Units 1 and 2
Georgia Power
Plant Hatch (nuclear) Units 1 and 2
Plant Vogtle (nuclear) Units 1 and 2
Plant Vogtle (nuclear) Units 3 and 4
Plant Scherer (coal) Units 1 and 2
Plant Scherer (coal) Unit 3
Rocky Mountain (pumped storage)
Mississippi Power
Greene County (natural gas) Units 1 and 2
Plant Daniel (coal) Units 1 and 2
Southern Company Gas
Dalton Pipeline (natural gas pipeline)
Percent
Ownership
Plant in
Service
Accumulated
Depreciation
CWIP
(in millions)
60.0 %(a)
91.8 (b)
$ 191
2,156
50.1 %(c)
45.7 (c)
45.7(c)(d)
8.4 (c)
75.0(c)
25.4 (e)
$1,446
3,664
4,613
287
1,310
181
$ 113
778
$ 659
2,331
19
123
639
153
$
$
1
40
70
62
3,232
2
10
—
40.0 %(a)
50.0 (f)
$ 125
805
$
80
281
$ —
1
50.0 %(g)
$ 271
$
27
$ —
(a) Jointly owned by Alabama Power and Mississippi Power and operated and maintained by Alabama Power.
(b) Jointly owned with PowerSouth and operated and maintained by Alabama Power.
(c) Georgia Power owns undivided interests in Plants Hatch, Vogtle, and Scherer in varying amounts jointly with one or more of the following entities: OPC,
MEAG Power, Dalton, FP&L, and JEA. Georgia Power has been contracted to operate and maintain the plants as agent for the co-owners and is jointly and
severally liable for third party claims related to these plants.
(d) Unit 4 remains under construction. See Note 2 under “Georgia Power – Nuclear Construction“ for additional information.
(e) Jointly owned with OPC, which is the operator of the plant.
(f) Jointly owned by FP&L and Mississippi Power. In accordance with the operating agreement, Mississippi Power acts as FP&L's agent with respect to the
operation and maintenance of these units. See Note 3 under “Other Matters – Mississippi Power – Plant Daniel“ for additional information.
(g) Jointly owned with The Williams Companies, Inc., the Dalton Pipeline is a 115-mile natural gas pipeline that serves as an extension of the Transcontinental
Gas Pipe Line Company, LLC pipeline system into northwest Georgia. Southern Company Gas leases its 50% undivided ownership for approximately
$26 million annually through 2042. The lessee is responsible for maintaining the pipeline during the lease term and for providing service to transportation
customers under its FERC-regulated tariff.
The Registrants' proportionate share of their jointly-owned facility operating expenses is included in the corresponding operating expenses
in the statements of income and each Registrant is responsible for providing its own financing.
114
Southern Company 2023 Annual Report Notes to Financial Statements
Assets Subject to Lien
Mississippi Power provides retail service to its largest retail customer, Chevron Products Company (Chevron), at its refinery in Pascagoula,
Mississippi through at least 2038 in accordance with agreements approved by the Mississippi PSC. The agreements grant Chevron a
security interest in the co-generation assets located at the refinery and owned by Mississippi Power, with a lease receivable balance of
$147 million at December 31, 2023, that is exercisable upon the occurrence of (i) certain bankruptcy events or (ii) other events of default
coupled with specific reductions in steam output at the facility and a downgrade of Mississippi Power's credit rating to below investment
grade by two of the three rating agencies. See Note 9 under “Lessor“ for additional information.
See Note 8 under “Long-term Debt“ for information regarding debt secured by certain assets of Georgia Power and Southern Company Gas.
6. ASSET RETIREMENT OBLIGATIONS
AROs are computed as the present value of the estimated costs for an asset's future retirement and are recorded in the period in which
the liability is incurred. The estimated costs are capitalized as part of the related long-lived asset and depreciated over the asset's useful
life. In the absence of quoted market prices, AROs are estimated using present value techniques in which estimates of future cash outlays
associated with the asset retirements are discounted using a credit-adjusted risk-free rate. Estimates of the timing and amounts of future
cash outlays are based on projections of when and how the assets will be retired and the cost of future removal activities. Each traditional
electric operating company and natural gas distribution utility has received accounting guidance from its state PSC or applicable state
regulatory agency allowing the continued accrual or recovery of other retirement costs for long-lived assets that it does not have a legal
obligation to retire. Accordingly, the accumulated removal costs for these obligations are reflected in the balance sheets as regulatory
liabilities and amounts to be recovered are reflected in the balance sheets as regulatory assets.
The ARO liabilities for the traditional electric operating companies primarily relate to facilities that are subject to the CCR Rule and the
related state rules, principally ash ponds. In addition, Alabama Power and Georgia Power have retirement obligations related to the
decommissioning of nuclear facilities (Alabama Power's Plant Farley and Georgia Power's ownership interests in Plant Hatch and Plant
Vogtle Units 1 through 3). See “Nuclear Decommissioning“ herein for additional information. Other significant AROs include various
landfill sites and asbestos removal for Alabama Power, Georgia Power, and Mississippi Power and gypsum cells and mine reclamation for
Mississippi Power. The ARO liability for Southern Power primarily relates to its solar and wind facilities, which are located on long-term land
leases requiring the restoration of land at the end of the lease.
The traditional electric operating companies and Southern Company Gas also have identified other retirement obligations, such as
obligations related to certain electric transmission and distribution facilities, certain asbestos-containing material within long-term assets
not subject to ongoing repair and maintenance activities, certain wireless communication towers, the disposal of polychlorinated biphenyls
in certain transformers, leasehold improvements, equipment on customer property, and property associated with the Southern Company
system's rail lines and natural gas pipelines. However, liabilities for the removal of these assets have not been recorded because the
settlement timing for certain retirement obligations related to these assets is indeterminable and, therefore, the fair value of the retirement
obligations cannot be reasonably estimated. A liability for these retirement obligations will be recognized when sufficient information
becomes available to support a reasonable estimation of the ARO.
Southern Company and the traditional electric operating companies will continue to recognize in their respective statements of income
allowed removal costs in accordance with regulatory treatment. Any differences between costs recognized in accordance with accounting
standards related to asset retirement and environmental obligations and those reflected in rates are recognized as either a regulatory asset
or liability in the balance sheets as ordered by the various state PSCs.
115
Southern Company 2023 Annual Report Notes to Financial Statements
Details of the AROs included in the balance sheets are as follows:
Balance at December 31, 2021
$ 11,687
$ 4,334
$ 6,824
$ 190
$131
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power(*)
(in millions)
Liabilities incurred
Liabilities settled
Accretion expense
Cash flow revisions
Balance at December 31, 2022
Liabilities incurred
Liabilities settled
Accretion expense
Cash flow revisions
Balance at December 31, 2023
36
(455)
406
(834)
$ 10,840
90
(617)
403
(399)
—
(205)
158
—
$4,287
—
(270)
156
(15)
35
(212)
231
(844)
$ 6,034
90
(304)
230
(385)
—
(20)
6
3
$ 179
—
(18)
5
2
—
—
6
7
$144
—
—
6
—
$ 10,317
$4,158
$ 5,665
$ 168
$150
(*) Included in other deferred credits and liabilities on Southern Power's consolidated balance sheets.
In December 2022, Georgia Power recorded a net decrease of approximately $780 million to its AROs related to the CCR Rule and the
related state rule resulting from changes in estimates, including lower future inflation rates, higher discount rates, and timing of closure
activities, as well as a change in closure methodology for one ash pond as approved in Georgia Power's 2022 IRP.
Following initial criticality for Plant Vogtle Unit 3 on March 6, 2023, Georgia Power recorded AROs of approximately $90 million.
Subsequent to December 31, 2023, Plant Vogtle Unit 4 achieved initial criticality, which will result in Georgia Power recording
AROs of approximately $118 million during the first quarter 2024. See Note 2 under “Georgia Power – Nuclear Construction“ for
additional information.
In September 2023 and November 2023, Georgia Power recorded net decreases of approximately $175 million and $210 million,
respectively, to its AROs related to the CCR Rule and the related state rule resulting from changes in estimates, including lower future
inflation rates and the timing of closure activities.
In June 2023, Alabama Power completed an updated decommissioning cost site study for Plant Farley. The estimated cost of
decommissioning based on the study resulted in a decrease in Alabama Power's ARO liability of approximately $15 million. See “Nuclear
Decommissioning“ herein for additional information.
The cost estimates for AROs related to the disposal of CCR are based on information at December 31, 2023 using various assumptions
related to closure and post-closure costs, timing of future cash outlays, inflation and discount rates, and the potential methods for
complying with the CCR Rule and the related state rules. The traditional electric operating companies have periodically updated, and
expect to continue periodically updating, their related cost estimates and ARO liabilities for each CCR unit as additional information related
to these assumptions becomes available. Some of these updates have been, and future updates may be, material. The cost estimates for
Alabama Power are based on closure-in-place for all ash ponds. The cost estimates for Georgia Power and Mississippi Power are based
on a combination of closure-in-place for some ash ponds and closure by removal for others. Additionally, the closure designs and plans
in the States of Alabama and Georgia are subject to approval by environmental regulatory agencies. Absent continued recovery of ARO
costs through regulated rates, results of operations, cash flows, and financial condition for Southern Company and the traditional electric
operating companies could be materially impacted. The ultimate outcome of these matters cannot be determined at this time. See Note 3
under “General Litigation Matters – Alabama Power“ for additional information.
Nuclear Decommissioning
The NRC requires licensees of commercial nuclear power reactors to establish a plan for providing reasonable assurance of funds for future
decommissioning. Alabama Power and Georgia Power have external trust funds (Funds) to comply with the NRC's regulations. Use of the
Funds is restricted to nuclear decommissioning activities. The Funds are managed and invested in accordance with applicable requirements
of various regulatory bodies, including the NRC, the FERC, and state PSCs, as well as the IRS. While Alabama Power and Georgia Power are
allowed to prescribe an overall investment policy to the Funds' managers, neither Southern Company nor its subsidiaries or affiliates are
allowed to engage in the day-to-day management of the Funds or to mandate individual investment decisions. Day-to-day management
of the investments in the Funds is delegated to unrelated third-party managers with oversight by the management of Alabama Power and
Georgia Power. The Funds' managers are authorized, within certain investment guidelines, to actively buy and sell securities at their own
discretion in order to maximize the return on the Funds' investments. The Funds are invested in a tax-efficient manner in a diversified mix
of equity and fixed income securities and are reported as trading securities.
116
Southern Company 2023 Annual Report Notes to Financial Statements
Alabama Power and Georgia Power record the investment securities held in the Funds at fair value, as disclosed in Note 13, as management
believes that fair value best represents the nature of the Funds. Gains and losses, whether realized or unrealized, are recorded in the
regulatory liability for AROs in the balance sheets and are not included in net income or OCI. Fair value adjustments and realized gains and
losses are determined on a specific identification basis.
Investment securities in the Funds for December 31, 2023 and 2022 were as follows:
At December 31, 2023:
Equity securities
Debt securities
Other securities
Total investment securities in the Funds
At December 31, 2022:
Equity securities
Debt securities
Other securities
Total investment securities in the Funds(*)
Southern
Company
Alabama
Power
(in millions)
$ 1,288
895
239
$ 2,422
$ 1,095
838
210
$ 2,143
$ 796
277
186
$1,259
$ 690
267
168
$1,125
Georgia
Power
$ 492
618
53
$ 1,163
$ 405
571
42
$ 1,018
(*) For Southern Company and Georgia Power, these amounts include investment securities pledged to creditors and collateral received and excludes payables
related to a securities lending program Georgia Power's Funds previously participated in through the managers of the Funds. Under this program, Georgia
Power's Funds' investment securities were loaned to institutional investors for a fee. Securities loaned were fully collateralized by cash, letters of credit,
and/or securities issued or guaranteed by the U.S. government or its agencies or instrumentalities. At December 31, 2022, approximately $35 million of
the fair market value of Georgia Power's Funds' securities were on loan and pledged to creditors under the Funds' managers' securities lending program.
At December 31, 2022, the fair value of the collateral received was approximately $36 million and could only be sold by the borrower upon the return of
the loaned securities. The collateral received was treated as a non-cash item in the statements of cash flows.
These amounts exclude receivables related to investment income and pending investment sales and payables related to pending
investment purchases.
The fair value increases (decreases) of the Funds, including unrealized gains (losses) and reinvested interest and dividends and excluding the
Funds' expenses, for 2023, 2022, and 2021 are shown in the table below.
Fair value increases (decreases)
2023
2022
2021
Unrealized gains (losses)
At December 31, 2023
At December 31, 2022
At December 31, 2021
Southern
Company
$ 281
(360)
274
$ 241
(391)
(27)
Alabama
Power
(in millions)
$ 157
(171)
200
$ 119
(204)
(30)
Georgia
Power
$ 124
(189)
74
$ 122
(187)
3
The investment securities held in the Funds continue to be managed with a long-term focus. Accordingly, all purchases and sales within the
Funds are presented separately in the statements of cash flows as investing cash flows, consistent with the nature of the securities and
purpose for which the securities were acquired.
For Alabama Power, approximately $13 million and $14 million at December 31, 2023 and 2022, respectively, previously recorded in
internal reserves is being transferred into the Funds through 2040 as approved by the Alabama PSC.
The NRC's minimum external funding requirements are based on a generic estimate of the cost to decommission only the radioactive
portions of a nuclear unit based on the size and type of reactor. Alabama Power and Georgia Power have filed plans with the NRC designed
to ensure that, over time, the deposits and earnings of the Funds will provide the minimum funding amounts prescribed by the NRC.
117
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2023 and 2022, the accumulated provisions for the external decommissioning trust funds were as follows:
Alabama Power
Plant Farley
Georgia Power
Plant Hatch
Plant Vogtle Units 1 and 2
Plant Vogtle Units 3 and 4
Total
2023
2022
(in millions)
$1,259
$ 1,125
$ 705
$ 628
434
24
382
8
$1,163
$ 1,018
Site study cost is the estimate to decommission a specific facility as of the site study year. The decommissioning cost estimates are based
on removal of the plant from service and prompt dismantlement. The actual decommissioning costs may vary from these estimates
because of changes in the assumed date of decommissioning, changes in NRC requirements, or changes in the assumptions used in making
these estimates. The estimated costs of decommissioning at December 31, 2023 based on the most current studies were as follows:
Alabama Power
Georgia Power
Most current study year
Decommissioning periods:
Beginning year
Completion year
Site study costs:
Radiated structures
Spent fuel management
Non-radiated structures
Total site study costs
(*) Based on Georgia Power's ownership interests.
Plant
Hatch(*)
Plant Vogtle
Units 1 and 2(*)
Plant Vogtle
Unit 3(*)
Plant
Farley
2023
2037
2087
2021
2034
2075
(in millions)
$ 1,402
513
133
$ 2,048
$
771
186
61
$ 1,018
2021
2047
2079
$ 628
170
85
$ 883
2020
2063
2074
$ 284
30
33
$ 347
For ratemaking purposes, Alabama Power's decommissioning costs are based on the site study and Georgia Power's decommissioning costs
are based on the NRC generic estimate to decommission the radioactive portion of the facilities and the site study estimate for spent fuel
management. Significant assumptions used to determine these costs for ratemaking were an estimated inflation rate of 4.5% for Plant Farley,
2.5% for Plants Hatch and Vogtle Units 1 and 2, and 2.4% for Plant Vogtle Unit 3 and an estimated trust earnings rate of 7.0% for Plant Farley,
4.5% for Plants Hatch and Vogtle Units 1 and 2, and 4.4% for Plant Vogtle Unit 3.
Amounts previously contributed to the Funds for Plant Farley are currently projected to be adequate to meet the decommissioning obligations.
Alabama Power's site-specific estimates of decommissioning costs for Plant Farley are updated every five years. The next site study for
Alabama Power is expected to be completed in 2028. Projections of funds are reviewed with the Alabama PSC to ensure that, over time, the
deposits and earnings of the Funds will provide adequate funding to cover the site-specific costs. If necessary, Alabama Power would seek the
Alabama PSC's approval to address any changes in a manner consistent with NRC and other applicable requirements.
Under the 2019 ARP, Georgia Power's annual decommissioning cost for ratemaking in 2021 and 2022 was a total of $4 million for Plant
Hatch and Plant Vogtle Units 1 and 2. Effective January 1, 2023, as approved in the 2022 ARP, there is no annual decommissioning cost for
ratemaking for Plant Hatch and Plant Vogtle Units 1 and 2. Any funding amount required by the NRC during the period covered by the 2022
ARP will be deferred to a regulatory asset and recovery is expected to be determined in Georgia Power's next base rate case. See Note 2 under
“Georgia Power – Rate Plans – 2022 ARP“ for additional information. Effective August 1, 2023, as approved under the Plant Vogtle Unit 3
and Common Facilities rate proceeding, Georgia Power's annual decommissioning cost for ratemaking is $8 million for Plant Vogtle Unit 3.
See Note 2 under “Georgia Power – Nuclear Construction – Regulatory Matters“ for additional information.
118
Southern Company 2023 Annual Report Notes to Financial Statements
7. CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS
The Registrants may hold ownership interests in a number of business ventures with varying ownership structures. Partnership interests
and other variable interests are evaluated to determine if each entity is a VIE. If a venture is a VIE for which a Registrant is the primary
beneficiary, the assets, liabilities, and results of operations of the entity are consolidated. The Registrants reassess the conclusion as to
whether an entity is a VIE upon certain occurrences, which are deemed reconsideration events.
For entities that are not determined to be VIEs, the Registrants evaluate whether they have control or significant influence over the
investee to determine the appropriate consolidation and presentation. Generally, entities under the control of a Registrant are consolidated,
and entities over which a Registrant can exert significant influence, but which a Registrant does not control, are accounted for under the
equity method of accounting.
Investments accounted for under the equity method are recorded within equity investments in unconsolidated subsidiaries in the balance
sheets and, for Southern Company and Southern Company Gas, the equity income is recorded within earnings from equity method
investments in the statements of income. See “SEGCO“ and “Southern Company Gas“ herein for additional information.
Southern Company
At December 31, 2023 and 2022, Southern Holdings had equity method investments totaling $126 million and $112 million, respectively,
primarily related to investments in venture capital funds focused on energy and utility investments. Earnings from these investments were
immaterial for all periods presented.
SEGCO
Alabama Power and Georgia Power own equally all of the outstanding capital stock of SEGCO, which owns electric generating units at
Plant Gaston with a total rated capacity of 1,020 MWs, as well as associated transmission facilities. Retirement of SEGCO's generating
units is currently expected to occur by December 31, 2028. However, Alabama Power, in conjunction with Georgia Power, is evaluating
extending the operation of Plant Gaston Units 1 through 4 beyond the indicated retirement date. See Note 2 under “Georgia Power –
Integrated Resource Plans“ for additional information. Alabama Power and Georgia Power account for SEGCO using the equity method;
Southern Company consolidates SEGCO. The capacity of these units is sold equally to Alabama Power and Georgia Power. Alabama Power
and Georgia Power make payments sufficient to provide for the operating expenses, taxes, interest expense, and a ROE. The share of
purchased power included in purchased power, affiliates in the statements of income totaled $112 million in 2023, $124 million in 2022,
and $75 million in 2021 for Alabama Power and $115 million in 2023, $127 million in 2022, and $77 million in 2021 for Georgia Power.
SEGCO paid dividends of $25 million in 2023, $14 million in 2022, and $14 million in 2021, one half of which were paid to each of
Alabama Power and Georgia Power. In addition, Alabama Power and Georgia Power each recognize 50% of SEGCO's net income.
Alabama Power, which owns and operates a generating unit adjacent to the SEGCO generating units, has a joint ownership agreement
with SEGCO for the ownership of an associated gas pipeline. Alabama Power owns 14% of the pipeline with the remaining 86%
owned by SEGCO.
See Note 3 under “Guarantees“ for additional information regarding guarantees of Alabama Power and Georgia Power related to SEGCO.
Southern Power
Variable Interest Entities
Southern Power has certain subsidiaries that are determined to be VIEs. Southern Power is considered the primary beneficiary of these
VIEs because it controls the most significant activities of the VIEs, including operating and maintaining the respective assets, and has the
obligation to absorb expected losses of these VIEs to the extent of its equity interests.
SP Solar and SP Wind
SP Solar is owned by Southern Power and a limited partner. A wholly-owned subsidiary of Southern Power is the general partner and holds
a 1% ownership interest, and another wholly-owned subsidiary of Southern Power owns a 66% ownership interest. The limited partner
holds the remaining 33% noncontrolling interest. SP Solar qualifies as a VIE since the arrangement is structured as a limited partnership and
the 33% limited partner does not have substantive kick-out rights against the general partner.
At December 31, 2023 and 2022, SP Solar had total assets of $5.6 billion and $5.9 billion, respectively, total liabilities of $0.4 billion, and
noncontrolling interests of $1.0 billion and $1.1 billion, respectively. Cash distributions from SP Solar are allocated 67% to Southern Power and
33% to the limited partner in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement,
distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its
partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves.
119
Southern Company 2023 Annual Report Notes to Financial Statements
SP Wind is owned by Southern Power and three financial investors. A wholly-owned subsidiary of Southern Power owns 100% of the
Class B membership interests and the three financial investors own 100% of the Class A membership interests. SP Wind qualifies as a VIE
since the structure of the arrangement is similar to a limited partnership and the Class A members do not have substantive kick-out rights
against Southern Power.
At December 31, 2023 and 2022, SP Wind had total assets of $2.1 billion and $2.2 billion, respectively, total liabilities of $187 million
and $169 million, respectively, and noncontrolling interests of $38 million and $39 million, respectively. Under the terms of the limited
liability agreement, distributions without Class A member consent are limited to available cash and SP Wind is obligated to distribute all
such available cash to its members each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of
appropriate operating reserves. Cash distributions from SP Wind are generally allocated 60% to Southern Power and 40% to the three
financial investors in accordance with the limited liability agreement.
Southern Power consolidates both SP Solar and SP Wind, as the primary beneficiary, since it controls the most significant activities of each
entity, including operating and maintaining their assets. Certain transfers and sales of the assets in the VIEs are subject to partner consent
and the liabilities are non-recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do
not include any long-term debt.
Other Variable Interest Entities
Southern Power has other consolidated VIEs that relate to certain subsidiaries that have either sold noncontrolling interests to tax equity
investors or acquired less than a 100% interest from facility developers. These entities are considered VIEs because the arrangements are
structured similar to a limited partnership and the noncontrolling members do not have substantive kick-out rights.
At December 31, 2023 and 2022, the other VIEs had total assets of $1.7 billion and $1.8 billion, respectively, total liabilities of $0.2 billion, and
noncontrolling interests of $0.8 billion. Under the terms of the partnership agreements, distributions of all available cash are required each
month or quarter and additional distributions require partner consent.
Equity Method Investments
During 2023 and 2022, Southern Power sold its remaining equity method investments in wind projects and received proceeds totaling
$50 million and $38 million, respectively. Earnings (loss) from these investments, including the gains associated with the sales, were
immaterial for all periods presented.
Southern Company Gas
Equity Method Investments
The carrying amounts of Southern Company Gas' equity method investments at December 31, 2023 and 2022 and related earnings (loss)
from those investments for the years ended December 31, 2023, 2022, and 2021 were as follows:
Investment Balance
SNG
Other
Total
Earnings (Loss) from Equity Method Investments
SNG
PennEast Pipeline(*)
Other
Total
December 31, 2023
December 31, 2022
(in millions)
$1,202
33
$1,235
2023
$139
—
1
$140
$ 1,243
33
$ 1,276
2021
$127
(81)
4
$ 50
2022
(in millions)
$146
—
2
$148
(*) For 2021, includes pre-tax impairment charges totaling $84 million. See “PennEast Pipeline Project“ herein for additional information, including the September
2021 cancellation of the project.
120
Southern Company 2023 Annual Report Notes to Financial Statements
PennEast Pipeline Project
In 2014, Southern Company Gas entered into a partnership in which it holds a 20% ownership interest in the PennEast Pipeline, an
interstate pipeline company formed to develop and operate an approximate 118-mile natural gas pipeline between New Jersey and
Pennsylvania. In 2019, an appellate court ruled that the PennEast Pipeline does not have federal eminent domain authority over lands in
which a state has property rights interests. In June 2021, the U.S. Supreme Court ruled in favor of PennEast Pipeline following a review of
the appellate court decision. Southern Company Gas assesses its equity method investments for impairment whenever events or changes
in circumstances indicate that the investment may be impaired. Following the U.S. Supreme Court ruling, during the second quarter
2021, Southern Company Gas management reassessed the project construction timing, including the anticipated timing for receipt of a
FERC certificate and all remaining state and local permits, as well as potential challenges thereto, and performed an impairment analysis.
The outcome of the analysis resulted in a pre-tax impairment charge of $82 million ($58 million after tax). In September 2021, PennEast
Pipeline announced that further development of the project was no longer supported, and, as a result, all further development of the
project ceased. During the third quarter 2021, Southern Company Gas recorded an additional pre-tax charge of $2 million ($2 million after
tax) related to its share of the project level impairment, as well as $7 million of additional tax expense, resulting in total pre-tax charges of
$84 million ($67 million after tax) during 2021 related to the project.
121
Southern Company 2023 Annual Report Notes to Financial Statements
8. FINANCING
Long-term Debt
Details of long-term debt at December 31, 2023 and 2022 are provided in the following table:
At December 31, 2023
Maturity
Weighted Average
Interest Rate
Balance Outstanding at
December 31,
2023
2022
(in millions)
2024-2073
2024-2081
2024-2044
2024-2063
2025-2063
2026-2027
2024-2045
4.16%
4.33%
2.88%
3.77%
3.64%
7.03%
5.44%
2025-2073
2024-2063
2026-2030
3.95%
3.94%
7.04%
2024-2052
2077
2024-2044
2025-2062
4.34%
5.00%
2.88%
3.64%
$40,235
8,333
4,788
3,400
2,500
84
234
298
302
(198)
(290)
59,686
2,476
$57,210
$ 9,875
1,321
75
5
(20)
(73)
11,183
223
$10,960
$ 9,575
270
4,788
1,968
240
(19)
(122)
16,700
502
$16,198
$35,683
8,836
4,874
2,844
2,275
84
167
314
330
(193)
(273)
54,941
4,285
$50,656
$ 9,675
995
45
5
(18)
(72)
10,630
301
$10,329
$ 7,925
270
4,874
1,738
238
(18)
(117)
14,910
901
$14,009
Southern Company
Senior notes(a)
Junior subordinated notes
FFB loans(b)
Revenue bonds(c)
First mortgage bonds(d)
Medium-term notes
Other long-term debt
Finance lease obligations(e)
Unamortized fair value adjustment
Unamortized debt premium (discount), net
Unamortized debt issuance expenses
Total long-term debt
Less: Amount due within one year
Total long-term debt excluding amount due within one year
Alabama Power
Senior notes
Revenue bonds(c)
Other long-term debt
Finance lease obligations(e)
Unamortized debt premium (discount), net
Unamortized debt issuance expenses
Total long-term debt
Less: Amount due within one year
Total long-term debt excluding amount due within one year
Georgia Power
Senior notes
Junior subordinated notes
FFB loans(b)
Revenue bonds(c)
Finance lease obligations(e)
Unamortized debt premium (discount), net
Unamortized debt issuance expenses
Total long-term debt
Less: Amount due within one year
Total long-term debt excluding amount due within one year
122
Southern Company 2023 Annual Report
Notes to Financial Statements
Mississippi Power
Senior notes
Revenue bonds(c)
Finance lease obligations(e)
Unamortized debt premium (discount), net
Unamortized debt issuance expenses
Total long-term debt
Less: Amount due within one year
Total long-term debt excluding amount due within one year
Southern Power
Senior notes(a)
Unamortized debt premium (discount), net
Unamortized debt issuance expenses
Total long-term debt
Less: Amount due within one year
Total long-term debt excluding amount due within one year
Southern Company Gas
Senior notes
First mortgage bonds(d)
Medium-term notes
Other long-term debt
Unamortized fair value adjustment
Unamortized debt premium (discount), net
Unamortized debt issuance expenses
Total long-term debt
Less: Amount due within one year
Total long-term debt excluding amount due within one year
At December 31, 2023
Maturity
Weighted Average
Interest Rate
Balance Outstanding at
December 31,
2023
2022
(in millions)
2024-2051
2025-2052
4.27%
4.08%
2025-2046
4.05%
2025-2051
2025-2063
2026-2027
2024-2045
4.36%
3.64%
7.03%
3.81%
$ 1,525
111
16
1
(9)
1,644
201
$ 1,443
$ 2,728
(4)
(13)
2,711
—
$ 2,711
$ 4,930
2,500
84
59
302
(8)
(34)
7,833
—
$ 7,833
$ 1,425
111
17
2
(10)
1,545
1
$ 1,544
$ 2,998
(5)
(14)
2,979
290
$ 2,689
$ 4,769
2,275
84
22
330
(8)
(30)
7,442
400
$ 7,042
(a) Includes a fair value gain (loss) of $(12) million and $(31) million at December 31, 2023 and 2022, respectively, related to Southern Power’s foreign currency
hedge on its euro-denominated senior notes.
(b) Secured by a first priority lien on (i) Georgia Power’s undivided ownership interest in Plant Vogtle Units 3 and 4 (primarily the units, 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. See “DOE Loan Guarantee Borrowings” herein for additional information.
(c) Revenue bond obligations represent loans to the traditional electric operating companies from public authorities of funds derived from sales by such
authorities of revenue bonds issued to finance pollution control and solid waste disposal and wastewater facilities. In some cases, the revenue bond
obligations represent obligations under installment sales agreements with respect to facilities constructed with the proceeds of revenue bonds issued by
public authorities. The traditional electric operating companies are required to make payments sufficient for the authorities to meet principal and interest
requirements of such bonds. Proceeds from certain issuances are restricted until qualifying expenditures are incurred.
(d) Secured by substantially all of Nicor Gas’ properties.
(e) Secured by the underlying lease ROU asset. See Note 9 for additional information.
123
Southern Company 2023 Annual Report
Notes to Financial Statements
Maturities of long-term debt for the next five years are as follows:
2024
2025
2026
2027
2028
Southern
Company(a)
Alabama
Power(b)
Georgia
Power(c)
Mississippi
Power
Southern
Power(d)
Southern
Company Gas
$2,480
4,124
3,791
2,075
2,612
$223
251
46
551
107
(in millions)
$503
849
448
512
864
$201
12
66
10
357
$ —
500
964
—
—
$ —
300
530
154
150
(a) See notes (b) and (c) below.
(b) Alabama Power’s 2024 maturities include $200 million aggregate principal amount of Series 2023A Floating Rate Senior Notes due May 15, 2073 that are
repayable at the option of the holders at certain dates beginning in 2024. As a result, the senior notes are classified as securities due within one year on the
balance sheets of Southern Company and Alabama Power at December 31, 2023.
(c) Amounts include principal amortization related to the FFB borrowings; however, the final maturity date is February 20, 2044. See “DOE Loan Guarantee
Borrowings” herein for additional information.
(d) Southern Power’s 2026 maturities include $564 million of euro-denominated debt at the U.S. dollar denominated hedge settlement amount.
DOE Loan Guarantee Borrowings
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 2019. Under the Amended and Restated Loan Guarantee Agreement, the DOE agreed to guarantee the obligations of Georgia Power
under the FFB Credit Facilities. Under the FFB Credit Facilities, Georgia Power was authorized to 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 could 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 related customer refunds).
In 2021, Georgia Power made the final borrowings under the FFB Credit Facilities and no further borrowings are permitted. During 2023,
Georgia Power made principal amortization payments of $86 million under the FFB Credit Facilities. At December 31, 2023 and 2022,
Georgia Power had $4.8 billion and $4.9 billion of borrowings outstanding under the FFB Credit Facilities, respectively.
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 undivided ownership interest in Plant Vogtle Units 3 and 4
(primarily the units, 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.
The final maturity date for each advance under the FFB Credit Facilities is February 20, 2044. Interest is payable quarterly and principal
payments began in 2020. Each borrowing under the FFB Credit Facilities bears interest at a fixed rate equal to the applicable U.S. Treasury
rate at the time of the borrowing 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, 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 by Bechtel or in connection with a cancellation of Plant Vogtle Units 3 and 4,
unless the Vogtle Owners enter into a replacement agreement; (iii) cancellation of Plant Vogtle Unit 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 Unit 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. 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.
124
Southern Company 2023 Annual Report Notes to Financial Statements
In connection with any cancellation of Plant Vogtle Unit 4, the DOE may elect to continue construction of Plant Vogtle Unit 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.
See Note 2 under “Georgia Power – Nuclear Construction” for additional information.
Secured Debt
Each of Southern Company’s subsidiaries is organized as a legal entity, separate and apart from Southern Company and its other
subsidiaries. There are no agreements or other arrangements among the Southern Company system companies under which the assets of
one company have been pledged or otherwise made available to satisfy obligations of Southern Company or any of its other subsidiaries.
As discussed under “Long-term Debt” herein, the Registrants had secured debt outstanding at December 31, 2023 and 2022. Each Registrant’s
senior notes, junior subordinated notes, revenue bond obligations, bank term loans, credit facility borrowings, and notes payable are effectively
subordinated to all secured debt of each respective Registrant.
Equity Units
In May 2022, Southern Company remarketed $862.5 million aggregate principal amount of its Series 2019A Remarketable Junior Subordinated
Notes due August 1, 2024 (2019A RSNs) and $862.5 million aggregate principal amount of its Series 2019B Remarketable Junior Subordinated
Notes due August 1, 2027 (2019B RSNs), pursuant to the terms of its 2019 Series A Equity Units (Equity Units). In connection with the
remarketing, the interest rates on the 2019A RSNs and the 2019B RSNs were reset to 4.475% and 5.113%, respectively, payable on a
semi-annual basis. In August 2022, the proceeds were ultimately used to settle the purchase contracts entered into as part of the Equity Units
and Southern Company issued approximately 25.2 million shares of common stock and received proceeds of $1.725 billion. At December 31,
2023 and 2022, the 2019A RSNs and the 2019B RSNs are included on Southern Company’s consolidated balance sheets in long-term debt or,
as applicable, securities due within one year.
Convertible Senior Notes
In February 2023, Southern Company issued $1.5 billion aggregate principal amount of Series 2023A 3.875% Convertible Senior Notes due
December 15, 2025 (Series 2023A Convertible Senior Notes). In March 2023, Southern Company issued an additional $225 million aggregate
principal amount of the Series 2023A Convertible Senior Notes upon the exercise by the initial purchasers of their over-allotment option.
Interest on the Series 2023A Convertible Senior Notes is payable semiannually, which began on June 15, 2023. The Series 2023A
Convertible Senior Notes will mature on December 15, 2025, unless earlier converted or repurchased, but are not redeemable at the
option of Southern Company. The Series 2023A Convertible Senior Notes are direct, unsecured, and unsubordinated obligations of
Southern Company, ranking equally with all of Southern Company’s other unsecured and unsubordinated indebtedness from time to time
outstanding, and are effectively subordinated to all secured indebtedness of Southern Company.
Holders may convert their Series 2023A Convertible Senior Notes at their option prior to the close of business on the business day
preceding September 15, 2025, but only under the following circumstances:
O during any calendar quarter (and only during such calendar quarter), if the last reported sale price of Southern Company’s common
stock for at least 20 trading days (whether or not consecutive) during the period of 30 consecutive trading days ending on, and
including, the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price
on each applicable trading day as determined by Southern Company;
O during the five business day period after any 10 consecutive trading day period (Measurement Period) in which the trading price per
$1,000 principal amount of Series 2023A Convertible Senior Notes for each trading day of the Measurement Period was less than 98%
of the product of the last reported sale price of the common stock and the conversion rate on each such trading day; or
O upon the occurrence of certain corporate events specified in the indenture governing the Series 2023A Convertible Senior Notes.
On or after September 15, 2025, a holder may convert all or any portion of its Series 2023A Convertible Senior Notes at any time prior to
the close of business on the second scheduled trading day immediately preceding the maturity date regardless of the foregoing conditions.
Southern Company will settle conversions of the Series 2023A Convertible Senior Notes by paying cash up to the aggregate principal
amount of the Series 2023A Convertible Senior Notes to be converted and paying or delivering, as the case may be, cash, shares of
common stock or a combination of cash and shares of common stock, at Southern Company’s election, in respect of the remainder, if any,
of Southern Company’s conversion obligation in excess of the aggregate principal amount of the Series 2023A Convertible Senior Notes
being converted. The Series 2023A Convertible Senior Notes are initially convertible at a rate of 11.8818 shares of common stock per
$1,000 principal amount converted, which is approximately equal to $84.16 per share of common stock. The conversion rate will be subject
125
Southern Company 2023 Annual Report Notes to Financial Statements
to adjustment upon the occurrence of certain specified events but will not be adjusted for accrued and unpaid interest. In addition, upon
the occurrence of a make-whole fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes),
Southern Company will, in certain circumstances, increase the conversion rate by a number of additional shares of common stock for
conversions in connection with the make-whole fundamental change.
Upon the occurrence of a fundamental change (as defined in the indenture governing the Series 2023A Convertible Senior Notes), holders
of the Series 2023A Convertible Senior Notes may require Southern Company to purchase all or a portion of their Series 2023A Convertible
Senior Notes, in principal amounts equal to $1,000 or an integral multiple thereof, for cash at a price equal to 100% of the principal
amount of the Series 2023A Convertible Senior Notes to be purchased plus any accrued and unpaid interest.
Bank Credit Arrangements
At December 31, 2023, committed credit arrangements with banks were as follows:
Expires
Company
2024
2025
2026
2028
Total
Unused
Southern Company parent(a)
Alabama Power
Georgia Power
Mississippi Power
Southern Power(a)(b)
Southern Company Gas(c)
SEGCO
Southern Company
$150
—
—
—
—
100
30
$280
$ —
—
—
125
—
—
—
$125
$ —
650
—
150
—
—
—
$800
(in millions)
$1,850
700
1,750
—
600
1,500
—
$6,400
$2,000
1,350
1,750
275
600
1,600
30
$7,605
$1,998
1,350
1,726
275
589
1,598
30
$7,566
Expires
within
One Year
$150
—
—
—
—
100
30
$280
(a) Arrangement expiring in 2028 represents a $2.45 billion combined arrangement for Southern Company and Southern Power as borrowers. Pursuant to the
combined facility, the allocations between Southern Company and Southern Power may be adjusted.
(b) Does not include Southern Power Company’s $75 million and $100 million continuing letter of credit facilities for standby letters of credit, expiring in 2025
and 2026, respectively, of which $8 million and $7 million, respectively, was unused at December 31, 2023. Southern Power’s subsidiaries are not parties to
its bank credit arrangements or letter of credit facilities.
(c) Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $800 million of
the credit arrangement expiring in 2028. Southern Company Gas’ committed credit arrangement expiring in 2028 also includes $700 million for which
Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the multi-year credit arrangement expiring in 2028,
the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted. Nicor Gas is also the borrower under a $100 million credit
arrangement expiring in 2024. See “Structural Considerations” herein for additional information.
The bank credit arrangements require payment of commitment fees based on the unused portion of the commitments. Commitment
fees average less than 1/4 of 1% for the Registrants and Nicor Gas. Subject to applicable market conditions, Southern Company and its
subsidiaries expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, Southern
Company and its subsidiaries may extend the maturity dates and/or increase or decrease the lending commitments thereunder.
These bank credit arrangements, as well as the term loan arrangements of the Registrants, Nicor Gas, and SEGCO, contain covenants
that limit debt levels and contain cross-acceleration provisions to other indebtedness (including guarantee obligations) that are restricted
only to the indebtedness of the individual company. The cross-acceleration provisions to other indebtedness would trigger an event of
default if the applicable borrower defaulted on indebtedness, the payment of which was then accelerated. Southern Company’s, certain
of Mississippi Power’s, Southern Company Gas’, and Nicor Gas’ credit arrangements contain covenants that limit debt levels to 70% of
total capitalization, as defined in the agreements, and the other subsidiaries’ bank credit arrangements contain covenants that limit debt
levels to 65% of total capitalization, as defined in the agreements. For purposes of these definitions, debt excludes junior subordinated
notes and, in certain arrangements, other hybrid securities. Additionally, for Southern Company and Southern Power, for purposes of these
definitions, 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 subsidiaries. At December 31, 2023, the
Registrants, Nicor Gas, and SEGCO were in compliance with all such covenants. None of the bank credit arrangements contain material
adverse change clauses at the time of borrowings.
A portion of the unused credit with banks is allocated to provide liquidity support to certain revenue bonds of the traditional electric
operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. At December 31, 2023, outstanding
variable rate demand revenue bonds of the traditional electric operating companies with allocated liquidity support totaled approximately
126
Southern Company 2023 Annual Report Notes to Financial Statements
$1.7 billion (comprised of approximately $818 million at Alabama Power, $819 million at Georgia Power, and $69 million at Mississippi
Power). In addition, at December 31, 2023, Georgia Power had approximately $325 million of fixed rate revenue bonds outstanding that
are required to be remarketed within the next 12 months. The variable rate demand revenue bonds and fixed rate revenue bonds required
to be remarketed within the next 12 months are classified as long-term debt on the balance sheets as a result of available long-term
committed credit.
At both December 31, 2023 and 2022, Southern Power had $106 million of cash collateral posted related to PPA requirements, which is
included in other deferred charges and assets on Southern Power’s consolidated balance sheets.
Notes Payable
The Registrants, Nicor Gas, and SEGCO make short-term borrowings primarily through commercial paper programs that have the liquidity
support of the committed bank credit arrangements described above under “Bank Credit Arrangements.” Southern Power’s subsidiaries
are not parties or obligors to its commercial paper program. Southern Company Gas maintains commercial paper programs at Southern
Company Gas Capital and at Nicor Gas. Nicor Gas’ commercial paper program supports working capital needs at Nicor Gas as Nicor Gas is
not permitted to make money pool loans to affiliates. All of Southern Company Gas’ other subsidiaries benefit from Southern Company
Gas Capital’s commercial paper program. See “Structural Considerations” herein for additional information.
In addition, Southern Company and certain of its subsidiaries have entered into various bank term loan agreements. Unless otherwise
stated, the proceeds of these loans were used to repay existing indebtedness and for general corporate purposes, including working capital
and, for the subsidiaries, their continuous construction programs.
Commercial paper and short-term bank term loans are included in notes payable in the balance sheets. Details of short-term borrowings for
the applicable Registrants were as follows:
Notes Payable at December 31, 2023
Notes Payable at December 31, 2022
Weighted Average
Interest Rate
Southern Company
Commercial paper
Short-term bank debt
Total
Alabama Power
Commercial paper
Georgia Power
Commercial paper
Short-term bank debt
Total
Southern Power
Commercial paper
Southern Company Gas
Commercial paper:
Southern Company Gas Capital
Nicor Gas
Short-term bank debt:
Nicor Gas
Total
Amount
Outstanding
(in millions)
$ 1,794
520
$ 2,314
Weighted Average
Interest Rate
5.6%
6.4%
5.7%
Amount
Outstanding
(in millions)
$ 809
1,800
$2,609
$
40
5.5%
$ —
$
809
520
$ 1,329
5.6%
6.4%
5.9%
$ —
1,600
$1,600
$
138
5.5%
$ 225
$
$
23
392
—
415
5.5%
5.5%
—%
5.5%
$ 285
283
200
$ 768
See “Bank Credit Arrangements” herein for information on bank term loan covenants that limit debt levels and cross-acceleration or
cross-default provisions.
4.7%
5.0%
4.9%
—%
—%
5.0%
5.0%
4.7%
4.8%
4.6%
4.9%
4.7%
127
Southern Company 2023 Annual Report Notes to Financial Statements
Outstanding Classes of Capital Stock
Southern Company
Common Stock
Stock Issued
During 2023, Southern Company issued approximately 2.1 million shares of common stock primarily through equity compensation plans
and received proceeds of approximately $36 million.
Shares Reserved
At December 31, 2023, a total of 131 million shares were reserved for issuance pursuant to the Southern Investment Plan, employee savings
plans, the Equity and Incentive Compensation Plan (which includes stock options and performance share units as discussed in Note 12), an
at-the-market program, and the Series 2023A Convertible Senior Notes (as discussed under “Convertible Senior Notes” herein). Of the shares
reserved, 26.9 million shares are available for awards under the Equity and Incentive Compensation Plan at December 31, 2023.
Diluted Earnings Per Share
For Southern Company, the only difference in computing basic and diluted earnings per share (EPS) is attributable to awards outstanding
under stock-based compensation plans and the Series 2023A Convertible Senior Notes. EPS dilution resulting from stock-based
compensation plans is determined using the treasury stock method and EPS dilution resulting from the Series 2023A Convertible Senior
Notes is determined using the net share settlement method. See Note 12 and “Convertible Senior Notes” herein for additional information.
Shares used to compute diluted EPS were as follows:
As reported shares
Effect of stock-based compensation
Diluted shares
Average Common Stock Shares
2023
1,092
6
1,098
2022
(in millions)
1,075
6
1,081
2021
1,061
7
1,068
For 2023, there were no anti-dilutive shares. For 2022 and 2021, an immaterial number of stock-based compensation awards was excluded
from the diluted EPS calculation because the awards were anti-dilutive.
For all periods presented, there was no dilution resulting from the Series 2023A Convertible Senior Notes.
Preferred Stock of Subsidiaries
As discussed further under “Alabama Power” herein, during 2022, Alabama Power redeemed all of its preferred stock and Class
A preferred stock.
Alabama Power
Alabama Power has preferred stock, Class A preferred stock, preference stock, and common stock authorized, but only common stock
outstanding at December 31, 2023.
During 2022, Alabama Power redeemed all of its preferred stock and Class A preferred stock at the redemption prices per share provided in
the table below, plus accrued and unpaid dividends to the redemption date.
Preferred Stock Redeemed During 2022
4.92% Preferred Stock
4.72% Preferred Stock
4.64% Preferred Stock
4.60% Preferred Stock
4.52% Preferred Stock
4.20% Preferred Stock
5.00% Class A Preferred Stock
128
Par Value/Stated
Capital Per Share
$100
$100
$100
$100
$100
$100
$ 25
Shares
80,000
50,000
60,000
100,000
50,000
135,115
10,000,000
Redemption
Price Per Share
$103.23
$102.18
$103.14
$104.20
$102.93
$105.00
$ 25.00
Southern Company 2023 Annual Report Notes to Financial Statements
Georgia Power
Georgia Power has preferred stock, Class A preferred stock, preference stock, and common stock authorized, but only common stock
outstanding.
Mississippi Power
Mississippi Power has preferred stock and common stock authorized, but only common stock outstanding.
Dividend Restrictions
The income of Southern Company is derived primarily from equity in earnings of its subsidiaries. At December 31, 2023, consolidated
retained earnings included $5.5 billion of undistributed retained earnings of the subsidiaries.
The traditional electric operating companies and Southern Power can only pay dividends to Southern Company out of retained earnings or
paid-in-capital.
See Note 7 under “Southern Power” for information regarding the distribution requirements for certain Southern Power subsidiaries.
By regulation, Nicor Gas is restricted, up to its retained earnings balance, in the amount it can dividend or loan to affiliates and is not
permitted to make money pool loans to affiliates. At December 31, 2023, the amount of Southern Company Gas’ subsidiary retained
earnings available for dividend payment totaled $1.7 billion.
Structural Considerations
Since Southern Company and Southern Company Gas are holding companies, the right of Southern Company and Southern Company Gas
and, hence, the right of creditors of Southern Company or Southern Company Gas to participate in any distribution of the assets of any
respective subsidiary of Southern Company or Southern Company Gas, whether upon liquidation, reorganization or otherwise, is subject to
prior claims of creditors and preferred stockholders of such subsidiary.
Southern Company Gas’ 100%-owned subsidiary, Southern Company Gas Capital, was established to provide for certain of Southern
Company Gas’ ongoing financing needs through a commercial paper program, the issuance of various debt, hybrid securities, and other
financing arrangements. Southern Company Gas fully and unconditionally guarantees all debt issued by Southern Company Gas Capital.
Nicor Gas is not permitted by regulation to make loans to affiliates or utilize Southern Company Gas Capital for its financing needs.
Southern Power Company’s senior notes, bank term loan, commercial paper, and bank credit arrangement are unsecured senior
indebtedness, which rank equally with all other unsecured and unsubordinated debt of Southern Power Company. Southern Power’s
subsidiaries are not issuers, borrowers, or obligors, as applicable, under any of these unsecured senior debt arrangements, which are
effectively subordinated to any future secured debt of Southern Power Company and any potential claims of creditors of Southern
Power’s subsidiaries.
9. LEASES
Lessee
The Registrants 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 ROU assets that will be amortized over the term of each lease.
129
Southern Company 2023 Annual Report Notes to Financial Statements
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:
At December 31, 2023
Electric generating units(*)
Real estate/land
Communication towers
Railcars
Other
Total
At December 31, 2022
Electric generating units(*)
Real estate/land
Communication towers
Railcars
Other
Total
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 670
871
123
64
60
$1,788
$ 760
885
141
34
79
$1,899
$ 58
4
1
32
3
$ 98
$ 59
4
2
12
4
$ 81
$ 1,028
54
4
27
2
$ 1,115
$ 1,163
54
4
18
1
$ 1,240
$ —
2
—
5
18
$ 25
$ —
2
—
3
21
$ 26
$ —
546
—
—
—
$ 546
$ —
542
—
—
—
$ 542
Southern
Company
Gas
$ —
28
23
—
—
$ 51
$ —
36
23
—
1
$ 60
(*) Amounts related to affiliate leases are eliminated in consolidation for Southern Company. See “Contracts that Contain a Lease” herein for
additional information.
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 27 years while the land leases have remaining terms of up to 44 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 and Nicor Gas. Communication tower leases have
remaining terms of up to 17 years.
Renewal options exist in many of the leases. The expected term used in calculating the lease obligation generally reflects only the
noncancelable period of the lease unless it is considered reasonably certain that the lease will be extended. Land leases associated with
renewable energy facilities at Southern Power and communication tower leases for automated meter infrastructure at Nicor Gas include
renewal periods reasonably certain of exercise resulting in an expected lease term at least equal to the expected life of the renewable
energy facilities and the automated meter infrastructure, respectively.
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 PPA, which varies between one and 16 years. Georgia Power has several PPAs with Southern Power that Georgia
Power accounts for as leases with a lease obligation of $416 million and $461 million at December 31, 2023 and 2022, respectively.
The amount paid for energy under these affiliate PPAs reflects a price that would be paid in an arm’s-length transaction as reviewed
and approved by the Georgia PSC. Amounts related to the affiliate PPAs are eliminated in consolidation for Southern Company.
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.
130
Southern Company 2023 Annual Report Notes to Financial Statements
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 at December 31, 2023 and 2022.
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:
At December 31, 2023
Operating Leases
Operating lease ROU assets, net
Operating lease obligations - current
Operating lease obligations - non-current
Total operating lease obligations(*)
Finance Leases
Finance lease ROU assets, net
Finance lease obligations - current
Finance lease obligations - non-current
Total finance lease obligations
At December 31, 2022
Operating Leases
Operating lease ROU assets, net
Operating lease obligations - current
Operating lease obligations - non-current
Total operating lease obligations(*)
Finance Leases
Finance lease ROU assets, net
Finance lease obligations - current
Finance lease obligations - non-current
Total finance lease obligations
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
$ 1,432
183
$
1,307
$ 1,490
$
$
$
272
11
287
298
$ 1,531
197
$
1,388
$ 1,585
$
$
$
292
18
296
314
$ 87
$ 12
81
$ 93
$
$
$
5
2
3
5
$ 71
9
$
67
$ 76
$
$
$
5
2
3
5
$ 884
$ 135
740
$ 875
$ 203
18
$
222
$ 240
$1,007
$ 151
851
$1,002
$ 205
16
$
222
$ 238
$ 9
$ 3
6
$ 9
$15
$ 1
15
$16
$ 9
$ 4
5
$ 9
$16
$ 1
16
$17
$ 488
29
$
517
$ 546
$ —
$ —
—
$ —
$ 489
28
$
514
$ 542
$ —
$ —
—
$ —
$ 47
$ 11
40
$ 51
$ —
$ —
—
$ —
$ 57
$ 9
51
$ 60
$ —
$ —
—
$ —
(*) Includes operating lease obligations related to PPAs at Southern Company, Alabama Power, and Georgia Power totaling $566 million, $58 million, and
$813 million, respectively, at December 31, 2023 and $652 million, $59 million, and $952 million, respectively, at December 31, 2022.
If not presented separately on the Registrants’ balance sheets, amounts related to leases are presented as follows: operating lease ROU
assets, net are included in “other deferred charges and assets”; operating lease obligations are included in “other current liabilities” and
“other deferred credits and liabilities,” as applicable; finance lease ROU assets, net are included in “plant in service”; and finance lease
obligations are included in “securities due within one year” and “long-term debt,” as applicable.
131
Southern Company 2023 Annual Report Notes to Financial Statements
Lease costs for 2023, 2022, and 2021, which includes both amounts recognized as operations and maintenance expense and amounts
capitalized as part of the cost of another asset, are as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
(in millions)
2023
Lease cost
Operating lease cost(*)
Finance lease cost:
Amortization of ROU assets
Interest on lease obligations
Total finance lease cost
Short-term lease costs
Variable lease cost
Sublease income
Total lease cost
2022
Lease cost
Operating lease cost(*)
Finance lease cost:
Amortization of ROU assets
Interest on lease obligations
Total finance lease cost
Short-term lease costs
Variable lease cost
Sublease income
Total lease cost
2021
Lease cost
Operating lease cost(*)
Finance lease cost:
Amortization of ROU assets
Interest on lease obligations
Total finance lease cost
Short-term lease costs
Variable lease cost
Sublease income
Total lease cost
$252
$ 16
$192
24
14
38
40
47
—
$377
2
—
2
16
—
—
$ 34
19
17
36
16
74
—
$318
$297
$ 59
$198
23
13
36
64
125
(1)
$521
1
—
1
44
13
—
$117
15
17
32
13
105
—
$348
$313
$ 58
$208
21
11
32
48
96
1
$490
1
—
1
15
4
—
$ 78
11
16
27
24
83
—
$342
$ 5
1
—
1
—
—
—
$ 6
$ 5
1
1
2
—
—
—
$ 7
$ 2
1
1
2
—
—
—
$ 4
$34
—
—
—
—
4
—
$38
$32
—
—
—
—
5
—
$37
$33
—
—
—
—
5
—
$38
$ 12
—
—
—
—
—
—
$ 12
$ 15
—
—
—
—
—
—
$ 15
$ 19
—
—
—
—
—
—
$ 19
(*) Includes operating lease costs related to PPAs at Southern Company, Alabama Power, and Georgia Power totaling $112 million, $4 million, and $174 million,
respectively, in 2023, $162 million, $48 million, and $180 million, respectively, in 2022, and $165 million, $47 million, and $184 million, respectively, in 2021.
Georgia Power has variable lease payments that are based on the amount of energy produced by certain renewable generating facilities
subject to PPAs, including $42 million, $45 million, and $41 million in 2023, 2022, and 2021, respectively, from finance leases which are
included in purchased power on Georgia Power’s statements of income, of which $21 million, $21 million, and $20 million was included in
purchased power, affiliates in 2023, 2022, and 2021, respectively.
132
Southern Company 2023 Annual Report Notes to Financial Statements
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:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
2023
Other information
Cash paid for amounts included in the measurements
of lease obligations:
Operating cash flows from operating leases
Operating cash flows from finance leases
Financing cash flows from finance leases
ROU assets obtained under operating leases
ROU assets obtained under finance leases
2022
Other information
Cash paid for amounts included in the measurements
of lease obligations:
Operating cash flows from operating leases
Operating cash flows from finance leases
Financing cash flows from finance leases
ROU assets obtained under operating leases
Reassessment of ROU assets under operating leases
ROU assets obtained under finance leases
2021
Other information
Cash paid for amounts included in the measurements
of lease obligations:
Operating cash flows from operating leases
Operating cash flows from finance leases
Financing cash flows from finance leases
ROU assets obtained under operating leases
ROU assets obtained under finance leases
$253
15
18
100
3
$303
11
16
56
16
118
$308
9
17
64
3
$17
—
2
30
3
$58
—
1
10
—
2
$58
—
1
3
—
$199
22
16
26
18
$206
20
10
17
—
116
$211
17
9
9
—
$ 5
—
1
1
—
$ 5
1
1
9
—
—
$ 2
1
1
—
—
$33
—
—
7
—
$30
—
—
—
16
—
$28
—
—
72
—
$12
—
—
7
—
$14
—
—
3
—
—
$19
—
—
7
—
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
At December 31, 2023
Weighted-average remaining lease term in years:
Operating leases
Finance leases
Weighted-average discount rate:
Operating leases
Finance leases
At December 31, 2022
Weighted-average remaining lease term in years:
Operating leases
Finance leases
Weighted-average discount rate:
Operating leases
Finance leases
17.2
16.7
4.68%
4.85%
17.3
17.4
4.51%
4.87%
11.1
4.3
5.02%
3.93%
13.0
6.4
4.87%
3.00%
7.5
10.6
4.58%
5.95%
8.1
11.8
4.52%
8.06%
4.6
11.9
3.67%
2.74%
4.7
12.9
3.49%
2.74%
33.1
N/A
4.89 %
N/A
34.0
N/A
4.86 %
N/A
7.0
N/A
3.80%
N/A
11.0
N/A
3.79%
N/A
133
Southern Company 2023 Annual Report Notes to Financial Statements
Maturities of lease liabilities are as follows:
Maturity Analysis
Operating leases:
2024
2025
2026
2027
2028
Thereafter
Total
Less: Present value discount
Operating lease obligations
Finance leases:
2024
2025
2026
2027
2028
Thereafter
Total
Less: Present value discount
Finance lease obligations
At December 31, 2023
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
(in millions)
$ 230
203
180
159
143
1,378
2,293
803
$1,490
$
22
27
27
27
26
320
449
151
$ 298
$ 16
14
12
10
7
64
123
30
$ 93
$
$
2
1
1
1
1
—
6
1
5
$ 172
147
142
141
135
303
1,040
165
$ 875
$
27
36
36
36
37
153
325
85
$ 240
$ 4
3
2
—
—
1
10
1
$ 9
$ 2
2
2
2
1
10
19
3
$16
$
36
29
29
29
30
1,000
1,153
607
$ 546
$ —
—
—
—
—
—
—
—
$ —
$12
12
9
4
3
18
58
7
$51
$ —
—
—
—
—
—
—
—
$ —
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.
Lessor
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 10 years, after which the
contracts renew on a month-to-month basis at the customer’s option. For Mississippi Power, these arrangements also include a tolling
arrangement related to an electric generating unit accounted for as a sales-type lease with a remaining term of 15 years. For Southern
Power, these arrangements consist of PPAs related to electric generating units accounted for as operating leases with remaining terms
of up to 23 years and PPAs related to battery energy storage facilities accounted for as sales-type leases with remaining terms of up
to 18 years. Southern Company Gas is the lessor in operating leases related to gas pipelines with remaining terms of up to 19 years.
For Southern Company, these arrangements also include PPAs related to fuel cells accounted for as operating leases with remaining
terms of up to 10 years.
134
Southern Company 2023 Annual Report
Notes to Financial Statements
Lease income for 2023, 2022, and 2021, is as follows:
2023
Lease income - interest income on sales-type leases
Lease income - operating leases
Variable lease income
Total lease income
2022
Lease income - interest income on sales-type leases
Lease income - operating leases
Variable lease income
Total lease income
2021
Lease income - interest income on sales-type leases
Lease income - operating leases
Variable lease income
Total lease income
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
$ 24
164
406
$594
$ 25
208
417
$650
$ 15
223
429
$667
$ —
35
1
$ 36
$ —
77
1
$ 78
$ —
82
—
$ 82
$ —
29
—
$29
$ —
32
—
$32
$ —
42
—
$42
$14
2
—
$16
$15
2
—
$17
$14
2
—
$16
$ 10
85
437
$532
$ 10
85
448
$543
$
1
85
456
$542
$ —
37
—
$37
$ —
36
—
$36
$ —
35
—
$35
Lease payments received under tolling arrangements and PPAs consist of either scheduled payments or variable payments based on the
amount of energy produced by the underlying electric generating units. Lease income related to PPAs for Alabama Power and Southern
Power is included in wholesale revenues. Scheduled payments to be received under outdoor lighting contracts, tolling arrangements, and
PPAs accounted for as leases are presented in the following maturity analyses.
Mississippi Power has a tolling arrangement accounted for as a sales-type lease. During 2021, Mississippi Power completed construction of
additional leased assets under the lease and, upon completion, the book value of $39 million was transferred from CWIP to lease receivables.
The transfer represented a non-cash investing transaction for purposes of the statements of cash flows.
During 2021, Southern Power completed construction of a portion of the Garland and Tranquillity battery energy storage facilities’ assets
and recorded losses totaling $40 million upon commencement of the related PPAs, which Southern Power accounts for as sales-type
leases. The losses were due to ITCs retained and expected to be realized by Southern Power and its partners in these projects, and no
estimated residual asset value was assumed in calculating the losses. Each lease had an initial term of 20 years. Upon commencement of
the leases, the book values of the related assets totaling $210 million were derecognized from CWIP and lease receivables were recorded.
The transfers represented noncash investing transactions for purposes of the statement of cash flows. See Note 15 under “Southern Power”
for additional information.
The undiscounted cash flows expected to be received for in-service leased assets under the leases are as follows:
2024
2025
2026
2027
2028
Thereafter
Total undiscounted cash flows
Net investment in sales-type lease(*)
Difference between undiscounted cash flows and discounted cash flows
At December 31, 2023
Southern
Company
Mississippi
Power
Southern
Power
(in millions)
$ 38
37
36
35
34
330
$510
311
$199
$ 23
22
21
20
19
145
$250
148
$102
$ 15
15
15
15
15
185
$260
163
$ 97
(*) For Mississippi Power, included in other current assets and other property and investments on the balance sheets. For Southern Power, included in other
current assets ($15 million and $15 million at December 31, 2023 and 2022, respectively) and net investment in sales-type leases ($148 million and $154
million at December 31, 2023 and 2022, respectively) on the balance sheet.
135
Southern Company 2023 Annual Report Notes to Financial Statements
The undiscounted cash flows to be received under operating leases and contracts accounted for as operating leases are as follows:
2024
2025
2026
2027
2028
Thereafter
Total
At December 31, 2023
Southern
Company
Alabama
Power
Southern
Power
(in millions)
$ 116
107
108
105
104
706
$1,246
$ 7
5
5
4
3
26
$50
$ 90
75
73
75
76
91
$480
Southern
Company
Gas
$ 35
29
29
28
28
354
$503
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. Alabama Power and Southern Power allocate 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 Georgia Power and Mississippi Power are immaterial.
Southern Company Leveraged Lease
At December 31, 2020, a subsidiary of Southern Holdings had four leveraged lease agreements related to energy generation, distribution,
and transportation assets, including two domestic and two international projects. During 2021, one of the domestic projects was sold and
the agreements for both international projects were terminated. At December 31, 2023, the one remaining leveraged lease agreement,
which relates to energy generation, had an expected remaining term of eight years. Southern Company continues to receive federal income
tax deductions for depreciation and amortization, as well as interest on long-term debt related to this investment. Southern Company
wrote off the related investment balance in 2020 following an evaluation of the recoverability of the lease receivable and the expected
residual value of the generation assets at the end of the lease.
The following table provides a summary of the components of income related to leveraged lease investments. Income was impacted in
2021 by the impairment charges discussed below and in Note 15 under “Southern Company.” Income in 2021 does not include the impacts
of the sale and terminations of leveraged lease projects discussed in Note 15 under “Southern Company.”
Pretax leveraged lease income
Income tax expense
Net leveraged lease income
2021
(in millions)
$17
(5)
$12
In June 2022, the Southern Holdings subsidiary operating the generating plant for the lessee provided notice to the lessee to terminate
the related operating and maintenance agreement effective June 30, 2023. Subsequently, the lessee failed to make the semi-annual
lease payment due in December 2022. As a result, the Southern Holdings subsidiary was unable to make its corresponding payment
to the holders of the underlying non-recourse debt related to the generation assets. The parties to the lease entered into forbearance
agreements which suspended the related contractual rights of the parties while they continued restructuring negotiations, during which
the termination date for the operating and maintenance agreement was delayed until July 31, 2023. The negotiations were completed
on July 14, 2023, resulting in the Southern Holdings subsidiary agreeing to continue operating the plant for the lessee until the lessee’s
associated power off-take agreement ends in 2032, subject to certain terms and conditions. The restructuring had no material impact on
Southern Company’s financial statements. Southern Company will continue to monitor the operational performance of the underlying
assets and evaluate the ability of the lessee to continue to meet its obligations, including those associated with a future closure or
retirement of the generation assets and associated properties, including the dry ash landfill.
136
Southern Company 2023 Annual Report Notes to Financial Statements
10. INCOME TAXES
Southern Company files a consolidated federal income tax return and the Registrants file various state income tax returns, some of which
are combined or unitary. Under a joint consolidated income tax allocation agreement, each Southern Company subsidiary’s current and
deferred tax expense is computed on a stand-alone basis, and each subsidiary is allocated an amount of tax similar to that which would be
paid if it filed a separate income tax return. In accordance with IRS regulations, each company is jointly and severally liable for the federal
tax liability.
Current and Deferred Income Taxes
Details of income tax provisions are as follows:
Federal —
Current
Deferred
Total federal
State —
Current
Deferred
Total state
Total
Federal —
Current
Deferred
Total federal
State —
Current
Deferred
Total state
Total
Federal —
Current
Deferred
Total federal
State —
Current
Deferred
Total state
Total
2023
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 54
299
353
41
102
143
$496
$ 242
(257)
(15)
82
14
96
81
$
$ 205
195
400
37
11
48
$ 448
$ 49
(26)
23
1
12
13
$ 36
$(320)
334
14
(1)
(1)
(2)
$ 12
2022
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 10
455
465
27
303
330
$795
$
54
259
313
14
96
110
$ 423
$ 38
152
190
(21)
201
180
$ 370
$ 42
(16)
26
—
11
11
$ 37
$ (43)
56
13
2
5
7
$ 20
Southern
Company
Gas
$ 62
68
130
24
57
81
$211
Southern
Company
Gas
$122
(3)
119
42
19
61
$180
Southern
Company
Alabama
Power
Georgia
Power
2021
Mississippi
Power
(in millions)
Southern
Power
Southern
Company
Gas
$ 50
36
86
(25)
206
181
$267
$ 104
172
276
23
73
96
$ 372
$ 311
(449)
(138)
71
(101)
(30)
$(168)
$ 25
(15)
10
—
11
11
$ 21
$ (340)
343
3
(16)
—
(16)
$ (13)
$ 85
35
120
(68)
223
155
$275
137
Southern Company 2023 Annual Report Notes to Financial Statements
Southern Company’s and Southern Power’s ITCs and PTCs generated in the current tax year and carried forward from prior tax years that
cannot be utilized in the current tax year are reclassified from current to deferred taxes in federal income tax expense in the tables above.
Southern Power’s ITCs and PTCs reclassified in this manner include $5 million for 2023, $17 million for 2022, and $6 million for 2021.
Southern Power received $332 million, $49 million, and $289 million of cash related to federal ITCs under renewable energy initiatives
in 2023, 2022, and 2021, respectively. See “Deferred Tax Assets and Liabilities” herein for additional information.
In accordance with regulatory requirements, deferred federal ITCs for the traditional electric operating companies are amortized over the
average life of the related property, with such amortization normally applied as a credit to reduce depreciation and amortization in the
statements of income. Southern Power’s and the natural gas distribution utilities’ deferred federal ITCs, as well as certain state ITCs for Nicor
Gas, are amortized to income tax expense over the life of the respective asset. ITCs amortized in 2023, 2022, and 2021 were immaterial for
the traditional electric operating companies and Southern Company Gas and were as follows for Southern Company and Southern Power:
2023
2022
2021
Southern
Company
Southern
Power
(in millions)
$84
83
84
$58
58
58
When Southern Power recognizes tax credits, the tax basis of the asset is reduced by 50% of the ITCs received, resulting in a net deferred
tax asset. Southern Power has elected to recognize the tax benefit of this basis difference as a reduction to income tax expense in the year
in which the plant reaches commercial operation.
State ITCs and other state credits, which are recognized in the period in which the credits are generated, reduced Georgia Power’s income
tax expense by $49 million in 2023, $53 million in 2022, and $66 million in 2021.
Southern Power’s federal and state PTCs, which are recognized in the period in which the credits are generated, reduced Southern Power’s
income tax expense by $26 million in 2023, $27 million in 2022, and $16 million in 2021.
During the fourth quarter 2023, Southern Power executed an agreement to transfer certain PTCs generated in 2023 and received cash of
$12 million. The discount recognized was booked through income tax expense and was immaterial.
Pursuant to the Global Amendments to the Vogtle Joint Ownership Agreements (as defined in Note 2 under “Georgia Power – Nuclear
Construction – Joint Owner Contracts”), Georgia Power paid $39 million to the other Vogtle Owners for advanced nuclear PTCs for Plant
Vogtle Unit 3. The gain recognized in 2023 was booked through income tax benefit and was immaterial.
Effective Tax Rate
Southern Company’s effective tax rate is typically lower than the statutory rate due to employee stock plans’ dividend deduction,
non-taxable AFUDC equity at the traditional electric operating companies, flowback of excess deferred income taxes at the regulated
utilities, and federal income tax benefits from ITCs and PTCs primarily at Southern Power.
In July 2021, Southern Company Gas affiliates completed the sale of Sequent. As a result of the sale, changes in state apportionment rates
resulted in $85 million of additional net state tax expense. See Note 15 under “Southern Company Gas” for additional information.
138
Southern Company 2023 Annual Report Notes to Financial Statements
A reconciliation of the federal statutory income tax rate to the effective income tax rate is as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
2023
Federal statutory rate
State income tax, net of federal deduction
Employee stock plans' dividend deduction
Non-deductible book depreciation
Flowback of excess deferred income taxes
AFUDC-Equity
Federal PTCs
ITC amortization
Noncontrolling interests
Other
Effective income tax (benefit) rate
21.0 %
2.6
(0.5)
0.7
(9.2)
(1.1)
(1.2)
(1.3)
0.6
(0.2)
11.4%
21.0%
5.2
—
0.7
(19.8)
(1.2)
—
(0.1)
—
(0.2)
5.6%
21.0%
4.9
—
0.4
(10.2)
—
—
—
—
0.1
16.2%
21.0%
1.5
—
0.8
(2.6)
(1.2)
(1.4)
(0.1)
—
(0.3)
17.7%
2022
21.0%
(0.7)
—
—
—
—
(7.4)
(19.0)
11.1
0.1
5.1%
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Federal statutory rate
State income tax, net of federal deduction
Employee stock plans' dividend deduction
Non-deductible book depreciation
Flowback of excess deferred income taxes
AFUDC-Equity
Federal PTCs
ITC amortization
Noncontrolling interests
Other
Effective income tax (benefit) rate
21.0%
6.2
(0.5)
0.6
(6.6)
(1.1)
—
(1.3)
0.5
—
18.8%
21.0%
4.8
—
0.5
(1.9)
(0.8)
—
(0.1)
—
0.3
23.8%
21.0%
4.4
—
0.3
(7.8)
—
—
—
—
0.3
18.2%
21.0%
6.5
—
0.6
(9.6)
(1.5)
—
(0.1)
—
—
16.9%
2021
21.0%
1.9
—
—
—
—
(6.6)
(17.2)
8.4
(0.1)
7.4%
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Federal statutory rate
State income tax, net of federal deduction
Employee stock plans' dividend deduction
Non-deductible book depreciation
Flowback of excess deferred income taxes
AFUDC-Equity
Federal PTCs
ITC amortization
Noncontrolling interests
Leveraged lease impairments and dispositions
Other
Effective income tax (benefit) rate
21.0%
5.5
(0.9)
0.9
(11.7)
(1.5)
—
(2.2)
0.8
(1.4)
(0.1)
10.4%
21.0%
4.6
—
0.5
(2.6)
(0.7)
—
(0.1)
—
—
0.2
22.9%
21.0%
(5.7)
—
3.1
(49.9)
(6.4)
—
(0.4)
—
—
(1.9)
(40.2)%
21.0%
4.9
—
0.4
(15.2)
—
—
—
—
—
0.6
11.7%
21.0%
(8.0)
—
—
—
—
(4.6)
(29.7)
13.4
—
(0.4)
(8.3)%
Southern
Company
Gas
21.0%
7.8
—
—
(2.6)
—
—
—
—
(0.6)
25.6%
Southern
Company
Gas
21.0%
6.4
—
—
(2.5)
—
—
(0.1)
—
(0.9)
23.9%
Southern
Company
Gas
21.0%
15.1
—
—
(2.8)
—
—
(0.1)
—
—
0.6
33.8%
139
Southern Company 2023 Annual Report
Notes to Financial Statements
Deferred Tax Assets and Liabilities
The tax effects of temporary differences between the carrying amounts of assets and liabilities in the financial statements of the
Registrants and their respective tax bases, which give rise to deferred tax assets and liabilities, are as follows:
December 31, 2023
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Deferred tax liabilities —
Accelerated depreciation
Property basis differences
Employee benefit obligations
AROs
Under recovered fuel and natural gas costs
Regulatory assets –
AROs
Employee benefit obligations
Remaining book value of retired assets
Premium on reacquired debt
Other
Total deferred income tax liabilities
Deferred tax assets —
AROs
ITC and PTC carryforwards
Employee benefit obligations
Estimated loss on plants under construction
Estimated loss on regulatory disallowance
Other state deferred tax attributes
Federal effect of net state deferred tax liabilities
Other property basis differences
State effect of federal deferred taxes
Other partnership basis differences
Regulatory liability associated with the Tax Reform
Legislation (not subject to normalization)
Long-term debt fair value adjustment
Other comprehensive losses
Other
Total deferred income tax assets
Valuation allowance
Net deferred income tax assets
Net deferred income taxes (assets)/liabilities
Recognized in the balance sheets:
Accumulated deferred income taxes – assets
Accumulated deferred income taxes – liabilities
$ 9,683
2,647
979
833
601
1,902
797
369
63
700
18,574
2,735
1,387
985
857
26
363
418
197
115
85
34
79
67
538
7,886
(206)
7,680
$10,894
$
(96)
$10,990
$ 2,566
1,444
321
476
80
667
213
143
9
182
6,101
1,143
12
224
—
—
—
215
—
115
—
30
—
4
188
1,931
—
1,931
$4,170
$ —
$4,170
$3,628
812
446
314
508
1,196
260
221
53
223
7,661
1,510
691
316
857
—
13
92
83
—
—
—
—
4
152
3,718
(75)
3,643
$4,018
$ —
$4,018
$ 339
188
49
—
13
39
37
5
1
43
714
39
—
52
—
—
231
—
—
—
—
3
—
—
57
382
(41)
341
$ 373
$(96)
$ 469
$1,346
—
12
—
—
—
—
—
—
2
1,360
—
481
10
—
—
49
27
97
—
85
—
—
6
18
773
(27)
746
$ 614
$ —
$ 614
Southern
Company
Gas
$ 1,576
189
74
—
—
—
11
—
—
191
2,041
—
—
89
—
26
8
101
—
—
—
—
79
—
74
377
(7)
370
$1,671
$ —
$1,671
140
Southern Company 2023 Annual Report Notes to Financial Statements
December 31, 2022
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Deferred tax liabilities —
Accelerated depreciation
Property basis differences
Employee benefit obligations
AROs
Under recovered fuel and natural gas costs
Regulatory assets –
AROs
Employee benefit obligations
Remaining book value of retired assets
Premium on reacquired debt
Other
Total deferred income tax liabilities
Deferred tax assets —
AROs
ITC and PTC carryforwards
Employee benefit obligations
Estimated loss on plants under construction
Other state deferred tax attributes
Federal effect of net state deferred tax liabilities
Other property basis differences
State effect of federal deferred taxes
Other partnership basis differences
Regulatory liability associated with the Tax Reform
Legislation (not subject to normalization)
Long-term debt fair value adjustment
Other comprehensive losses
Other
Total deferred income tax assets
Valuation allowance
Net deferred income tax assets
Net deferred income taxes (assets)/liabilities
Recognized in the balance sheets:
Accumulated deferred income taxes – assets
Accumulated deferred income taxes – liabilities
$ 9,443
2,350
888
876
805
2,006
677
400
66
555
18,066
2,882
1,685
890
888
388
365
207
136
111
137
85
72
552
8,398
(257)
8,141
$ 9,925
$ (111)
$10,036
$ 2,564
1,303
284
499
185
679
180
142
9
179
6,024
1,178
12
198
—
—
175
—
136
—
127
—
4
213
2,043
—
2,043
$3,981
$ —
$3,981
$ 3,447
693
412
324
548
1,285
226
253
57
181
7,426
1,609
673
304
888
12
88
79
—
—
—
—
5
186
3,844
(125)
3,719
$ 3,707
$ —
$ 3,707
$ 338
179
43
—
40
42
30
5
—
40
717
42
—
47
—
239
—
—
—
—
9
—
—
62
399
(41)
358
$ 359
$(107)
$ 466
$1,351
—
11
—
—
—
—
—
—
14
1,376
—
794
9
—
51
28
109
—
111
—
—
5
17
1,124
(27)
1,097
$ 279
$ —
$ 279
Southern
Company
Gas
$ 1,505
150
68
—
32
—
15
—
—
82
1,852
—
—
89
—
7
92
—
—
—
—
85
—
28
301
(9)
292
$1,560
$ —
$1,560
The traditional electric operating companies and the natural gas distribution utilities have tax-related regulatory assets (deferred income tax
charges) and regulatory liabilities (deferred income tax credits). The regulatory assets are primarily attributable to tax benefits flowed through
to customers in prior years, deferred taxes previously recognized at rates lower than the current enacted tax law, and taxes applicable to
capitalized interest. The regulatory liabilities are primarily attributable to deferred taxes previously recognized at rates higher than the current
enacted tax law and to unamortized ITCs. See Note 2 for each Registrant’s related balances at December 31, 2023 and 2022.
141
Southern Company 2023 Annual Report Notes to Financial Statements
Tax Credit Carryforwards
Federal ITC/PTC carryforwards at December 31, 2023 were as follows:
Federal ITC/PTC carryforwards
Tax year in which federal ITC/PTC carryforwards begin expiring
Year by which federal ITC/PTC carryforwards are expected to be utilized
Southern
Company
Alabama
Power
Georgia
Power
Southern
Power
(in millions)
$ 829
2031
2029
$
12
2032
2028
$ 131
2031
2028
$ 481
2035
2029
The estimated tax credit utilization reflects the various transactions described in Note 15 and could be impacted by numerous factors,
including the acquisition of additional renewable projects, changes in taxable income projections, transfer of eligible credits, potential
income tax rate changes, and the ultimate implementation of the natural gas safe harbor method for repairs. In the third quarter 2023,
Georgia Power started generating advanced nuclear PTCs for Plant Vogtle Unit 3 beginning on the in-service date of July 31, 2023.
In addition, pursuant to the Global Amendments to the Vogtle Joint Ownership Agreements (as defined in Note 2 under “Georgia Power –
Nuclear Construction – Joint Owner Contracts”), Georgia Power is purchasing advanced nuclear PTCs for Plant Vogtle Unit 3 from the other
Vogtle Owners. See Note 2 under “Georgia Power – Nuclear Construction” for additional information on Plant Vogtle Units 3 and 4.
At December 31, 2023, Georgia Power also had approximately $452 million in net state investment and other net state tax credit
carryforwards for the State of Georgia that will expire between tax years 2023 and 2032 and are not expected to be fully utilized.
Georgia Power has a net state valuation allowance of $60 million associated with these carryforwards.
The ultimate outcome of these matters cannot be determined at this time.
Net Operating Loss Carryforwards
At December 31, 2023, the net state income tax benefit of state and local NOL carryforwards for Southern Company’s subsidiaries
were as follows:
Company/Jurisdiction
Mississippi Power
Mississippi
Southern Power
Oklahoma
Florida
Other states
Southern Power Total
Other(*)
New York
New York City
Other states
Southern Company Total
Approximate Net State Income Tax
Benefit of NOL Carryforwards
(in millions)
Tax Year
NOL
Begins
Expiring
$183
2032
26
10
2
$ 38
11
14
30
$276
2035
2034
Various
2036
2036
Various
(*) Represents other non-registrant Southern Company subsidiaries. Alabama Power, Georgia Power, and Southern Company Gas did not have material state or
local NOL carryforwards at December 31, 2023.
State NOLs for Mississippi, Oklahoma, and Florida are not expected to be fully utilized prior to expiration. At December 31, 2023,
Mississippi Power had a net state valuation allowance of $32 million for the Mississippi NOL, Southern Power had net state valuation
allowances of $11 million for the Oklahoma NOL and $10 million for the Florida NOL, and Southern Company had a net valuation
allowance of $25 million for the New York and New York City NOLs.
The ultimate outcome of these matters cannot be determined at this time.
142
Southern Company 2023 Annual Report Notes to Financial Statements
Unrecognized Tax Benefits
Changes in unrecognized tax benefits for the periods presented were as follows:
Unrecognized tax benefits at December 31, 2020
Tax positions changes – Increase from prior periods
Unrecognized tax benefits at December 31, 2021
Tax positions changes – Increase from prior periods
Unrecognized tax benefits at December 31, 2022
Tax positions changes -
Increase from prior periods
Statute of limitations expiration
Unrecognized tax benefits at December 31, 2023
Southern Company
Georgia Power
(in millions)
Southern
Company Gas
$ 44
3
47
33
80
88
(52)
$ 116
$ —
—
—
—
—
86
(9)
$ 77
$ —
—
—
32
32
2
—
$ 34
The unrecognized tax positions increase from prior periods for 2022 is primarily related to the amendment of certain 2018 state tax filing
positions related to Southern Company Gas dispositions. If accepted by the states, these positions would decrease Southern Company’s and
Southern Company Gas’ annual effective tax rates. The ultimate outcome of these unrecognized tax benefits is dependent on acceptance by
each state and is not expected to be resolved within the next 12 months.
The unrecognized tax positions increase from prior periods for 2023 are primarily related to the amendment of certain 2019 through
2021 state tax filing positions related to tax credit utilization, a portion of which decreased in the fourth quarter 2023 due to a statute of
limitations expiration. If effective settlement of the positions is favorable, these positions would decrease Southern Company’s and Georgia
Power’s annual effective tax rates. The ultimate outcome of this unrecognized tax benefit, of which a portion is expected to be resolved
within the next 12 months, is dependent on acceptance by the state or expiration of related statute of limitations.
The unrecognized tax positions reductions due to statute of limitations expiration for 2023 primarily relates to a 2019 state tax filing
position to exclude certain gains from 2019 dispositions from taxation in a certain unitary state. This tax position and related interest was
recognized in the fourth quarter 2023 and decreased Southern Company’s annual effective tax rate.
All of the Registrants classify interest on tax uncertainties as interest expense. Accrued interest for all tax positions was immaterial for all
years presented. None of the Registrants accrued any penalties on uncertain tax positions.
The IRS has finalized its audits of Southern Company’s consolidated federal income tax returns through 2022. Southern Company is a
participant in the Compliance Assurance Process of the IRS. The IRS has selected six Southern Power partnership returns for exam for the
2020 and 2021 tax years. The ultimate outcome of this matter cannot be determined at this time. The audits for the Registrants’ state
income tax returns have either been concluded, or the statute of limitations has expired, for years prior to 2015.
11. RETIREMENT BENEFITS
The Southern Company system has a qualified defined benefit, trusteed pension plan covering substantially all employees, with the
exception of PowerSecure employees. The qualified pension plan is funded in accordance with requirements of the Employee Retirement
Income Security Act of 1974, as amended (ERISA). No contributions to the qualified pension plan were made for the year ended
December 31, 2023 and no mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2024.
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. For the year ending December 31, 2024, no contributions to any other postretirement trusts are expected.
143
Southern Company 2023 Annual Report Notes to Financial Statements
Actuarial Assumptions
The weighted average rates assumed in the actuarial calculations used to determine both the net periodic costs for the pension and other
postretirement benefit plans for the following year and the benefit obligations as of the measurement date are presented below.
Assumptions used to determine net periodic costs:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
2023
Pension plans
Discount rate – benefit obligations
Discount rate – interest costs
Discount rate – service costs
Expected long-term return on plan assets
Annual salary increase
Other postretirement benefit plans
Discount rate – benefit obligations
Discount rate – interest costs
Discount rate – service costs
Expected long-term return on plan assets
Annual salary increase
5.25%
5.13
5.36
8.40
4.80
5.18%
5.08
5.34
7.67
4.80
5.26%
5.14
5.38
8.40
4.80
5.20%
5.09
5.35
7.95
4.80
5.25%
5.12
5.37
8.40
4.80
5.17%
5.08
5.33
7.43
4.80
5.31%
5.19
5.37
8.40
4.80
5.24%
5.12
5.33
—
4.80
5.25%
5.12
5.38
8.40
4.80
5.17%
5.07
5.34
7.49
4.80
2022
Assumptions used to determine net periodic costs:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Pension plans
Discount rate – benefit obligations
Discount rate – interest costs
Discount rate – service costs
Expected long-term return on plan assets
Annual salary increase
Other postretirement benefit plans
Discount rate – benefit obligations
Discount rate – interest costs
Discount rate – service costs
Expected long-term return on plan assets
Annual salary increase
3.09 %
2.55
3.34
8.25
4.80
2.90 %
2.32
3.26
7.21
4.80
3.12%
2.58
3.36
8.25
4.80
2.95%
2.38
3.30
7.54
4.80
3.07%
2.54
3.35
8.25
4.80
2.88%
2.27
3.26
7.22
4.80
3.07%
2.51
3.37
8.25
4.80
2.87%
2.30
3.27
6.88
4.80
2021
3.21 %
2.79
3.36
8.25
4.80
3.07 %
2.55
3.25
—
4.80
Assumptions used to determine net periodic costs:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Pension plans
Discount rate – benefit obligations
Discount rate – interest costs
Discount rate – service costs
Expected long-term return on plan assets
Annual salary increase
Other postretirement benefit plans
Discount rate – benefit obligations
Discount rate – interest costs
Discount rate – service costs
Expected long-term return on plan assets
Annual salary increase
144
2.81 %
2.13
3.18
8.25
4.80
2.56 %
1.84
3.07
7.09
4.80
2.85%
2.17
3.23
8.25
4.80
2.63%
1.91
3.13
7.18
4.80
2.79%
2.09
3.21
8.25
4.80
2.52%
1.82
3.08
6.84
4.80
2.80%
2.12
3.20
8.25
4.80
2.53%
1.78
3.06
6.98
4.80
2.99 %
2.46
3.22
8.25
4.80
2.78 %
2.12
3.05
—
4.80
Southern
Company
Gas
5.24%
5.12
5.31
8.40
4.80
5.16%
5.07
5.33
6.59
4.80
Southern
Company
Gas
3.04%
2.53
3.21
8.25
4.80
2.82%
2.17
3.22
6.08
4.80
Southern
Company
Gas
2.75%
2.10
2.97
8.25
4.80
2.46%
1.64
3.01
6.54
4.80
Southern Company 2023 Annual Report Notes to Financial Statements
Assumptions used to determine benefit obligations:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
2023
Pension plans
Discount rate
Annual salary increase
Other postretirement benefit plans
Discount rate
Annual salary increase
5.07%
4.60
4.99%
4.60
5.08%
4.60
5.01%
4.60
5.06%
4.60
4.98%
4.60
5.06%
4.60
4.98%
4.60
5.14%
4.60
5.06%
4.60
5.05%
4.60
4.98%
4.60
Assumptions used to determine benefit obligations:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
2022
Pension plans
Discount rate
Annual salary increase
Other postretirement benefit plans
Discount rate
Annual salary increase
5.25 %
4.80
5.18 %
4.80
5.26%
4.80
5.20%
4.80
5.25%
4.80
5.17%
4.80
5.25%
4.80
5.17%
4.80
5.31 %
4.80
5.24 %
4.80
5.24%
4.80
5.16%
4.80
The Registrants estimate the expected rate of return on pension plan and other postretirement benefit plan assets using a financial model
to project the expected return on each current investment portfolio. The analysis projects an expected rate of return on each of the
different asset classes in order to arrive at the expected return on the entire portfolio relying on each trust’s target asset allocation and
reasonable capital market assumptions. The financial model is based on four key inputs: anticipated returns by asset class (based in part on
historical returns), each trust’s target asset allocation, an anticipated inflation rate, and the projected impact of a periodic rebalancing of
each trust’s portfolio. The Registrants set the expected rate of return assumption using an arithmetic mean which represents the expected
simple average return to be earned by the pension plan assets over any one year. The Registrants believe the use of the arithmetic mean is
more compatible with the expected rate of return’s function of estimating a single year’s investment return.
An additional assumption used in measuring the accumulated other postretirement benefit obligations (APBO) was a weighted average
medical care cost trend rate. The weighted average medical care cost trend rates used in measuring the APBO for the Registrants at
December 31, 2023 were as follows:
Pre-65
Post-65 medical
Post-65 prescription
Pension Plans
Initial Cost
Trend Rate
Ultimate Cost
Trend Rate
Year That Ultimate
Rate is Reached
7.00%
5.50
8.50
4.50%
4.50
4.50
2032
2032
2032
The total accumulated benefit obligation for the pension plans at December 31, 2023 and 2022 was as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
December 31, 2023
December 31, 2022
$ 11,991
11,422
$ 2,746
2,601
$3,674
3,534
$
$
546
520
145
135
$ 808
801
An actuarial loss of $0.5 billion and an actuarial gain of $3.9 billion were recorded for the annual remeasurement of the Southern Company
system pension plans at December 31, 2023 and 2022, respectively, primarily due to a decrease of 18 basis points and an increase of 216
basis points, respectively, in the overall discount rate used to calculate the benefit obligation as a result of higher market interest rates.
145
Southern Company 2023 Annual Report Notes to Financial Statements
Changes in the projected benefit obligations and the fair value of plan assets during the plan years ended December 31, 2023 and 2022
were as follows:
Change in benefit obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Benefits paid
Actuarial loss
Balance at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Fair value of plan assets at end of year
Accrued asset
Change in benefit obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Benefits paid
Actuarial gain
Balance at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual loss on plan assets
Employer contributions
Benefits paid
Fair value of plan assets at end of year
Accrued asset
2023
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$12,602
275
626
(744)
493
13,252
14,218
1,092
52
(744)
14,618
$ 1,366
$2,906
64
145
(155)
116
3,076
3,427
260
11
(154)
3,544
$ 468
$ 3,851
68
191
(224)
123
4,009
4,456
331
9
(225)
4,571
562
$
$ 569
11
28
(32)
23
599
649
50
2
(32)
669
$ 70
$163
6
8
(6)
6
177
178
12
2
(7)
185
8
$
2022
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 16,382
412
408
(692)
(3,908)
12,602
17,225
(2,376)
61
(692)
14,218
$ 1,616
$3,806
99
96
(144)
(951)
2,906
4,141
(579)
9
(144)
3,427
$ 521
$ 5,012
103
123
(226)
(1,161)
3,851
5,415
(753)
20
(226)
4,456
605
$
$ 743
17
18
(30)
(179)
569
786
(110)
3
(30)
649
$ 80
$222
9
6
(5)
(69)
163
213
(31)
1
(5)
178
$ 15
Southern
Company
Gas
$ 868
24
42
(104)
52
882
1,002
79
3
(104)
980
98
$
Southern
Company
Gas
$ 1,134
34
28
(75)
(253)
868
1,241
(167)
3
(75)
1,002
$ 134
The projected benefit obligations for the qualified and non-qualified pension plans at December 31, 2023 are shown in the following table.
All pension plan assets are related to the qualified pension plan.
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
(in millions)
$ 12,540
713
$2,959
117
$ 3,865
145
$ 569
29
$154
22
$ 822
60
Projected benefit obligations:
Qualified pension plan
Non-qualified pension plan
146
Southern Company 2023 Annual Report Notes to Financial Statements
Amounts recognized in the balance sheets at December 31, 2023 and 2022 related to the Registrants’ pension plans consist of the following:
December 31, 2023:
Prepaid pension costs(a)
Other regulatory assets, deferred(b)
Other current liabilities
Employee benefit obligations(c)
Other regulatory liabilities, deferred
AOCI
December 31, 2022:
Prepaid pension costs(a)
Other regulatory assets, deferred(b)
Other current liabilities
Employee benefit obligations(c)
Other regulatory liabilities, deferred
AOCI
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$2,079
2,960
(64)
(649)
(47)
79
$ 2,290
2,455
(56)
(618)
(85)
24
$ 585
821
(11)
(106)
—
—
$ 629
679
(10)
(98)
—
—
$ 706
1,051
(13)
(131)
—
—
$ 738
887
(12)
(121)
—
—
$ 99
152
(2)
(27)
—
—
$ 108
123
(2)
(26)
—
—
$ 31
—
(2)
(21)
—
20
$ 37
—
(2)
(20)
—
11
Southern
Company
Gas
$ 158
143
(3)
(58)
—
(45)
$ 183
111
(3)
(42)
—
(75)
(a) Included in prepaid pension and other postretirement benefit costs on Alabama Power’s balance sheet and other deferred charges and assets on Southern
Power’s consolidated balance sheet.
(b) Amounts for Southern Company exclude regulatory assets of $173 million and $190 million at December 31, 2023 and 2022, respectively, associated with
unamortized amounts in Southern Company Gas’ pension plans prior to its acquisition by Southern Company.
(c) Included in other deferred credits and liabilities on Southern Power’s consolidated balance sheets.
Presented below are the amounts included in regulatory assets at December 31, 2023 and 2022 related to the portion of the defined
benefit pension plan attributable to Southern Company, the traditional electric operating companies, and Southern Company Gas that had
not yet been recognized in net periodic pension cost.
Balance at December 31, 2023
Regulatory assets:
Prior service cost
Net loss
Regulatory amortization
Total regulatory assets(*)
Balance at December 31, 2022
Regulatory assets:
Prior service cost
Net loss
Regulatory amortization
Total regulatory assets(*)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
(in millions)
Southern
Company
Gas
$
9
2,904
—
$ 2,913
$
10
2,361
—
$ 2,371
$
4
817
—
$ 821
$
4
675
—
$ 679
$
6
1,045
—
$1,051
$
1
151
—
$ 152
$
7
880
—
$ 887
$
1
122
—
$ 123
$ (7)
100
50
$143
$ (9)
66
54
$111
(*) Amounts for Southern Company exclude regulatory assets of $173 million and $190 million at December 31, 2023 and 2022, respectively, associated with
unamortized amounts in Southern Company Gas’ pension plans prior to its acquisition by Southern Company.
147
Southern Company 2023 Annual Report Notes to Financial Statements
The changes in the balance of regulatory assets related to the portion of the defined benefit pension plan attributable to Southern
Company, the traditional electric operating companies, and Southern Company Gas for the years ended December 31, 2023 and 2022
are presented in the following table:
Regulatory assets (liabilities):(*)
Balance at December 31, 2021
Net (gain) loss
Reclassification adjustments:
Amortization of prior service costs
Amortization of net gain (loss)
Amortization of regulatory assets(*)
Total reclassification adjustments
Total change
Balance at December 31, 2022
Net loss
Reclassification adjustments:
Amortization of prior service costs
Amortization of net loss
Amortization of regulatory assets(*)
Total reclassification adjustments
Total change
Balance at December 31, 2023
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
(in millions)
Southern
Company
Gas
$ 2,801
(183)
(1)
(246)
—
(247)
(430)
$ 2,371
576
(1)
(33)
—
(34)
542
$2,913
$ 809
(67)
(1)
(62)
—
(63)
(130)
$ 679
153
(1)
(10)
—
(11)
142
$ 821
$ 971
(9)
(1)
(74)
—
(75)
(84)
$ 887
178
(1)
(13)
—
(14)
164
$1,051
$ 146
(12)
—
(11)
—
(11)
(23)
$ 123
31
—
(2)
—
(2)
29
$ 152
$ 91
27
2
1
(10)
(7)
20
$111
34
2
—
(4)
(2)
32
$143
(*) Amounts for Southern Company exclude regulatory assets of $173 million and $190 million at December 31, 2023 and 2022, respectively, associated with
unamortized amounts in Southern Company Gas’ pension plans prior to its acquisition by Southern Company.
Presented below are the amounts included in AOCI at December 31, 2023 and 2022 related to the portion of the defined benefit pension
plan attributable to Southern Company, Southern Power, and Southern Company Gas that had not yet been recognized in net periodic
pension cost.
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
$ (1)
80
$79
$ (2)
26
$24
$ —
20
$ 20
$ —
11
$ 11
$ (2)
(43)
$(45)
$ (3)
(72)
$(75)
Balance at December 31, 2023
AOCI:
Prior service cost
Net (gain) loss
Total AOCI
Balance at December 31, 2022
AOCI:
Prior service cost
Net (gain) loss
Total AOCI
148
Southern Company 2023 Annual Report Notes to Financial Statements
The components of OCI related to the portion of the defined benefit pension plan attributable to Southern Company, Southern Power, and
Southern Company Gas for the years ended December 31, 2023 and 2022 are presented in the following table:
AOCI:
Balance at December 31, 2021
Net gain
Reclassification adjustments:
Amortization of net gain (loss)
Total change
Balance at December 31, 2022
Net loss
Reclassification adjustments:
Amortization of prior service costs
Amortization of net loss
Total reclassification adjustments
Total change
Balance at December 31, 2023
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
$100
(82)
6
(76)
$ 24
62
1
(8)
(7)
55
$ 79
$ 35
(22)
(2)
(24)
$ 11
9
—
—
—
9
$ 20
$ (45)
(30)
—
(30)
$ (75)
29
1
—
1
30
$ (45)
149
Southern Company 2023 Annual Report Notes to Financial Statements
Components of net periodic pension cost for the Registrants were as follows:
2023
Service cost
Interest cost
Expected return on plan assets
Recognized net (gain) loss
Net amortization
Prior service cost
Net periodic pension cost (income)
2022
Service cost
Interest cost
Expected return on plan assets
Recognized net loss
Net amortization
Prior service cost
Net periodic pension cost (income)
2021
Service cost
Interest cost
Expected return on plan assets
Recognized net loss
Net amortization
Prior service cost
Net periodic pension cost (income)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
$
275
626
(1,229)
32
—
—
$ (296)
$
412
408
(1,265)
240
—
—
$ (205)
$
$
434
346
(1,191)
314
1
—
(96)
$ 64
145
(297)
9
1
—
$ (78)
$ 99
96
(306)
62
1
—
$ (48)
$ 102
82
(287)
82
1
—
$ (20)
$ 68
191
(385)
13
1
—
$(112)
$ 103
123
(399)
75
1
—
$ (97)
$ 112
104
(375)
100
1
—
$ (58)
$ 11
28
(56)
2
—
—
$(15)
$ 17
18
(57)
11
—
—
$(11)
$ 18
16
(55)
15
—
—
$ (6)
$ 6
8
(15)
—
—
—
$ (1)
$ 9
6
(15)
2
—
—
$ 2
$ 10
5
(14)
3
—
—
$ 4
$ 24
42
(85)
(5)
15
(3)
$(12)
$ 34
28
(91)
8
15
(3)
$ (9)
$ 37
24
(86)
13
15
(3)
$ —
The service cost component of net periodic pension cost is included in operations and maintenance expenses and all other components of
net periodic pension cost are included in other income (expense), net in the Registrants’ statements of income.
Net periodic pension cost is the sum of service cost, interest cost, and other costs netted against the expected return on plan assets.
The expected return on plan assets is determined by multiplying the expected rate of return on plan assets and the market-related value
of plan assets. In determining the market-related value of plan assets, the Registrants have elected to amortize changes in the market value
of return-seeking plan assets over five years and to recognize the changes in the market value of liability-hedging plan assets immediately.
Given the significant concentration in return-seeking plan assets, the accounting value of plan assets that is used to calculate the expected
return on plan assets differs from the current fair value of the plan assets.
150
Southern Company 2023 Annual Report Notes to Financial Statements
Future benefit payments reflect expected future service and are estimated based on assumptions used to measure the projected benefit
obligation for the pension plans. At December 31, 2023, estimated benefit payments were as follows:
Benefit Payments:
2024
2025
2026
2027
2028
2029 to 2033
Other Postretirement Benefits
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 748
776
801
822
840
4,417
$ 164
171
177
182
187
988
$ 241
248
254
257
260
1,337
$ 33
34
36
37
38
201
$ 7
7
8
8
7
47
Southern
Company
Gas
$ 57
59
60
62
64
336
Changes in the APBO and the fair value of the Registrants’ plan assets during the plan years ended December 31, 2023 and 2022 were as follows:
Change in benefit obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Benefits paid
Actuarial (gain) loss
Balance at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Fair value of plan assets at end of year
Accrued asset (liability)
Change in benefit obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Benefits paid
Actuarial gain
Retiree drug subsidy
Balance at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual loss on plan assets
Employer contributions
Benefits paid
Fair value of plan assets at end of year
Accrued asset (liability)
2023
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$1,441
15
70
(107)
(33)
1,386
998
131
73
(107)
1,095
$ (291)
$ 344
4
17
(24)
(12)
329
372
52
3
(24)
403
$ 74
$ 59
1
3
(4)
(2)
57
24
2
3
(4)
25
$ (32)
$ 514
4
25
(36)
(18)
489
368
51
27
(36)
410
$ (79)
2022
$ 9
—
—
(1)
1
9
—
—
1
(1)
—
$ (9)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 1,849
23
42
(109)
(365)
1
1,441
1,251
(218)
73
(108)
998
$ (443)
$ 440
6
10
(23)
(89)
—
344
489
(98)
4
(23)
372
$ 28
$ 656
6
15
(38)
(125)
—
514
450
(71)
27
(38)
368
$ (146)
$ 76
1
2
(4)
(16)
—
59
29
(4)
3
(4)
24
$ (35)
$11
—
—
(1)
(1)
—
9
—
—
1
(1)
—
$ (9)
Southern
Company
Gas
$ 179
1
9
(18)
1
172
113
19
14
(18)
128
$ (44)
Southern
Company
Gas
$ 237
1
5
(18)
(46)
—
179
143
(25)
13
(18)
113
$ (66)
151
Southern Company 2023 Annual Report Notes to Financial Statements
Amounts recognized in the balance sheets at December 31, 2023 and 2022 related to the Registrants’ other postretirement benefit plans
consist of the following:
December 31, 2023:
Prepaid other postretirement benefit costs(a)
Other regulatory assets, deferred(b)
Other current liabilities
Employee benefit obligations(c)
Other regulatory liabilities, deferred
AOCI
December 31, 2022:
Prepaid other postretirement benefit costs(a)
Other regulatory assets, deferred(b)
Other current liabilities
Employee benefit obligations(c)
Other regulatory liabilities, deferred
AOCI
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
Southern
Company
Gas
$ —
23
(6)
(285)
(231)
(9)
$ —
34
(6)
(437)
(170)
(4)
$ 74
—
—
—
(48)
—
$ 28
—
—
—
(21)
—
$ —
11
—
(79)
(85)
—
$ —
19
—
(146)
(58)
—
$ —
—
—
(32)
(10)
—
$ —
—
—
(35)
(9)
—
$ —
—
(1)
(8)
—
1
$ —
—
(1)
(8)
—
—
$ —
—
—
(44)
(68)
(10)
$ —
—
—
(66)
(58)
(2)
(a) Included in prepaid pension and other postretirement benefit costs on Alabama Power’s balance sheet.
(b) Amounts for Southern Company exclude regulatory assets of $24 million and $32 million at December 31, 2023 and 2022, respectively, associated with
unamortized amounts in Southern Company Gas’ other postretirement benefit plans prior to its acquisition by Southern Company.
(c) Included in other deferred credits and liabilities on Southern Power’s consolidated balance sheets.
Presented below are the amounts included in net regulatory assets (liabilities) at December 31, 2023 and 2022 related to the other
postretirement benefit plans of Southern Company, the traditional electric operating companies, and Southern Company Gas that had not
yet been recognized in net periodic other postretirement benefit cost.
Balance at December 31, 2023:
Regulatory assets (liabilities):
Prior service cost
Net gain
Regulatory amortization
Total regulatory assets (liabilities)(*)
Balance at December 31, 2022:
Regulatory assets (liabilities):
Prior service cost
Net gain
Regulatory amortization
Total regulatory assets (liabilities)(*)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
(in millions)
Southern
Company
Gas
$ 13
(216)
—
$(203)
$ 14
(150)
—
$ (136)
$ 4
(52)
—
$(48)
$ 4
(25)
—
$(21)
$ 5
(79)
—
$(74)
$ 6
(45)
—
$(39)
$ 1
(11)
—
$(10)
$ 1
(10)
—
$ (9)
$ —
(64)
(4)
$(68)
$ 1
(64)
5
$(58)
(*) Amounts for Southern Company exclude regulatory assets of $24 million and $32 million at December 31, 2023 and 2022, respectively, associated with
unamortized amounts in Southern Company Gas’ other postretirement benefit plans prior to its acquisition by Southern Company.
152
Southern Company 2023 Annual Report Notes to Financial Statements
The changes in the balance of net regulatory assets (liabilities) related to the other postretirement benefit plans for the plan years ended
December 31, 2023 and 2022 are presented in the following table:
Net regulatory assets (liabilities):(*)
Balance at December 31, 2021
Net (gain) loss
Reclassification adjustments:
Amortization of prior service costs
Amortization of net gain (loss)
Amortization of regulatory assets(*)
Total reclassification adjustments
Total change
Balance at December 31, 2022
Net gain
Reclassification adjustments:
Amortization of prior service costs
Amortization of net gain
Amortization of regulatory assets(*)
Total reclassification adjustments
Total change
Balance at December 31, 2023
Southern
Company
Alabama
Power
Georgia
Power
(in millions)
Mississippi
Power
Southern
Company
Gas
$ (74)
(64)
1
1
—
2
(62)
$ (136)
(77)
(1)
6
—
5
(72)
$ (208)
$(62)
41
—
—
—
—
41
$(21)
(30)
—
3
—
3
(27)
$(48)
$(10)
(27)
—
(2)
—
(2)
(29)
$(39)
(38)
(1)
4
—
3
(35)
$(74)
$ 1
(10)
—
—
—
—
(10)
$ (9)
(1)
—
—
—
—
(1)
$(10)
$(34)
(13)
—
—
(11)
(11)
(24)
$(58)
—
—
—
(10)
(10)
(10)
$(68)
(*) Amounts for Southern Company exclude regulatory assets of $24 million and $32 million at December 31, 2023 and 2022, respectively, associated with
unamortized amounts in Southern Company Gas’ other postretirement benefit plans prior to its acquisition by Southern Company.
Presented below are the amounts included in AOCI at December 31, 2023 and 2022 related to the other postretirement benefit plans of
Southern Company, Southern Power, and Southern Company Gas that had not yet been recognized in net periodic other postretirement
benefit cost.
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
Balance at December 31, 2023
AOCI:
Prior service cost
Net (gain) loss
Total AOCI
Balance at December 31, 2022
AOCI:
Prior service cost
Net (gain) loss
Total AOCI
$ 1
(10)
$ (9)
$ 1
(5)
$ (4)
$ —
1
$ 1
$ —
—
$ —
$ —
(10)
$ (10)
$ —
(2)
$ (2)
153
Southern Company 2023 Annual Report Notes to Financial Statements
The components of OCI related to the other postretirement benefit plans for the plan years ended December 31, 2023 and 2022 are
presented in the following table:
Southern
Company
Southern
Power
(in millions)
Southern
Company
Gas
AOCI:
Balance at December 31, 2021
Net gain
Reclassification adjustments:
Amortization of net gain (loss)
Total change
Balance at December 31, 2022
Net (gain) loss
Reclassification adjustments:
Amortization of net gain (loss)
Total change
Balance at December 31, 2023
$ —
(3)
(1)
(4)
$ (4)
(12)
7
(5)
$ (9)
$ 2
(2)
—
(2)
$ —
1
—
1
$ 1
Components of the other postretirement benefit plans’ net periodic cost for the Registrants were as follows:
2023
Service cost
Interest cost
Expected return on plan assets
Net amortization
Net periodic postretirement benefit cost (income)
2022
Service cost
Interest cost
Expected return on plan assets
Net amortization
Net periodic postretirement benefit cost (income)
2021
Service cost
Interest cost
Expected return on plan assets
Net amortization
Net periodic postretirement benefit cost (income)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$ 15
70
(83)
(11)
$ (9)
$ 23
42
(80)
(1)
$ (16)
$ 24
35
(76)
2
$ (15)
$ 4
17
(33)
(3)
$ (15)
$ 6
10
(32)
—
$ (16)
$ 6
9
(30)
—
$ (15)
$ 4
25
(29)
(3)
$ (3)
$ 6
15
(28)
2
$ (5)
$ 7
12
(26)
2
$ (5)
$ 1
3
(3)
—
$ 1
$ 1
2
(2)
—
$ 1
$ 1
1
(1)
—
$ 1
$ —
—
1
—
$ 1
$ —
—
1
—
$ 1
$ —
—
1
—
$ 1
$ (5)
—
3
3
$ (2)
—
(8)
(8)
$ (10)
Southern
Company
Gas
$ 1
9
(10)
6
$ 6
$ 1
5
(9)
6
$ 3
$ 2
4
(10)
6
$ 2
154
Southern Company 2023 Annual Report Notes to Financial Statements
The service cost component of net periodic postretirement benefit cost is included in operations and maintenance expenses and all
other components of net periodic postretirement benefit cost are included in other income (expense), net in the Registrants’ statements
of income.
The Registrants’ future benefit payments, including prescription drug benefits, are provided in the table below. These amounts reflect
expected future service and are estimated based on assumptions used to measure the APBO for the other postretirement benefit plans.
Benefit payments:
2024
2025
2026
2027
2028
2029 to 2033
Benefit Plan Assets
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
(in millions)
$111
109
108
108
108
523
$ 24
24
24
24
25
123
$ 40
39
38
38
38
188
$ 5
5
5
5
4
21
$ 1
1
1
1
1
1
Southern
Company
Gas
$ 17
17
16
16
15
64
Pension plan and other postretirement benefit plan assets are managed and invested in accordance with all applicable requirements,
including ERISA and the Internal Revenue Code. The Registrants’ investment policies for both the pension plans and the other
postretirement benefit plans cover a diversified mix of assets as described below. Derivative instruments may be used to gain efficient
exposure to the various asset classes and as hedging tools. Additionally, the Registrants minimize the risk of large losses primarily through
diversification but also monitor and manage other aspects of risk.
The investment strategy for plan assets related to the Southern Company system’s qualified pension plan is to be broadly diversified
across major asset classes. The asset allocation is established after consideration of various factors that affect the assets and liabilities
of the pension plan including, but not limited to, historical and expected returns and interest rates, volatility, correlations of asset
classes, the current level of assets and liabilities, and the assumed growth in assets and liabilities. Because a significant portion of the
liability of the pension plan is long-term in nature, the assets are invested consistent with long-term investment expectations for return
and risk. To manage the actual asset class exposures relative to the target asset allocation, the Southern Company system employs a
formal rebalancing program. As additional risk management, external investment managers and service providers are subject to written
guidelines to ensure appropriate and prudent investment practices. Management believes the portfolio is well-diversified with no
significant concentrations of risk.
155
Southern Company 2023 Annual Report Notes to Financial Statements
Investment Strategies and Benefit Plan Asset Fair Values
A description of the major asset classes that the pension and other postretirement benefit plans are comprised of, along with the valuation
methods used for fair value measurement, is provided below:
Description
Valuation Methodology
Domestic equity: A mix of large and small capitalization
stocks with generally an equal distribution of value and
Domestic and international equities such as common stocks,
American depositary receipts, and real estate investment trusts that
growth attributes, managed both actively and through
trade on public exchanges are classified as Level 1 investments and
passive index approaches.
International equity: A mix of large and small capitalization
growth and value stocks with developed and emerging markets
exposure, managed both actively and through fundamental
indexing approaches.
are valued at the closing price in the active market. Equity funds with
unpublished prices that are comprised of publicly traded securities
(such as commingled/pooled funds) are also valued at the closing
price in the active market, but are classified as Level 2.
Fixed income: A mix of domestic and international bonds.
Investments in fixed income securities, including fixed income pooled
funds, are generally classified as Level 2 investments and are valued
based on prices reported in the market place. Additionally, the value
of fixed income securities takes into consideration certain items such
as broker quotes, spreads, yield curves, interest rates, and discount
rates that apply to the term of a specific instrument.
Trust-owned life insurance (TOLI): Investments of taxable
trusts aimed at minimizing the impact of taxes on the portfolio.
Investments in TOLI policies are classified as Level 2 investments and
are valued based on the underlying investments held in the policy’s
separate accounts. The underlying assets are equity and fixed income
pooled funds that are comprised of Level 1 and Level 2 securities.
Real estate: Investments in equity or debt of real properties and
in publicly traded real estate securities.
Investments in real estate, special situations, private equity,
private credit, and infrastructure are typically invested in private
Special situations: Investments in opportunistic strategies
with the objective of diversifying and enhancing returns and
exploiting short-term inefficiencies, as well as investments in
promising new strategies of a longer-term nature.
Private equity: Investments in private or public securities
typically through privately-negotiated and/or structured
transactions, including leveraged buyouts, venture capital, and
distressed debt.
Private credit: Investments focused on debt instruments,
of which returns are driven by income rather than
capital appreciation.
Infrastructure: Investments in real assets, typically with
long-term, predictable, and stable cash flows and a meaningful
income component.
partnerships and/or other pooled vehicles (Funds) which are generally
classified as Net Asset Value as a Practical Expedient, since the
Funds and underlying assets are not publicly traded and/or often
have liquidity restrictions. The managers of the Funds value the
assets using various inputs and techniques depending on the nature
of the underlying investments. Techniques may include purchase
multiples for comparable transactions, comparable public company
trading multiples, discounted cash flow analysis, prevailing market
capitalization rates, recent sales of comparable investments, and
independent third-party appraisals. The total market value of each of
the Funds is determined by aggregating the value of the underlying
assets less liabilities.
For purposes of determining the fair value of the pension plan and other postretirement benefit plan assets and the appropriate level
designation, management relies on information provided by the plan’s trustee. This information is reviewed and evaluated by management
with changes made to the trustee information as appropriate. The fair values presented herein exclude cash, receivables related to
investment income and pending investment sales, and payables related to pending investment purchases.
156
Southern Company 2023 Annual Report Notes to Financial Statements
The fair values, and actual allocations relative to the target allocations, of the Southern Company system’s pension plans at
December 31, 2023 and 2022 are presented below.
At December 31, 2023:
Southern Company
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Alabama Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Net Asset
Value as a
Practical
Expedient
(NAV)
Significant
Unobservable
Inputs
(Level 3)
(in millions)
Total
Target
Allocation
Actual
Allocation
$ 1,959
1,947
—
—
—
—
371
369
—
—
—
—
$ 4,646
$ 476
472
—
—
—
—
90
89
—
—
—
—
$ 1,127
$ 771
1,052
1,973
44
1,724
777
58
—
—
—
—
—
$ 6,399
$ 187
255
479
11
418
188
14
—
—
—
—
—
$ 1,552
$ —
—
—
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
—
—
—
—
—
$ —
$ — $ 2,730
2,999
—
—
—
—
—
—
1,684
245
1,761
25
—
$ 3,715
1,973
44
1,724
777
429
2,053
245
1,761
25
—
$14,760
$ — $
—
663
727
—
—
—
—
—
408
59
427
6
—
$ 900
479
11
418
188
104
497
59
427
6
—
$ 3,579
41%
40%
30
32
12
3
9
3
2
100%
14
2
12
—
—
100%
41%
40%
30
32
12
3
9
3
2
100%
14
2
12
—
—
100%
157
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2023:
Georgia Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Mississippi Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
(in millions)
Net Asset
Value as a
Practical
Expedient
(NAV)
Total
Target
Allocation
Actual
Allocation
$ 611
609
—
—
—
—
116
115
—
—
—
—
$ 1,451
$
89
89
—
—
—
—
17
17
—
—
—
—
$ 212
$ 241
329
617
14
539
243
18
—
—
—
—
—
$ 2,001
$
35
48
90
2
79
36
3
—
—
—
—
—
$ 293
$ —
—
—
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
—
—
—
—
—
$ —
$ — $ 852
938
—
—
—
—
—
—
527
77
551
8
—
$ 1,163
617
14
539
243
134
642
77
551
8
—
$ 4,615
$ — $ 124
137
—
—
—
—
—
—
77
11
81
1
—
$ 170
90
2
79
36
20
94
11
81
1
—
$ 675
41%
40%
30
32
12
3
9
3
2
100%
14
2
12
—
—
100%
41%
40%
30
32
12
3
9
3
2
100%
14
2
12
—
—
100%
158
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2023:
Southern Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Southern Company Gas
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Net Asset
Value as a
Practical
Expedient
(NAV)
Significant
Unobservable
Inputs
(Level 3)
(in millions)
Total
Target
Allocation
Actual
Allocation
$ 24
25
—
—
—
—
5
5
—
—
—
—
$ 59
$130
130
—
—
—
—
25
25
—
—
—
—
$310
$ 10
13
25
1
22
10
1
—
—
—
—
—
$ 82
$ 52
71
132
3
116
52
4
—
—
—
—
—
$430
$ —
—
—
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
21
3
22
—
—
$ 46
$ —
—
—
—
—
—
—
113
16
118
2
—
$249
$ 34
38
25
1
22
10
6
26
3
22
—
—
$187
$182
201
132
3
116
52
29
138
16
118
2
—
$989
41%
40%
30
32
12
3
9
3
2
100%
14
2
12
—
—
100%
41%
40%
30
32
12
3
9
3
2
100%
14
2
12
—
—
100%
159
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2022:
Southern Company
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
Liabilities:
Derivatives
Total
Alabama Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
Liabilities:
Derivatives
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
(in millions)
Net Asset
Value as a
Practical
Expedient
(NAV)
Total
Target
Allocation
Actual
Allocation
$ 2,078
2,166
—
—
—
—
399
376
—
—
$ 5,019
(4)
$ 5,015
$ 500
522
—
—
—
—
96
91
—
—
$ 1,209
(1)
$ 1,208
$ 691
1,090
1,469
29
1,494
607
7
—
—
—
$ 5,387
—
$ 5,387
$ 167
263
354
7
360
146
2
—
—
—
$ 1,299
—
$ 1,299
$ —
—
—
—
—
—
—
—
—
—
$ —
—
$ —
$ —
—
—
—
—
—
—
—
—
—
$ —
—
$ —
$ — $ 2,769
3,256
—
—
—
—
—
—
1,887
187
1,717
$ 3,791
1,469
29
1,494
607
406
2,263
187
1,717
$14,197
45%
43%
30
28
13
3
9
100%
15
2
12
100%
—
$ 3,791
(4)
$14,193
100%
100%
$ — $
—
667
785
—
—
—
—
—
455
45
414
$ 914
354
7
360
146
98
546
45
414
$ 3,422
45%
43%
30
28
13
3
9
100%
15
2
12
100%
—
$ 914
(1)
$ 3,421
100%
100%
160
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2022:
Georgia Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
Liabilities:
Derivatives
Total
Mississippi Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
Southern Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
(in millions)
Net Asset
Value as a
Practical
Expedient
(NAV)
Total
Target
Allocation
Actual
Allocation
$ 651
678
—
—
—
—
125
118
—
—
$ 1,572
$ 217
342
460
9
468
190
2
—
—
—
$ 1,688
(1)
$ 1,571
—
$ 1,688
$
95
99
—
—
—
—
18
17
—
—
$ 229
$
$
25
27
—
—
—
5
5
—
—
62
$
32
50
67
1
68
28
—
—
—
—
$ 246
$
$
9
14
18
19
8
—
—
—
—
68
$ —
—
—
—
—
—
—
—
—
—
$ —
—
$ —
$ —
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
—
—
$ —
$ — $ 868
1,020
—
—
—
—
—
—
591
59
538
$ 1,188
460
9
468
190
127
709
59
538
$4,448
45%
43%
30
28
13
3
9
100%
15
2
12
100%
—
$ 1,188
(1)
$4,447
100%
100%
$ — $ 127
149
—
—
—
—
—
—
86
9
78
$ 173
67
1
68
28
18
103
9
78
$ 648
$ — $
—
34
41
—
—
—
—
24
2
21
47
18
19
8
5
29
2
21
$ 177
$
45%
43%
30
28
13
3
9
100%
15
2
12
100%
45%
43%
30
28
13
3
9
100%
15
2
12
100%
161
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2022:
Southern Company Gas
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
(in millions)
Net Asset
Value as a
Practical
Expedient
(NAV)
Total
Target
Allocation
Actual
Allocation
$ 146
152
—
—
—
—
28
27
—
—
$ 353
$ 49
77
104
2
105
43
1
—
—
—
$ 381
$ —
—
—
—
—
—
—
—
—
—
$ —
$ — $ 195
229
—
—
—
—
—
—
133
13
121
$ 267
104
2
105
43
29
160
13
121
$ 1,001
45%
43%
30
28
13
3
9
100%
15
2
12
100%
162
Southern Company 2023 Annual Report Notes to Financial Statements
The fair values, and actual allocations relative to the target allocations, of the applicable Registrants’ other postretirement benefit plan
assets at December 31, 2023 and 2022 are presented below.
At December 31, 2023:
Southern Company
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Trust-owned life insurance
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Alabama Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Trust-owned life insurance
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Net Asset
Value as a
Practical
Expedient
(NAV)
(in millions)
Total
Target
Allocation
Actual
Allocation
$ 85
53
—
—
—
—
21
—
11
—
—
—
—
$170
$ 16
16
—
—
—
3
—
3
—
—
—
—
$ 38
$ 87
82
57
2
47
92
2
456
—
—
—
—
—
$825
$
6
9
16
14
8
—
280
—
—
—
—
—
$333
$ —
—
—
—
—
—
—
—
46
6
48
1
—
$101
$ —
—
—
—
—
—
—
14
2
15
—
—
$ 31
$ 172
135
57
2
47
92
23
456
57
6
48
1
—
$ 1,096
$
22
25
16
14
8
3
280
17
2
15
—
—
$ 402
60%
61%
30
28
4
1
3
1
1
100%
6
1
4
—
—
100%
67%
66%
23
23
4
1
3
1
1
100%
6
1
4
—
—
100%
163
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2023:
Georgia Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Trust-owned life insurance
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Mississippi Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Private credit
Infrastructure
Total
Southern Company Gas
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Trust-owned life insurance
Real estate investments
Private equity
Total
164
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Net Asset
Value as a
Practical
Expedient
(NAV)
(in millions)
Total
Target
Allocation
Actual
Allocation
$47
16
—
—
—
13
—
4
—
—
—
—
$80
$ 3
3
—
—
—
1
1
—
—
—
—
$ 8
$ 2
2
—
—
—
1
—
—
—
$ 5
$
6
40
16
14
47
—
176
—
—
—
—
—
$299
$
1
1
7
2
1
—
—
—
—
—
—
$ 12
$ 67
22
1
1
29
—
—
—
—
$120
$ —
—
—
—
—
—
—
14
2
14
—
—
$30
$ —
—
—
—
—
—
2
—
2
—
—
$ 4
$ —
—
—
—
—
—
—
1
1
$ 2
$ 53
56
16
14
47
13
176
18
2
14
—
—
$409
$
4
4
7
2
1
1
3
—
2
—
—
$ 24
$ 69
24
1
1
29
1
—
1
1
$127
58%
57%
35
35
3
1
2
1
—
100%
4
1
3
—
—
100%
34%
33%
43
44
10
2
7
3
1
100%
11
2
10
—
—
100%
72%
72%
26
26
1
1
100%
1
1
100%
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2022:
Southern Company
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Mortgage- and asset-backed securities
Corporate bonds
Pooled funds
Cash equivalents and other
Trust-owned life insurance
Real estate investments
Special situations
Private equity
Total
Alabama Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Trust-owned life insurance
Real estate investments
Special situations
Private equity
Total
Georgia Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Trust-owned life insurance
Real estate investments
Special situations
Private equity
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Net Asset
Value as a
Practical
Expedient
(NAV)
(in millions)
Total
Target
Allocation
Actual
Allocation
$ 85
58
—
—
—
—
19
—
11
—
—
$173
$ 17
18
—
—
—
3
—
3
—
—
$ 41
$ 46
17
—
—
—
9
—
4
—
—
$ 76
$ 74
79
43
1
40
79
—
406
—
—
—
$722
$
6
9
12
12
7
—
252
—
—
—
$298
$
6
39
10
12
40
—
154
—
—
—
$261
$ —
—
—
—
—
—
—
—
51
6
46
$103
$ —
—
—
—
—
—
—
16
2
14
$ 32
$ —
—
—
—
—
—
—
15
2
14
$ 31
$159
137
43
1
40
79
19
406
62
6
46
$998
$ 23
27
12
12
7
3
252
19
2
14
$371
$ 52
56
10
12
40
9
154
19
2
14
$368
61%
59%
30
28
5
1
3
100%
7
1
5
100%
69%
65%
23
23
4
1
3
100%
7
1
4
100%
58%
56%
35
34
4
1
2
100%
5
1
4
100%
165
Southern Company 2023 Annual Report Notes to Financial Statements
At December 31, 2022:
Mississippi Power
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Special situations
Private equity
Total
Southern Company Gas
Assets:
Equity:
Domestic equity
International equity
Fixed income:
U.S. Treasury, government, and agency bonds
Corporate bonds
Pooled funds
Cash equivalents and other
Real estate investments
Private equity
Total
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Net Asset
Value as a
Practical
Expedient
(NAV)
(in millions)
Total
Target
Allocation
Actual
Allocation
$ 3
3
—
—
—
2
1
—
—
$ 9
$ 2
2
—
—
—
1
—
—
$ 5
$
1
2
4
2
1
—
—
—
—
$ 10
$ 56
20
1
1
27
—
—
—
$105
$ —
—
—
—
—
—
3
—
2
$ 5
$ —
—
—
—
—
—
2
1
$ 3
$
4
5
4
2
1
2
4
—
2
$ 24
$ 58
22
1
1
27
1
2
1
$113
37%
35%
43
41
11
2
7
100%
12
2
10
100%
72%
70%
26
27
1
1
100%
2
1
100%
Employee Savings Plan
Southern Company and its subsidiaries also sponsor 401(k) defined contribution plans covering substantially all employees and provide
matching contributions up to specified percentages of an employee’s eligible pay. Total matching contributions made to the plans for 2023,
2022, and 2021 were as follows:
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas
$131
124
119
$28
26
26
(in millions)
$31
29
28
$5
5
5
$3
3
2
$18
17
16
2023
2022
2021
166
Southern Company 2023 Annual Report Notes to Financial Statements
12. STOCK COMPENSATION
Stock-based compensation primarily in the form of Southern Company performance share units (PSU) and restricted stock units (RSU) may
be granted through the Equity and Incentive Compensation Plan to Southern Company system employees ranging from line management
to executives.
At December 31, 2023, the number of current and former employees participating in stock-based compensation programs for the Registrants was
as follows:
Number of employees
Southern
Company
1,401
Alabama
Power
191
Georgia
Power
210
Mississippi
Power
Southern
Power
Southern
Company Gas
42
40
193
The majority of PSUs and RSUs awarded contain terms where employees become immediately vested in PSUs and RSUs upon retirement.
As a result, compensation expense for employees that are retirement eligible at the grant date is recognized immediately, while compensation
expense for employees that become retirement eligible during the vesting period is recognized over the period from grant date to the date of
retirement eligibility. In addition, the Registrants recognize forfeitures as they occur.
All unvested PSUs and RSUs vest immediately upon a change in control where Southern Company is not the surviving corporation.
Performance Share Units
PSUs granted to employees vest at the end of a three-year performance period. Shares of Southern Company common stock are delivered
to employees at the end of the performance period with the number of shares issued ranging from 0% to 200% of the target number of
PSUs granted, based on achievement of the performance goals established by the Compensation Committee of the Southern Company
Board of Directors.
Southern Company has issued two types of PSUs, each with a unique performance goal. These types of PSUs include total shareholder
return (TSR) awards based on the TSR for Southern Company common stock during the three-year performance period as compared to a
group of industry peers and ROE awards based on Southern Company’s equity-weighted return over the performance period.
The fair value of TSR awards is determined as of the grant date using a Monte Carlo simulation model. In determining the fair value of the
TSR awards issued to employees, the expected volatility is based on the historical volatility of Southern Company’s stock over a period
equal to the performance period. The risk-free rate is based on the U.S. Treasury yield curve in effect at the time of grant that covers
the performance period of the awards. The following table shows the assumptions used in the pricing model and the weighted average
grant-date fair value of TSR awards granted:
Year Ended December 31
Expected volatility
Expected term (in years)
Interest rate
Weighted average grant-date fair value
2023
30.0%
3
3.8%
2022
29.6%
3
1.7%
2021
30.0%
3
0.2%
$76.83
$79.69
$69.06
The Registrants recognize TSR award compensation expense on a straight-line basis over the three-year performance period without remeasurement.
The fair values of ROE awards are based on the closing stock price of Southern Company common stock on the date of the grant. The weighted
average grant-date fair value of the ROE awards granted during 2023, 2022, and 2021 was $68.93, $66.87, and $59.49, respectively.
Compensation expense for ROE awards is generally recognized ratably over the three-year performance period adjusted for expected changes in
ROE performance. Total compensation cost recognized for vested ROE awards reflects final performance metrics.
Southern Company had 2.4 million unvested PSUs outstanding at December 31, 2022. In February 2023, the PSUs that vested for the three-year
performance period ended December 31, 2022 were converted into 1.8 million shares outstanding at a share price of $67.13. During 2023,
Southern Company granted 1.3 million PSUs and 1.3 million PSUs were vested or forfeited, resulting in 2.4 million unvested PSUs outstanding
at December 31, 2023. In February 2024, the PSUs that vested for the three-year performance period ended December 31, 2023 were
converted into 2.3 million shares outstanding at a weighted average share price of $66.95.
167
Southern Company 2023 Annual Report Notes to Financial Statements
Total PSU compensation cost, and the related tax benefit recognized in income, for the years ended December 31, 2023, 2022, and 2021 are as
follows:
Southern Company
Compensation cost recognized in income
Tax benefit of compensation cost recognized in income
Southern Company Gas
Compensation cost recognized in income
Tax benefit of compensation cost recognized in income
2023
$107
28
$ 14
4
2022
(in millions)
$101
26
$ 12
4
2021
$ 112
29
$ 17
4
Total PSU compensation cost and the related tax benefit recognized in income were immaterial for all periods presented for all other
Registrants. The compensation cost related to the grant of Southern Company PSUs to the employees of each Subsidiary Registrant is
recognized in each Subsidiary Registrant’s financial statements with a corresponding credit to equity representing a capital contribution
from Southern Company.
At December 31, 2023, Southern Company’s total unrecognized compensation cost related to PSUs was $32 million and is expected to be
recognized over a weighted-average period of approximately 19 months. The total unrecognized compensation cost related to PSUs at
December 31, 2023 was immaterial for all other Registrants.
Restricted Stock Units
The fair value of RSUs is based on the closing stock price of Southern Company common stock on the date of the grant. The weighted
average grant-date fair values of RSUs granted during 2023, 2022, and 2021 were $68.95, $67.20, and $59.56, respectively. For most
RSU awards, one-third of the RSUs vest each year throughout a three-year service period and compensation cost for RSUs is generally
recognized over the corresponding one-, two-, or three-year vesting period. Shares of Southern Company common stock are delivered to
employees at the end of each vesting period.
Southern Company had 0.9 million RSUs outstanding at December 31, 2022. During 2023, Southern Company granted 0.5 million RSUs and
0.5 million RSUs were vested or forfeited, resulting in 0.9 million unvested RSUs outstanding at December 31, 2023, including RSUs related
to employee retention agreements.
For the years ended December 31, 2023, 2022, and 2021, Southern Company’s total compensation cost for RSUs recognized in income
was $30 million, $26 million, and $32 million, respectively. The related tax benefit also recognized in income was $8 million, $7 million,
and $8 million for the years ended December 31, 2023, 2022, and 2021, respectively. Total unrecognized compensation cost related to
RSUs at December 31, 2023, which is being recognized over a weighted-average period of approximately 17 months, is immaterial for
Southern Company.
Total RSUs outstanding and total compensation cost and related tax benefit for the RSUs recognized in income for the years ended
December 31, 2023, 2022, and 2021, as well as the total unrecognized compensation cost at December 31, 2023, were immaterial for all
other Registrants. The compensation cost related to the grant of Southern Company RSUs to the employees of each Subsidiary Registrant
is recognized in such Subsidiary Registrant’s financial statements with a corresponding credit to equity representing a capital contribution
from Southern Company.
Stock Options
In 2015, Southern Company discontinued granting stock options. As of December 31, 2017, all stock option awards were vested and
compensation cost fully recognized. Stock options expire no later than 10 years after the grant date and the latest possible exercise will
occur by November 2024. At December 31, 2023, the weighted average remaining contractual term for the options outstanding and
exercisable was approximately 2 months.
Southern Company’s activity in the stock option program for 2023 is summarized below:
Outstanding at December 31, 2022
Exercised
Outstanding and Exercisable at December 31, 2023
168
Shares Subject to
Option
Weighted Average
Exercise Price
(in millions)
1.0
0.7
0.3
$42.22
42.54
$41.58
Southern Company 2023 Annual Report Notes to Financial Statements
Southern Company’s cash receipts from issuances related to stock options exercised under the share-based payment arrangements for the
years ended December 31, 2023, 2022, and 2021 were $28 million, $75 million, and $66 million, respectively.
At December 31, 2023, the aggregate intrinsic value for options outstanding and exercisable was immaterial for all Registrants.
Total intrinsic value of options exercised, and the related tax benefit, for the years ended December 31, 2023, 2022, and 2021 are
presented below for Southern Company and were immaterial for all other Registrants:
Year Ended December 31
Southern Company
Intrinsic value of options exercised
Tax benefit of options exercised
13. FAIR VALUE MEASUREMENTS
2023
2022
(in millions)
$18
4
$49
12
2021
$34
7
Fair value measurements are based on inputs of observable and unobservable market data that a market participant would use in pricing the
asset or liability. The use of observable inputs is maximized where available and the use of unobservable inputs is minimized for fair value
measurement and reflects a three-tier fair value hierarchy that prioritizes inputs to valuation techniques used for fair value measurement.
O Level 1 consists of observable market data in an active market for identical assets or liabilities.
O Level 2 consists of observable market data, other than that included in Level 1, that is either directly or indirectly observable.
O Level 3 consists of unobservable market data. The input may reflect the assumptions of each Registrant of what a market participant
would use in pricing an asset or liability. If there is little available market data, then each Registrant’s own assumptions are the best
available information.
In the case of multiple inputs being used in a fair value measurement, the lowest level input that is significant to the fair value
measurement represents the level in the fair value hierarchy in which the fair value measurement is reported.
Net asset value as a practical expedient is the classification used for assets that do not have readily determined fair values. Fund managers
value the assets using various inputs and techniques depending on the nature of the underlying investments.
169
Southern Company 2023 Annual Report At December 31, 2023, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated
level of the fair value hierarchy, were as follows:
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
Significant
Other
Observable
Inputs
Significant
Unobservable
Inputs
(Level 1)
(Level 2)
(Level 3)
Net Asset
Value as a
Practical
Expedient
(NAV)
(in millions)
Total
$
6
$
49
$ —
$ —
$
55
764
145
—
—
—
—
—
—
3
58
253
9
$ 1,238
$
$
46
—
—
3
—
49
216
171
369
48
6
389
89
—
—
3
15
27
$ 1,382
$ 312
264
122
—
13
$ 711
—
—
—
—
—
—
—
—
—
—
—
8
$ 8
$ —
—
—
16
—
$ 16
—
—
—
—
—
—
—
169
—
9
—
—
$178
$ —
—
—
—
—
$ —
980
316
369
48
6
389
89
169
3
70
268
44
$2,806
$ 358
264
122
19
13
$ 776
$ —
$
15
$ —
$ —
$
15
443
145
—
—
—
—
—
8
119
—
$ 715
208
—
20
1
231
25
—
—
15
27
$ 542
$ —
$ 110
—
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
—
—
—
—
169
9
—
—
$178
$ —
651
145
20
1
231
25
169
17
134
27
$1,435
$ 110
At December 31, 2023:
Southern Company
Assets:
Energy-related derivatives(a)
Investments in trusts:(b)
Domestic equity
Foreign equity
U.S. Treasury and government agency
securities
Municipal bonds
Pooled funds – fixed income
Corporate bonds
Mortgage and asset backed securities
Private equity
Cash and cash equivalents
Other
Cash equivalents and restricted cash
Other investments
Total
Liabilities:
Energy-related derivatives(a)
Interest rate derivatives
Foreign currency derivatives
Contingent consideration
Other
Total
Alabama Power
Assets:
Energy-related derivatives
Nuclear decommissioning trusts:(b)
Domestic equity
Foreign equity
U.S. Treasury and government agency
securities
Municipal bonds
Corporate bonds
Mortgage and asset backed securities
Private equity
Other
Cash equivalents and restricted cash
Other investments
Total
Liabilities:
Energy-related derivatives
170
Notes to Financial StatementsSouthern Company 2023 Annual Report Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
Significant
Other
Observable
Inputs
Significant
Unobservable
Inputs
Net Asset Value
as a Practical
Expedient
At December 31, 2023:
(Level 1)
(Level 2)
(Level 3)
(NAV)
Total
(in millions)
Georgia Power
Assets:
Energy-related derivatives
Nuclear decommissioning trusts:(b)
Domestic equity
Foreign equity
U.S. Treasury and government agency securities
Municipal bonds
Corporate bonds
Mortgage and asset backed securities
Other
Total
Liabilities:
Energy-related derivatives
Mississippi Power
Assets:
Energy-related derivatives
Cash equivalents
Total
Liabilities:
Energy-related derivatives
Southern Power
Assets:
Energy-related derivatives
Liabilities:
Energy-related derivatives
Foreign currency derivatives
Contingent consideration
Other
Total
Southern Company Gas
Assets:
Energy-related derivatives(a)
Non-qualified deferred compensation trusts:
Domestic equity
Foreign equity
Pooled funds - fixed income
Cash and cash equivalents
Total
Liabilities:
Energy-related derivatives(a)(b)
Interest rate derivatives
Total
$ —
321
—
—
—
—
—
50
$371
$ —
$ —
17
$ 17
$ —
$ —
$ —
—
3
—
3
$
$
6
—
—
—
3
9
$
$ 46
—
$ 46
$ 13
1
170
349
47
158
64
3
$ 805
$ 124
$ 15
—
$ 15
$ 61
$
3
$
5
22
—
13
$ 40
$
3
7
1
6
—
$ 17
$ 12
79
$ 91
$ —
—
—
—
—
—
—
—
$ —
$ —
$ —
—
$ —
$ —
$ —
$ —
—
16
—
$ 16
$ —
—
—
—
—
$ —
$ —
—
$ —
$ —
—
—
—
—
—
—
—
$ —
$ —
$ —
—
$ —
$ —
$ —
$ —
—
—
—
$ —
$ —
—
—
—
—
$ —
$ —
—
$ —
$
13
322
170
349
47
158
64
53
$1,176
$ 124
$
$
$
$
$
$
15
17
32
61
3
5
22
19
13
59
$
9
7
1
6
3
26
$
$
58
79
$ 137
(a) Excludes cash collateral of $62 million.
(b) Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6
under “Nuclear Decommissioning” for additional information.
171
Notes to Financial StatementsSouthern Company 2023 Annual Report At December 31, 2022, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated
level of the fair value hierarchy, were as follows:
Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
Significant
Other
Observable
Inputs
Significant
Unobservable
Inputs
Net Asset Value
as a Practical
Expedient
At December 31, 2022:
(Level 1)
(Level 2)
(Level 3)
(NAV)
Total
(in millions)
Southern Company
Assets:
Energy-related derivatives(a)
Interest rate derivatives
Investments in trusts:(b)(c)
Domestic equity
Foreign equity
U.S. Treasury and government agency securities
Municipal bonds
Pooled funds – fixed income
Corporate bonds
Mortgage and asset backed securities
Private equity
Cash and cash equivalents
Other
Cash equivalents
Other investments
Total
Liabilities:
Energy-related derivatives(a)
Interest rate derivatives
Foreign currency derivatives
Contingent consideration
Other
Total
Alabama Power
Assets:
Energy-related derivatives
Nuclear decommissioning trusts:(b)
Domestic equity
Foreign equity
U.S. Treasury and government agency securities
Municipal bonds
Corporate bonds
Mortgage and asset backed securities
Private equity
Other
Cash equivalents
Other investments
Total
Liabilities:
$
18
—
651
125
—
—
—
—
—
—
4
37
1,427
9
$ 2,271
$
$
32
—
—
—
—
32
$ 181
12
178
150
285
51
7
412
90
—
—
12
20
26
$1,424
$ 178
302
216
—
13
$ 709
$ —
$
62
396
125
—
—
—
—
—
7
438
—
$ 966
169
—
19
1
225
22
—
—
20
26
$ 544
Energy-related derivatives
$ —
$
39
172
$ —
—
—
—
—
—
—
—
—
—
—
—
—
—
$ —
$ —
—
—
12
—
$ 12
$ —
—
—
—
—
—
—
—
—
—
—
$ —
$ —
$ —
—
—
—
—
—
—
—
—
161
—
—
—
—
$161
$ —
—
—
—
—
$ —
$ 199
12
829
275
285
51
7
412
90
161
4
49
1,447
35
$ 3,856
$ 210
302
216
12
13
$ 753
$ —
$
62
—
—
—
—
—
—
161
—
—
—
$161
565
125
19
1
225
22
161
7
458
26
$ 1,671
$ —
$
39
Notes to Financial StatementsSouthern Company 2023 Annual Report Fair Value Measurements Using
Quoted Prices
in Active
Markets for
Identical Assets
Significant
Other
Observable
Inputs
Significant
Unobservable
Inputs
Net Asset
Value as a
Practical
Expedient
At December 31, 2022:
(Level 1)
(Level 2)
(Level 3)
(NAV)
Total
(in millions)
Georgia Power
Assets:
Energy-related derivatives
Nuclear decommissioning trusts:(b)(c)
Domestic equity
Foreign equity
U.S. Treasury and government agency securities
Municipal bonds
Corporate bonds
Mortgage and asset backed securities
Other
Cash equivalents
Total
Liabilities:
Energy-related derivatives
Mississippi Power
Assets:
Energy-related derivatives
Cash equivalents
Total
Liabilities:
Energy-related derivatives
Southern Power
Assets:
Energy-related derivatives
Liabilities:
Energy-related derivatives
Foreign currency derivatives
Contingent consideration
Other
Total
Southern Company Gas
Assets:
Energy-related derivatives(a)
Non-qualified deferred compensation trusts:
Domestic equity
Foreign equity
Pooled funds - fixed income
Cash equivalents
Cash equivalents
Total
Liabilities:
Energy-related derivatives(a)(b)
Interest rate derivatives
Total
$ —
255
—
—
—
—
—
30
355
$640
$ —
$ —
47
$ 47
$ —
$ —
$ —
—
—
—
$ —
$ 18
—
—
—
4
50
$ 72
$ 32
—
$ 32
$ 42
1
149
266
50
187
68
12
—
$775
$ 62
$ 59
—
$ 59
$ 32
$
8
$ 12
47
—
13
$ 72
$ 10
8
1
7
—
—
$ 26
$ 33
86
$119
$ —
—
—
—
—
—
—
—
—
$ —
$ —
$ —
—
$ —
$ —
$ —
$ —
—
12
—
$ 12
$ —
—
—
—
—
—
$ —
$ —
—
$ —
$ —
—
—
—
—
—
—
—
—
$ —
$ —
$ —
—
$ —
$ —
$ —
$ —
—
—
—
$ —
$ —
—
—
—
—
—
$ —
$ —
—
$ —
$
42
256
149
266
50
187
68
42
355
$1,415
$
62
$
59
47
$ 106
$
32
$
$
$
8
12
47
12
13
84
$
28
8
1
7
4
50
98
$
$
65
86
$ 151
(a) Excludes cash collateral of $41 million.
(b) Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6
under “Nuclear Decommissioning” for additional information.
(c) Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. See Note 6
under “Nuclear Decommissioning” for additional information.
173
Notes to Financial StatementsSouthern Company 2023 Annual Report 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 14 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 under “Nuclear Decommissioning” for additional information.
Southern Power has contingent payment obligations related to two of its acquisitions whereby it is primarily obligated to make
generation-based payments to the seller, commencing at the commercial operation of each facility and continuing through 2026 and
2035, respectively. The obligations are primarily categorized as Level 3 under Fair Value Measurements as the fair value is determined using
significant unobservable inputs for the forecasted facility’s generation in MW-hours, as well as other inputs such as a fixed dollar amount
per MW-hour, and a discount rate. The fair value of contingent consideration reflects the net present value of expected payments and any
periodic change arising from forecasted generation is expected to be immaterial.
Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection
facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system.
The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the
contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value of
expected payments.
“Other investments” primarily includes investments traded in the open market that have maturities greater than 90 days, which are
categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds,
and/or agency bonds.
The fair value measurements of private market investments held in Alabama Power’s nuclear decommissioning trusts that are calculated at
net asset value per share (or its equivalent) as a practical expedient totaled $178 million and $161 million at December 31, 2023 and 2022,
respectively. Unfunded commitments related to the private market investments totaled $87 million and $78 million at December 31, 2023
and 2022, respectively. Private market investments include high-quality private equity funds across several market sectors, funds that
invest in real estate assets, and a private credit fund. Private market funds do not have redemption rights. Distributions from these funds
will be received as the underlying investments in the funds are liquidated.
174
Notes to Financial StatementsSouthern Company 2023 Annual Report At December 31, 2023 and 2022, other financial instruments for which the carrying amount did not equal fair value were as follows:
At December 31, 2023:
Long-term debt, including securities due within one year:
Carrying amount
Fair value
At December 31, 2022:
Long-term debt, including securities due within one year:
Carrying amount
Fair value
Southern
Company(*)
Alabama
Power
Georgia
Power
Mississippi
Power
Southern
Power
Southern
Company
Gas(*)
(in billions)
$59.4
55.0
$54.6
48.6
$11.2
10.1
$ 16.5
15.1
$10.6
9.2
$ 14.7
13.0
$ 1.6
1.4
$ 1.5
1.3
$2.7
2.6
$3.0
2.8
$7.8
6.8
$7.4
6.5
(*) The carrying amount of Southern Company Gas’ long-term debt includes fair value adjustments from the effective date of the 2016 merger with Southern
Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being through 2043.
The fair values are determined using Level 2 measurements and are based on quoted market prices for the same or similar issues or on the
current rates available to the Registrants.
14. DERIVATIVES
The Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign
currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to
take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company’s
policies in areas such as counterparty exposure and risk management practices. For the traditional electric operating companies, Southern
Power, and Southern Company Gas’ other businesses, each company’s policy is that derivatives are to be used primarily for hedging
purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques
including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized
at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note 13 for additional fair value
information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as
operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond
with the classification of the hedged interest or principal, respectively. See Note 1 under “Financial Instruments” for additional information.
See Note 15 under “Southern Company Gas” for additional information regarding the sale of Sequent.
Energy-Related Derivatives
The Subsidiary Registrants enter into energy-related derivatives to hedge exposures to electricity, natural gas, and other fuel price changes.
However, due to cost-based rate regulations and other various cost recovery mechanisms, the traditional electric operating companies and
the natural gas distribution utilities have limited exposure to market volatility in energy-related commodity prices. Each of the traditional
electric operating companies and certain of the natural gas distribution utilities of Southern Company Gas manage fuel-hedging programs,
implemented per the guidelines of their respective state PSCs or other applicable state regulatory agencies, through the use of financial
derivative contracts, which are expected to continue to mitigate price volatility. The traditional electric operating companies (with respect
to wholesale generating capacity) and Southern Power have limited exposure to market volatility in energy-related commodity prices
because their long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. However, the traditional electric
operating companies and Southern Power may be exposed to market volatility in energy-related commodity prices to the extent any
uncontracted capacity is used to sell electricity. Southern Company Gas retains exposure to price changes that can, in a volatile energy
market, be material and can adversely affect its results of operations.
Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather.
Exchange-traded options are carried at fair value, with changes reflected in operating revenues. Non-exchange-traded options are
accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in
operating revenues.
175
Notes to Financial StatementsSouthern Company 2023 Annual Report Energy-related derivative contracts are accounted for under one of three methods:
O Regulatory Hedges – Energy-related derivative contracts designated as regulatory hedges relate primarily to the traditional electric
operating companies’ and the natural gas distribution utilities’ fuel-hedging programs, where gains and losses are initially recorded
as regulatory liabilities and assets, respectively, and then are included in fuel expense as the underlying fuel is used in operations and
ultimately recovered through an approved cost recovery mechanism.
O 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 AOCI 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.
O 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 December 31, 2023, the net volume of energy-related derivative contracts for natural gas positions, together with the longest hedge
date over which the respective entity is hedging its exposure to the variability in future cash flows for forecasted transactions and the
longest non-hedge date for derivatives not designated as hedges, were as follows:
Southern Company(*)
Alabama Power
Georgia Power
Mississippi Power
Southern Power
Southern Company Gas(*)
Net Purchased
mmBtu
(in millions)
Longest
Hedge Date
Longest
Non-Hedge Date
448
118
128
93
7
102
2030
2026
2026
2028
2030
2027
2028
—
—
—
2024
2028
(*) Southern Company Gas’ derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and
a short position is a contract to sell natural gas. Southern Company Gas’ volume represents the net of long natural gas positions of 112 million mmBtu and
short natural gas positions of 10 million mmBtu at December 31, 2023, which is also included in Southern Company’s total volume.
In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural
gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume
of natural gas subject to such a feature is 12 million mmBtu for Southern Company, which includes 3 million mmBtu for Alabama Power,
4 million mmBtu for Georgia Power, 2 million mmBtu for Mississippi Power, and 3 million mmBtu for Southern Power.
For cash flow hedges of energy-related derivatives, the estimated pre-tax gains (losses) expected to be reclassified from AOCI to earnings
for the year ending December 31, 2024 are $(37) million for Southern Company, $(4) million for Southern Power, and $(33) million for
Southern Company Gas.
Interest Rate Derivatives
Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates.
Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow hedges where the
derivatives’ fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and presented on the same
income statement line item as the earnings effect of the hedged transactions. Derivatives related to existing fixed rate securities are
accounted for as fair value hedges, where the derivatives’ fair value gains or losses and hedged items’ fair value gains or losses are both
recorded directly to earnings on the same income statement line item. Fair value gains or losses on derivatives that are not designated or
fail to qualify as hedges are recognized in the statements of income as incurred.
176
Notes to Financial StatementsSouthern Company 2023 Annual Report At December 31, 2023, the following interest rate derivatives were outstanding:
Cash Flow Hedges of Forecasted Debt
Georgia Power
Mississippi Power
Mississippi Power
Fair Value Hedges of Existing Debt
Southern Company parent
Southern Company parent
Southern Company Gas
Southern Company
Notional
Amount
(in millions)
$ 150
75
75
400
1,000
500
$2,200
Weighted Average
Interest Rate Paid
Interest Rate
Received
Hedge
Maturity Date
4.01%
3.84%
4.04%
N/A
N/A
N/A
April 2024
June 2024
June 2024
1-month SOFR + 0.80 %
1-month SOFR + 2.48%
1-month SOFR + 0.49%
1.75% March 2028
April 2030
3.70%
1.75% January 2031
Fair Value
Gain (Loss)
December 31,
2023
(in millions)
$ —
—
—
(46)
(139)
(79)
$ (264)
For cash flow hedges of interest rate derivatives, the estimated pre-tax losses expected to be reclassified from AOCI to interest expense for
the year ending December 31, 2024 are $19 million for Southern Company and immaterial for the traditional electric operating companies
and Southern Company Gas. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings
through 2054 for Southern Company, Georgia Power, and Mississippi Power, 2052 for Alabama Power, and 2046 for Southern Company Gas.
Foreign Currency Derivatives
Southern Company and certain subsidiaries, including Southern Power, may enter into foreign currency derivatives to hedge exposure
to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S.
dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives’ fair value gains or losses
are recorded in OCI and are reclassified into earnings at the same time and on the same income statement line as the earnings effect of the
hedged transactions, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Derivatives related
to existing fixed rate securities are accounted for as fair value hedges, where the derivatives’ fair value gains or losses and hedged items’
fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or
losses arising from changes in the U.S. currency exchange rates. Southern Company has elected to exclude the cross-currency basis spread
from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in
the fair value of the excluded components and the amounts recognized in earnings as a component of OCI.
At December 31, 2023, the following foreign currency derivatives were outstanding:
Pay Notional Pay Rate
Receive
Notional
Receive
Rate
Hedge
Maturity Date
(in millions)
(in millions)
Fair Value
Gain (Loss)
December 31,
2023
(in millions)
Cash Flow Hedges of Existing Debt
Southern Power
$ 564
3.78%
€ 500
1.85%
June 2026
$ (22)
Fair Value Hedges of Existing Debt
Southern Company parent
Southern Company
1,476
3.39%
1,250
1.88%
September 2027
$2,040
€ 1,750
(100)
$ (122)
For cash flow hedges of foreign currency derivatives, the estimated pre-tax losses expected to be reclassified from AOCI to earnings for the
year ending December 31, 2024 are $11 million for Southern Power.
Derivative Financial Statement Presentation and Amounts
The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative
receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain
subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain
provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on
the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.
177
Notes to Financial StatementsSouthern Company 2023 Annual Report The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets
as follows:
Derivative Category and Balance Sheet Location
Assets
Liabilities
Assets
Liabilities
2023
2022
Southern Company
Energy-related derivatives designated as hedging instruments
for regulatory purposes
(in millions)
Assets from risk management activities/Liabilities from risk management activities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives designated as hedging instruments for regulatory purposes
Derivatives designated as hedging instruments in cash flow and fair
$ 12
31
43
$198
117
315
$123
52
175
$ 121
44
165
value hedges
Energy-related derivatives:
Assets from risk management activities/Liabilities from risk management activities
Other deferred charges and assets/Other deferred credits and liabilities
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities
Other deferred charges and assets/Other deferred credits and liabilities
Foreign currency derivatives:
Assets from risk management activities/Liabilities from risk management activities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives designated as hedging instruments in cash flow
and fair value hedges
Energy-related derivatives not designated as hedging instruments
Assets from risk management activities/Liabilities from risk management
activities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives not designated as hedging instruments
Gross amounts recognized
Gross amounts offset(a)
Net amounts recognized in the Balance Sheets(b)
Alabama Power(c)
Energy-related derivatives designated as hedging instruments
for regulatory purposes
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives designated as hedging instruments for regulatory purposes
Gross amounts offset
Net amounts recognized in the Balance Sheets
Georgia Power
Energy-related derivatives designated as hedging instruments
for regulatory purposes
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives not designated as hedging instruments
Other deferred charges and assets/Other deferred credits and liabilities
Gross amounts recognized
Gross amounts offset
Net amounts recognized in the Balance Sheets
—
3
—
—
—
—
3
8
1
9
55
(23)
$ 32
$ 6
9
15
(10)
$ 5
$ 2
10
12
1
13
(11)
$ 2
29
4
74
190
34
88
419
8
2
10
744
(85)
$659
$ 69
41
110
(10)
$100
$ 82
42
124
—
124
(11)
$113
3
6
12
—
—
—
21
13
2
15
211
(70)
$141
$ 42
20
62
(24)
$ 38
$ 36
6
42
—
42
(21)
$ 21
27
4
62
240
34
182
549
13
1
14
728
(111)
$ 617
$ 21
18
39
(24)
$ 15
$ 43
18
61
1
62
(21)
$ 41
178
Notes to Financial StatementsSouthern Company 2023 Annual Report Derivative Category and Balance Sheet Location
Assets
Liabilities
Assets
Liabilities
2023
2022
Mississippi Power(c)
Energy-related derivatives designated as hedging instruments
for regulatory purposes
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives designated as hedging instruments for regulatory purposes
Gross amounts offset
Net amounts recognized in the Balance Sheets
Southern Power
Derivatives designated as hedging instruments in cash flow and fair
value hedges
Energy-related derivatives:
(in millions)
$ 3
12
15
(14)
$ 1
$ 27
34
61
(14)
$ 47
$ 33
26
59
(17)
$ 42
$ 24
8
32
(17)
$ 15
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
$ —
3
$
Foreign currency derivatives:
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives designated as hedging instruments in cash flow and fair
value hedges
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives not designated as hedging instruments
Net amounts recognized in the Balance Sheets
Southern Company Gas
Energy-related derivatives designated as hedging instruments for regulatory
purposes
—
—
3
—
—
—
$ 3
5
—
11
11
27
—
—
—
$ 27
$ —
5
$ 12
—
—
—
5
2
1
3
8
$
11
36
59
—
—
—
$ 59
Other current assets/Other current liabilities
$ 1
$ 20
$ 12
$ 33
Derivatives designated as hedging instruments in cash flow and fair
value hedges
Energy-related derivatives:
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Interest rate derivatives:
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives designated as hedging instruments in cash flow and fair
value hedges
Energy-related derivatives not designated as hedging instruments
Other current assets/Other current liabilities
Other deferred charges and assets/Other deferred credits and liabilities
Total derivatives not designated as hedging instruments
Gross amounts recognized
Gross amounts offset(a)
Net amounts recognized in the Balance Sheets(b)
—
—
—
—
—
7
1
8
9
12
$ 21
24
4
20
59
107
8
2
10
137
(50)
$ 87
3
1
—
—
4
11
1
12
28
—
$ 28
(a) Gross amounts offset includes cash collateral held on deposit in broker margin accounts of $62 million and $41 million at December 31, 2023
and 2022, respectively.
(b) Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for all
periods presented.
(c) Energy-related derivatives not designated as hedging instruments were immaterial at December 31, 2022. There were no such instruments at
December 31, 2023.
15
4
14
72
105
12
1
13
151
(41)
$ 110
179
Notes to Financial StatementsSouthern Company 2023 Annual Report At December 31, 2023 and 2022, the pre-tax effects of unrealized derivative gains (losses) arising from energy-related derivative
instruments designated as regulatory hedging instruments and deferred were as follows:
Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheets
Derivative Category and Balance Sheet Location
At December 31, 2023:
Energy-related derivatives:
Other regulatory assets, current
Other regulatory assets, deferred
Other regulatory liabilities, current
Other regulatory liabilities, deferred
Total energy-related derivative gains (losses)
At December 31, 2022:
Energy-related derivatives:
Other regulatory assets, current
Other regulatory assets, deferred
Other regulatory liabilities, current
Other regulatory liabilities, deferred
Total energy-related derivative gains (losses)
Southern
Company
Alabama
Power
Georgia
Power
Mississippi
Power
(in millions)
Southern
Company
Gas
$ (180)
(87)
9
1
$ (257)
$ (71)
(23)
72
31
9
$
$ (67)
(32)
4
—
$ (95)
$ (8)
(7)
29
9
$ 23
$ (80)
(33)
—
1
$ (112)
$ (26)
(14)
19
2
$ (19)
$(25)
(22)
1
—
$(46)
$(13)
(2)
22
20
$ 27
$ (8)
—
4
—
$ (4)
$(24)
—
2
—
$(22)
For the years ended December 31, 2023, 2022, and 2021, the pre-tax effects of cash flow and fair value hedge accounting on AOCI for the
applicable Registrants were as follows:
Gain (Loss) From Derivatives Recognized in OCI
Southern Company
Cash flow hedges:
Energy-related derivatives
Interest rate derivatives
Foreign currency derivatives
Fair value hedges(*):
Foreign currency derivatives
Total
Georgia Power
Cash flow hedges:
Interest rate derivatives
Southern Power
Cash flow hedges:
Energy-related derivatives
Foreign currency derivatives
Total
Southern Company Gas
Cash flow hedges:
Energy-related derivatives
2023
2022
2021
(in millions)
$(81)
(12)
14
21
$(58)
$
3
46
(105)
(24)
$ (80)
$ 34
5
(103)
(3)
$ (67)
$ (2)
$ 31
$ —
$(18)
14
$ (4)
$ (15)
(105)
$ (120)
$ 12
(103)
$ (91)
$(63)
$ 18
$ 22
(*) Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is
recorded in OCI.
180
Notes to Financial StatementsSouthern Company 2023 Annual Report The pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on AOCI were immaterial for Alabama Power
for all years presented and immaterial for Mississippi Power in 2023.
The pre-tax effects of cash flow and fair value hedge accounting on income for the years ended December 31, 2023, 2022, and 2021 were
as follows:
Location and Amount of Gain (Loss) Recognized in Income on Cash Flow
and Fair Value Hedging Relationships
Southern Company
Total cost of natural gas
Gain (loss) on energy-related cash flow hedges(a)
Total other operations and maintenance
Gain (loss) on energy-related cash flow hedges(a)
Total depreciation and amortization
Gain (loss) on energy-related cash flow hedges(a)
Total interest expense, net of amounts capitalized
Gain (loss) on interest rate cash flow hedges(a)
Gain (loss) on foreign currency cash flow hedges(a)
Gain (loss) on interest rate fair value hedges(b)
Total other income (expense), net
Gain (loss) on foreign currency cash flow hedges(a)(c)
Gain (loss) on foreign currency fair value hedges
Amount excluded from effectiveness testing recognized in earnings
Southern Power
Total depreciation and amortization
Gain (loss) on energy-related cash flow hedges(a)
Total interest expense, net of amounts capitalized
Gain (loss) on foreign currency cash flow hedges(a)
Total other income (expense), net
Gain (loss) on foreign currency cash flow hedges(a)(c)
Southern Company Gas
Total cost of natural gas
Gain (loss) on energy-related cash flow hedges(a)
Total other operations and maintenance
Gain (loss) on energy-related cash flow hedges(a)
Total interest expense, net of amounts capitalized
Gain (loss) on interest rate cash flow hedges(a)
Gain (loss) on interest rate fair value hedges(b)
2023
$ 1,644
(44)
6,093
(2)
4,525
(23)
(2,446)
(35)
(11)
37
553
19
69
(21)
504
(23)
(129)
(11)
12
19
$
$ 1,644
(44)
1,194
(2)
(310)
(19)
6
2022
(in millions)
$ 3,004
37
6,573
—
3,663
(5)
(2,022)
(25)
(19)
(291)
500
(83)
(106)
24
516
(5)
(138)
(19)
7
(83)
$
$ 3,004
37
1,176
—
(263)
(4)
(86)
2021
$ 1,619
17
5,902
—
3,565
9
(1,837)
(27)
(24)
(30)
449
(104)
(63)
3
517
9
(147)
(24)
10
(104)
$
$ 1,619
17
1,072
—
(238)
—
—
(a) Reclassified from AOCI 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 AOCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency
exchange rates used to record the euro-denominated notes.
The pre-tax effects of cash flow hedge accounting on income for interest rate derivatives were immaterial for the traditional electric
operating companies for all years presented.
181
Notes to Financial StatementsSouthern Company 2023 Annual Report At December 31, 2023 and 2022, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for
fair value hedges:
Balance Sheet Location of Hedged Items
Southern Company
Long-term debt
Southern Company Gas
Long-term debt
Carrying Amount of the Hedged Item
Cumulative Amount of Fair Value
Hedging Adjustment included in
Carrying Amount of the Hedged Item
At December 31,
2023
At December 31,
2022
At December 31,
2023
At December 31,
2022
(in millions)
(in millions)
$(3,024)
$(2,927)
$ (427)
$ (415)
$ 235
$ 70
$282
$ 81
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 for the years ended December 31, 2023, 2022, and 2021 were as follows:
Derivatives in Non-Designated
Hedging Relationships
Statements of Income Location
Energy-related derivatives
Natural gas revenues(*)
Cost of natural gas
Total derivatives in non-designated hedging relationships
Gain (Loss)
2022
(in millions)
$ (11)
(65)
$ (76)
2023
$ —
59
$ 59
2021
$ (117)
(27)
$ (144)
(*) Excludes the impact of weather derivatives recorded in natural gas revenues of $15 million and $(7) million for 2023 and 2022, respectively, as they are
accounted for based on intrinsic value rather than fair value. There was no weather derivatives impact for 2021.
The pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for all other Registrants for all
years presented.
Contingent Features
The Registrants do not have any credit arrangements that would require material changes in payment schedules or terminations as a
result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event
of various credit rating changes of certain Southern Company subsidiaries. Generally, collateral may be provided by a Southern Company
guaranty, letter of credit, or cash. At December 31, 2023, the Registrants had no collateral posted with derivative counterparties to satisfy
these arrangements.
For Southern Company, the fair value of foreign currency derivative liabilities and interest rate derivative liabilities with contingent features,
and the maximum potential collateral requirements arising from the credit-risk-related contingent features at a rating below BBB- and/or
Baa3, was $52 million at December 31, 2023. For Southern Power, the fair value of foreign currency derivative liabilities with contingent
features, and the maximum potential collateral requirements arising from the credit-risk-related contingent features at a rating below
BBB- and/or Baa3, was immaterial at December 31, 2023. For the traditional electric operating companies and Southern Power, energy-
related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related
contingent features, at a rating below BBB- and/or Baa3, were immaterial at December 31, 2023. The maximum potential collateral
requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power
include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a
credit rating change to below investment grade.
Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative
transactions and they may be required to post collateral based on the value of the positions in these accounts and the associated margin
requirements. At December 31, 2023, cash collateral posted in these accounts was immaterial for Alabama Power and Southern Power.
Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative
transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas
may be required to deposit cash into these accounts. At December 31, 2023, cash collateral held on deposit in broker margin accounts
was $62 million.
182
Notes to Financial StatementsSouthern Company 2023 Annual Report The Registrants are exposed to losses related to financial instruments in the event of counterparties’ nonperformance. The Registrants only
enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody’s and S&P or
with counterparties who have posted collateral to cover potential credit exposure. The Registrants have also established risk management
policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty
credit risk.
Southern Company Gas uses established credit policies to determine and monitor the creditworthiness of counterparties, including
requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most
often in the form of cash or letters of credit from an investment-grade financial institution, but may also include cash or U.S. government
securities held by a trustee. Prior to entering a physical transaction, Southern Company Gas assigns its counterparties an internal credit
rating and credit limit based on the counterparties’ Moody’s, S&P, and Fitch ratings, commercially available credit reports, and audited
financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.
Southern Company Gas utilizes netting agreements whenever possible to mitigate exposure to counterparty credit risk. Netting agreements
enable Southern Company Gas to net certain assets and liabilities by counterparty across product lines and against cash collateral, provided
the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, counterparties are settled net,
they are recorded on a gross basis on the balance sheet as energy marketing receivables and energy marketing payables.
The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of
counterparty nonperformance.
15. ACQUISITIONS AND DISPOSITIONS
None of the dispositions discussed herein, both individually and combined, represented a strategic shift in operations for the applicable
Registrants 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.
Southern Company
In October 2021, Southern Company completed the sale of a leveraged lease investment to the lessee for $45 million. No gain or loss was
recognized on the sale; however, it did result in the recognition of approximately $16 million of additional tax benefits. Prior to the sale, in
the second quarter 2021, a charge of $7 million ($6 million after tax) was recorded to reduce the investment to its estimated fair value, less
costs to sell.
In December 2021, Southern Company completed the termination of its leasehold interest in assets associated with its two international
leveraged lease projects and received cash proceeds of approximately $673 million after the accelerated exercise of the lessee’s purchase
options. The pre-tax gain associated with the transaction was approximately $93 million ($99 million gain after tax).
Alabama Power
In September 2022, Alabama Power completed its acquisition of the Calhoun Generating Station, which was accounted for as an asset
acquisition. The total purchase price was $179 million, of which $171 million was related to net assets recorded within property, plant,
and equipment on the balance sheet and reflected in property additions within the investing section of the statement of cash flows.
The remainder primarily related to fossil fuel stock and materials and supplies. See Note 2 under “Alabama Power – Rate CNP New Plant”
for additional information.
Southern Power
Southern Power’s acquisition-related costs for the projects discussed under “Asset Acquisitions” and “Construction Projects” were not
material for any of the years presented. There were no asset acquisitions during 2022.
183
Notes to Financial StatementsSouthern Company 2023 Annual Report Asset Acquisitions
Project Facility
Resource
Seller
Asset Acquisitions During 2023
Millers Branch(a)
South Cheyenne
Asset Acquisitions During 2021
Deuel Harvest(b)
Solar
Solar
EDF Renewables
Development, Inc.
Hanwha Q Cells
USA Corp.
Wind
Invenergy
Renewables LLC
Approximate
Nameplate
Capacity
(MW)
200
150
300
Location
Haskell
County, TX
Laramie
County, WY
Southern
Power
Ownership
Percentage
Expected/
Actual
COD
100%
100%
Fourth
quarter
2025
Second
quarter
2024
PPA Contract
Period
20 years
20 years
Deuel
County, SD
100% of
Class B
February
2021
25 years
and 15 years
(a) The project includes an option to expand capacity up to an additional 300 MWs. Subsequent to December 31, 2023, Southern Power committed to expand
the construction of the facility through a second phase adding up to 205 MWs, with commercial operation expected to occur in the second quarter 2026.
(b) In March 2021, Southern Power acquired a controlling interest in the project from Invenergy Renewables LLC and completed a tax equity transaction
whereby it sold the Class A membership interests in the project. Southern Power consolidates the project’s operating results in its financial statements and
the tax equity partner and Invenergy Renewables LLC each own a noncontrolling interest.
The aggregate purchase price for the two projects acquired during 2023 was $193 million, which is primarily recorded within construction
work in progress on the balance sheet at December 31, 2023.
Construction Projects
Project Facility
Resource
Projects Completed During 2022
Garland Solar Storage(a)
Battery energy storage
Tranquillity Solar Storage(a)
Battery energy storage
Approximate
Nameplate
Capacity
(MW)
Location
COD
88
72
Kern County, CA
Fresno County, CA
September 2021 through
February 2022(b)
November 2021 through
March 2022(c)
PPA
Contract
Period
20 years
20 years
Projects Completed During 2021
Glass Sands(d)
Wind
118
Murray County, OK
November 2021
12 years
(a) In 2020, Southern Power restructured its ownership of the project, while retaining the controlling interests, by contributing the Class A membership
interests to an existing partnership and selling 100% of the Class B membership interests. During 2021, Southern Power further restructured its
ownership in the battery energy storage projects and completed tax equity transactions whereby it sold the Class A membership interests in the projects.
Southern Power consolidates each project’s operating results in its financial statements and the tax equity partner and two other partners each own a
noncontrolling interest. See Note 9 under “Lessor” for additional information.
(b) The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in 2022.
(c) The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in 2022.
(d) In December 2020, Southern Power purchased 100% of the membership interests of the Glass Sands facility.
Development Projects
Southern Power purchased wind turbine equipment in 2016 and 2017 for deployment to development and construction projects. All of
this equipment has either been deployed to projects that have been completed or has been sold to third parties. Gains on wind turbine
equipment contributed to various equity method investments totaled approximately $37 million in 2021.
184
Notes to Financial StatementsSouthern Company 2023 Annual Report Southern Company Gas
Sale of Sequent
In July 2021, Southern Company Gas affiliates completed the sale of Sequent to Williams Field Services Group for a total cash purchase
price of $159 million, including final working capital adjustments. The pre-tax gain associated with the transaction was approximately
$121 million ($92 million after tax). The sale resulted in $85 million of additional tax expense.
Sale of Natural Gas Storage Facilities
In September 2022, certain affiliates of Southern Company Gas entered into agreements to sell two natural gas storage facilities located
in California and Texas for an aggregate purchase price of $186 million, plus working capital and certain other adjustments. The sale of the
Texas facility was completed in November 2022 and the sale of the California facility was completed on September 22, 2023. Both sales
resulted in an immaterial loss. Completion of the sale of the Texas facility was subject to release of a Southern Company Gas parent
guarantee, which was executed in October 2022 and, as a result, Southern Company Gas recorded pre-tax impairment charges totaling
approximately $131 million ($99 million after tax) in the fourth quarter 2022.
16. SEGMENT AND RELATED INFORMATION
Southern Company
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
$537 million, $875 million, and $515 million in 2023, 2022, and 2021, respectively. Revenues from sales of natural gas from Southern
Company Gas to the traditional electric operating companies were immaterial for all periods presented. Revenues from sales of natural gas
from Southern Company Gas (prior to its sale of Sequent) to Southern Power were $18 million in 2021. The “All Other” column includes the
Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments
below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions
and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications.
All other inter-segment revenues are not material.
185
Notes to Financial StatementsSouthern Company 2023 Annual Report Financial data for business segments and products and services for the years ended December 31, 2023, 2022, and 2021 was as follows:
Electric Utilities
Traditional
Electric
Operating
Companies
Southern
Power
Eliminations
Total
Southern
Company
Gas
All
Other
Eliminations
Consolidated
(in millions)
$ 18,358
$ 2,189
$ (549)
$ 19,998
$ 4,702
$ 718
$(165)
$ 25,253
3,361
69
(1)
1,145
571
504
7
—
129
12
—
—
—
—
—
3,865
76
(1)
1,274
583
582
9
140
310
211
3,637
—
100,429
357
2
12,761
—
—
(545)
3,994
2
112,645
615
5,015
25,083
78
26
5
879
(298)
(635)
144
2,446
—
(26)
—
(17)
—
2
—
(843)
4,525
85
144
2,446
496
3,976
5,161
139,331
$ 20,408
$ 3,369
$ (904)
$ 22,873
$ 5,962
$ 593
$(149)
$ 29,279
2,513
44
—
929
828
3,318
—
95,861
516
3
—
138
20
354
2
13,081
—
—
—
—
—
3,029
47
—
1,067
848
559
3
148
263
180
—
—
(659)
3,672
2
108,283
572
5,015
24,621
75
16
3
694
(233)
(711)
144
2,665
—
(7)
—
(2)
—
3,663
59
151
2,022
795
(9)
—
(678)
3,524
5,161
134,891
$ 16,614
$ 2,216
$ (530)
$ 18,300
$ 4,380
$ 582
$(149)
$ 23,113
2,436
20
1
821
232
1,981
—
89,051
517
1
—
147
(13)
—
—
—
—
—
2,953
21
1
968
219
536
—
50
238
275
266
2
13,390
—
—
(667)
2,247
2
101,774
539
5,015
23,560
76
4
24
631
(227)
(384)
263
2,975
—
(3)
1
—
—
3,565
22
76
1,837
267
(9)
—
(775)
2,393
5,280
127,534
2023
Operating revenues
Depreciation and
amortization
Interest income
Earnings from equity
method investments
Interest expense
Income taxes (benefit)
Segment net income
(loss)(a)(b)(c)(d)
Goodwill
Total assets
2022
Operating revenues
Depreciation and
amortization
Interest income
Earnings from equity
method investments
Interest expense
Income taxes (benefit)
Segment net income
(loss)(a)(b)(e)(f)
Goodwill
Total assets
2021
Operating revenues
Depreciation and
amortization
Interest income
Earnings from equity
method investments
Interest expense
Income taxes (benefit)
Segment net income
(loss)(a)(b)(g)(h)(i)
Goodwill
Total assets
(a) Attributable to Southern Company.
(b) For the traditional electric operating companies, includes pre-tax charges (credits) to income at Georgia Power for the estimated probable loss associated
with the construction of Plant Vogtle Units 3 and 4 of $(68) million ($(50) million after tax) in 2023, $183 million ($137 million after tax) in 2022, and
$1.7 billion ($1.3 billion after tax) in 2021. See Note 2 under “Georgia Power – Nuclear Construction” for additional information.
(c) For Southern Power, includes an $18 million pre-tax loss recovery ($9 million after tax and partnership allocations) related to an arbitration award
and a $16 million pre-tax gain ($12 million after tax) on the sale of spare parts. See Note 3 under “General Litigation Matters – Southern Power” for
additional information.
(d) For Southern Company Gas, includes pre-tax charges totaling approximately $96 million ($72 million after tax) associated with the disallowance of certain
capital investments at Nicor Gas. See Note 2 under “Southern Company Gas” for additional information.
186
Notes to Financial StatementsSouthern Company 2023 Annual Report (e) For Southern Company Gas, includes pre-tax impairment charges totaling approximately $131 million ($99 million after tax) related to the sale of natural
gas storage facilities. See Note 15 under “Southern Company Gas” for additional information.
(f) For the “All Other” column, includes a $119 million goodwill impairment loss (pre-tax and after tax) at PowerSecure. See Note 1 under “Goodwill and Other
Intangible Assets” for additional information.
(g) For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million
pre-tax ($28 million after tax). See Notes 7 and 15 under “Southern Power” for additional information.
(h) For Southern Company Gas, includes a pre-tax gain of $121 million ($92 million after tax) related to its sale of Sequent, as well as the resulting $85 million
of additional tax expense due to changes in state apportionment rates, and pre-tax impairment charges totaling $84 million ($67 million after tax) related
to its equity method investment in the PennEast Pipeline project. See Notes 7 and 15 under “Southern Company Gas” for additional information.
(i) For the “All Other” column, includes a pre-tax gain of $93 million ($99 million gain after tax) associated with the termination of two leveraged leases
projects. See Note 15 under “Southern Company” for additional information.
Products and Services
Year
2023
2022
2021
Year
2023
2022
2021
Electric Utilities’ Revenues
Retail
Wholesale
Other
Total
(in millions)
$16,343
18,197
14,852
$2,467
3,641
2,455
$1,188
1,035
993
$19,998
22,873
18,300
Southern Company Gas’ Revenues
Gas
Distribution
Operations
Gas
Marketing
Services
All Other
Total
$4,090
5,240
3,656
(in millions)
$548
638
475
$ 64
84
249
$4,702
5,962
4,380
Southern Company Gas
Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments,
and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas’ reportable segments also included
wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 under “Southern Company Gas”
for additional information on the disposition activities described herein.
Gas distribution operations is the largest component of Southern Company Gas’ business and includes natural gas local distribution utilities
that construct, manage, and maintain intrastate natural gas pipelines and gas distribution facilities in four states.
Gas pipeline investments consists of joint ventures in natural gas pipeline investments including a 50% interest in SNG and a 50% joint
ownership interest in the Dalton Pipeline. These natural gas pipelines enable the provision of diverse sources of natural gas supplies to the
customers of Southern Company Gas. See Notes 5 and 7 for additional information.
Through July 1, 2021, wholesale gas services provided natural gas asset management and/or related logistics services for each of Southern
Company Gas’ utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engaged in natural gas
storage and gas pipeline arbitrage and related activities.
Gas marketing services provides natural gas marketing to end-use customers primarily in Georgia and Illinois through SouthStar.
The all other column includes segments and subsidiaries that fall below the quantitative threshold for separate disclosure, including storage
and fuels operations. The all other column included a natural gas storage facility in Texas through its sale in November 2022 and a natural
gas storage facility in California through its sale in September 2023.
187
Notes to Financial StatementsSouthern Company 2023 Annual Report Financial data for business segments for the years ended December 31, 2023, 2022, and 2021 was as follows:
Gas
Distribution
Operations
Gas
Pipeline
Investments
Wholesale
Gas
Services(a)
Gas
Marketing
Services
(in millions)
Total
All Other
Eliminations
Consolidated
2023
Operating revenues
Depreciation and amortization
Operating income (loss)
Earnings from equity method
investments
Interest expense
Income taxes
Segment net income (loss)(b)
Total assets
2022
Operating revenues
Depreciation and amortization
Operating income (loss)
Earnings from equity method
investments
Interest expense
Income taxes (benefit)
Segment net income (loss)(c)
Total assets
2021
Operating revenues
Depreciation and amortization
Operating income (loss)
Earnings from equity method
investments
Interest expense
Income taxes
Segment net income (loss)(d)(e)(f)
Total assets
$ 4,105
561
804
—
275
126
441
22,906
$ 5,267
516
803
—
229
145
470
22,040
$ 3,679
482
708
—
207
120
412
20,917
$
32
5
22
140
32
32
98
1,534
$
32
5
21
148
27
35
107
1,577
$
32
5
21
50
25
27
19
1,467
$ —
—
—
$ 548
15
130
$ 4,685
581
956
$
36
1
(4)
—
—
—
—
—
—
3
37
91
1,615
140
310
195
630
26,055
—
—
16
(15)
9,675
$ —
—
—
$ 638
16
133
$ 5,937
537
957
$
55
22
(135)
—
—
—
—
—
—
3
37
94
1,616
148
259
217
671
25,233
—
4
(37)
(99)
8,943
$ 188
—
241
$ 475
18
125
$ 4,374
505
1,095
$
38
31
(40)
—
2
32
107
31
—
3
34
88
1,556
50
237
213
626
23,971
—
1
62
(87)
12,114
$
$
$
(19)
—
(13)
$ 4,702
582
939
—
—
—
—
(10,647)
140
310
211
615
25,083
(30)
—
(8)
$ 5,962
559
814
—
—
—
—
(9,555)
(32)
—
—
—
—
—
—
(12,525)
148
263
180
572
24,621
$ 4,380
536
1,055
50
238
275
539
23,560
(a) As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment in 2023 or 2022. Prior to the sale of Sequent, the revenues
for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and
intercompany revenues is shown in the following table.
Third Party
Gross
Revenues
Inter -
company
Revenues
Total
Gross
Revenues
(in millions)
Less Gross
Gas Costs
Operating
Revenues
2021
$ 3,881
$ 90
$3,971
$3,783
$188
(b) For gas distribution operations, includes pre-tax charges totaling approximately $96 million ($72 million after tax) associated with the disallowance of
certain capital investments at Nicor Gas. See Note 2 under “Southern Company Gas” for additional information.
(c) For the “All Other” column, includes pre-tax impairment charges totaling approximately $131 million ($99 million after tax) related to the sale of natural gas
storage facilities. See Note 15 under “Southern Company Gas” for additional information.
(d) For gas pipeline investments, includes pre-tax impairment charges totaling $84 million ($67 million after tax) related to the equity method investment in
the PennEast Pipeline project. See Note 7 under “Southern Company Gas” for additional information.
(e) For wholesale gas services, includes a pre-tax gain of $121 million ($92 million after tax) related to the sale of Sequent.
(f) For the “All Other” column, includes $85 million of additional tax expense as a result of the sale of Sequent.
188
Notes to Financial StatementsSouthern Company 2023 Annual Report Shareholder Information
Transfer Agent
EQ Shareowner Services is Southern Company’s transfer agent,
dividend-paying agent, investment plan administrator and
registrar. If you have questions concerning your registered
Southern Company shareowner account, please contact:
EQ Shareowner Services
1110 Centre Pointe Curve, Suite 101
Mendota Heights, Minnesota 55120
Telephone: 1.800.554.7626
Website: shareowneronline.com
Southern Company Shareholder Relations
Telephone: 404.506.0965
Email: shareholderservices@southernco.com
Southern Investment Plan
The Southern Investment Plan is a convenient way to become
a Southern Company shareholder. Participants in the Plan
can purchase additional shares in Southern Company through
optional cash purchases and reinvestment of dividends.
The Southern Investment Plan prospectus can be found at
investor.southerncompany.com/shareowner-services.
Dividend Payments
Southern Company has paid dividends since 1948. Historically,
dividends are declared and paid quarterly at the discretion of
the board of directors.
Auditors
Deloitte & Touche LLP
191 Peachtree St. NE
Suite 2000
Atlanta, GA 30303
Investor Information
For information about earnings and dividends,
stock quotes and current news releases, please
visit us at investor.southerncompany.com.
Institutional Investor Inquiries
Southern Company maintains an investor relations office in
Atlanta, Georgia, 404.506.0901, to meet the information needs
of institutional investors and securities analysts.
Electronic Delivery of Proxy Materials
Any stockholder may enroll for electronic delivery of proxy
materials by logging on at www.icsdelivery.com/so.
Common Stock
Southern Company common stock is listed on the NYSE
under the ticker symbol SO. On January 31, 2024,
Southern Company had 95,412 shareholders of record.
The 2023 annual report is submitted for shareholders’
information. It is not intended for use in connection with
any sale or purchase of, or any solicitation of offers to buy
or sell, securities.
Southern Company is a holding company that conducts
business through its subsidiaries. Unless the context other-
wise requires, references to Southern Company’s customers,
communities and operations in this 2023 annual report refer to
the customers, communities and operations of its subsidiaries.
Pages 6-188 of this 2023 annual report contain excerpts from
Southern Company’s Annual Report on Form 10-K for the year
ended December 31, 2023, which was filed with the SEC on
February 14, 2024. Information in these pages is provided as
of the February 14, 2024 filing date and has not been updated
for any subsequent events or developments.
Visit our website at www.southerncompany.com.
Follow us on X at www.twitter.com/southerncompany.
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